EASTERN SYSTEM UPGRADE - Millennium Pipelinemillenniumpipeline.com/documents/ESU/Volume II/VOLUME...

EASTERN SYSTEM UPGRADE

RESOURCE REPORT 9

Air and Noise Quality

FERC Docket No. CP16-__-000

July 2016

Resource Report 9 - Air and Noise Quality i Eastern System Upgrade

TABLE OF CONTENTS

Section Page

9.0 RESOURCE REPORT 9 - AIR AND NOISE QUALITY ........................................................... 9-1

9.1 AIR QUALITY ............................................................................................................................. 9-2

9.1.1 Existing Conditions .......................................................................................................... 9-2

Climate ......................................................................................................... 9-2

National Ambient Air Quality Standards ..................................................... 9-2

New York State Ambient Air Quality Standards ........................................... 9-3

Attainment Status .......................................................................................... 9-3

Ambient Air Quality in the Project Area ...................................................... 9-4

9.1.2 Regulatory Requirements ................................................................................................ 9-4

General Conformity ...................................................................................... 9-4

New Source Review ...................................................................................... 9-5

Class I Areas ................................................................................................ 9-6

Title V Operating Permit and State Operating Permit Programs ................ 9-6

Standards of Performance for New Stationary Sources ............................... 9-7

Risk Management Program .......................................................................... 9-9

Greenhouse Gas Mandatory Reporting Rule ............................................. 9-10

9.1.3 Air Quality Impacts ....................................................................................................... 9-10

Project Construction .................................................................................. 9-10

Project Operation ....................................................................................... 9-12

Emissions Health Effect Evaluation ........................................................... 9-13

9.2 NOISE QUALITY ...................................................................................................................... 9-15

9.2.1 Noise Regulations .......................................................................................................... 9-15

Federal Energy Regulatory Commission ................................................... 9-15

State Regulations ........................................................................................ 9-16

County Regulations .................................................................................... 9-16

Local Regulations ....................................................................................... 9-16

9.2.2 Existing Noise Levels .................................................................................................... 9-16

9.2.3 Construction Noise Impacts ........................................................................................... 9-17

Aboveground Facilities .............................................................................. 9-17

Pipeline Facilities ...................................................................................... 9-17

Horizontal Directional Drill Sites .............................................................. 9-17

9.2.4 Operating Noise Impacts ............................................................................................... 9-19

Highland CS (New) .................................................................................... 9-19

Hancock CS (Modified) .............................................................................. 9-19

Ramapo M&R (Modified) ........................................................................... 9-20

Huguenot M&R (Modified) ........................................................................ 9-20

9.2.5 Noise Mitigation Measures ............................................................................................ 9-20

9.2.6 Post-Construction Sound Surveys.................................................................................. 9-21

Highland CS (New) .................................................................................... 9-21

Hancock CS (Modified) .............................................................................. 9-21

Resource Report 9 - Air and Noise Quality ii Eastern System Upgrade

Ramapo M&R (Modified) ........................................................................... 9-21

Huguenot M&R (Modified) ........................................................................ 9-21

9.3 REFERENCES ........................................................................................................................... 9-21

LIST OF TABLES

Page

TABLE 9.0-1 Project Compressor Station Summary ............................................................................. 9-2

TABLE 9.2-1 Construction Noise Assessment for the HDD Sites ....................................................... 9-18

LIST OF APPENDICES

APPENDIX 9A Supplemental Tables

TABLE 9A-1 Regional Climate Data

TABLE 9A-2 National Ambient Air Quality Standards

TABLE 9A-3 New York State Ambient Air Quality Standards

TABLE 9A-4 Attainment Status of the Project Areas

TABLE 9A-5 Ambient Air Quality Data for the Project Areas

TABLE 9A-6 Project Construction Emissions in the New York-New Jersey-Long Island, NY-

NJ-CT O3 Nonattainment Area

TABLE 9A-7 Project Construction Emissions in Attainment Areas

TABLE 9A-8 Operational Emissions Summary - Natural Gas Releases

TABLE 9A-9 Hourly Operational Emissions Summary (Excludes Natural Gas Releases)

TABLE 9A-10 Annual Operational Emissions Summary (Excludes Natural Gas Releases)

TABLE 9A-11 Compressor Station AERSCREEN / AERMOD Modeling Results

TABLE 9A-12 Noise Quality Analysis for the Proposed Highland CS

TABLE 9A-13 Noise Quality Analysis for the Modified Hancock CS

TABLE 9A-14 Noise Quality Analysis for the Modified Ramapo M&R

TABLE 9A-15 Noise Quality Analysis for the Modified Huguenot M&R

APPENDIX 9B Construction Emission Calculations

APPENDIX 9C Air Permit Applications

APPENDIX 9D Air Quality Modeling Assessments

APPENDIX 9E HDD Construction Noise Assessment (Eastern System Upgrade)

APPENDIX 9F Highland Compressor Station Ambient Sound Survey and Noise Impact Analysis

(Eastern System Upgrade)

APPENDIX 9G Hancock Compressor Station Noise Impact Analysis (Eastern System Upgrade)

APPENDIX 9H Ramapo Meter Station Pre-Construction Sound Survey and Noise Impact Analysis


Resource Report 9 - Air and Noise Quality iii Eastern System Upgrade

APPENDIX 9I Huguenot M&R Station Ambient Sound Survey and Noise Impact Analysis (Eastern

System Upgrade)

VOLUME IV-B - CRITICAL ENERGY INFRASTRUCTURE INFORMATION

APPENDIX 9J Noise Analysis Plot Plans

Resource Report 9 - Air and Noise Quality iv Eastern System Upgrade

RESOURCE REPORT 9 – AIR AND NOISE QUALITY

Filing Requirement Location in

Environmental Report

Describe existing air quality, including background levels of nitrogen dioxide

and other criteria pollutants which may be emitted above EPA-identified

significance levels. (18 CFR § 380.12(k)(1))

Section 9.1.1

Quantitatively describe existing noise levels at noise-sensitive areas, such as

schools, hospitals, or residences and include any areas covered by relevant

state or local noise ordinances. (18 CFR § 380.12 (k)(2)).

(i) Report existing noise levels as the Leq (day), Leq (night), and Ldn and

include the basis for the data or estimates.

(ii) For existing compressor stations, include the results of a sound level

survey at the site property line and nearby noise-sensitive areas while

the compressors are operated at full load.

(iii) For proposed new compressor station sites, measure or estimate the

existing ambient sound environment based on current land uses and

activities.

(iv) Include a plot plan that identifies the locations and duration of noise

measurements, the time of day, weather conditions, wind speed and

direction, engine load, and other noise sources present during each

measurement.

Section 9.2 and Appendices

9F through 9H

Estimate the impact of the project on air quality, including how existing

regulatory standards would be met. (18 CFR § 380.12(k)(3))

(i) Provide the emission rate of nitrogen oxides from existing and proposed

facilities, expressed in pounds per hour and tons per year for maximum

operating conditions, include supporting calculations, emission factors,

fuel consumption rates, and annual hours of operation.

(ii) For major sources of air emissions (as defined by the Environmental

Protection Agency), provide copies of applications for permits to

construct (and operate, if applicable) or for applicability determinations

under regulations for the prevention of significant air quality

deterioration and subsequent determinations.

Sections 9.1.2 and 9.1.3

Appendix 9C

Resource Report 9 - Air and Noise Quality v Eastern System Upgrade

RESOURCE REPORT 9 – AIR AND NOISE QUALITY

Filing Requirement Location in

Environmental Report

Provide a quantitative estimate of the impact of the project on noise levels at

noise-sensitive areas, such as schools, hospitals, or residences. (18 CFR §

380.12(k)(4))

(i) Include step-by-step supporting calculations or identify the computer

program used to model the noise levels, the input and raw output data

and all assumptions made when running the model, far-field sound level

data for maximum facility operation, and the source of the data.

(ii) Include sound pressure levels for unmuffled engine inlets and exhausts,

engine casings, and cooling equipment; dynamic insertion loss for all

mufflers; sound transmission loss for all compressor building

components, including walls, roof, doors, windows and ventilation

openings; sound attenuation from the station to nearby noise-sensitive

areas, the manufacturer’s name, the model number, the performance

rating; and a description of each noise source and noise control

component to be employed at the proposed compressor station. For

proposed compressors the initial filing must include at least the

proposed horsepower, type of compression, and energy source for the

compressor.

Section 9.2 and Appendices

9E through 9H

(iii) Far-field sound level data measured from similar units in service

elsewhere, when available, may be substituted for manufacturer's far-

field sound level data.

(iv) If specific noise control equipment has not been chosen, include a

schedule for submitting the data prior to certification.

(v) The estimate must demonstrate that the project will comply with

applicable noise regulations and show how the facility will meet the

following requirements:

(A) The noise attributable to any new compressor station, compression

added to an existing station, or any modification, upgrade or update

of an existing station, must not exceed a day-night sound level

(Ldn) of 55 dBA at any pre-existing noise-sensitive area (such as

schools, hospitals, or residences).

(B) New compressor stations or modifications of existing stations shall

not result in a perceptible increase in vibration at any noise sensitive

area.

Describe measures and manufacturer’s specifications for equipment proposed

to mitigate impact to air and noise quality, including emission control

systems, installation of filters, mufflers, or insulation of piping and buildings,

and orientation of equipment away from noise-sensitive areas.

(18 CFR § 380.12(k)(5))

Sections 9.1.3

and 9.2.5

Resource Report 9 - Air and Noise Quality vi Eastern System Upgrade

FERC COMMENTS ON

DRAFT RESOURCE REPORT 9

LOCATION OR

RESPONSE TO COMMENT

JULY 1, 2016 COMMENTS

Resource Report 9 – Air and Noise Quality

1. Revise Section 9.1.2.2 to clearly identify permitting

requirements for the aboveground facilities, explaining which

New York State Department of Environmental Conservation

permits are equivalent to major New Source Review, minor

New Source Review, or other state level air permits. Note,

only those emission sources subject to major or minor New

Source Review are exempt from general conformity.

The NYSDEC permitting requirements and

an assessment of major and minor NSR

applicability are included in the revised

Section 9.1.2.2.

2. Include a discussion on the Project's applicability for the

Greenhouse Gas Mandatory Reporting Rule.

A discussion of the Greenhouse Gas

Mandatory Reporting Rule is included in

Section 9.1.2.8.

3. Clarify the discrepancy in the acres affected for fugitive dust

emissions in tables 9.B.2.1 through 9.B.2.2 and the land

requirements in Tables 1.4-1 and 1.4-2. Revise the

calculations if necessary, based on any revised values

The acres affected for fugitive dust

emissions in tables 9.B.2.1 and 9.B.2.2

include the land requirements for the

Huguenot Loop (159.07 acres from Table

1.4-1), and the land requirements for the

Wagoner Interconnect, Huguenot M&R,

Westtown M&R, Wagoner Interconnect

PAR 13, Pig Launcher / Receiver, and

Alternate Interconnect (5.15 acres from

Table 1.4-2), which results in a total of

164.2 acres affected, and corresponds with

the total acres affected in Tables 9.B.2.1 and

9.B.2.2.

4. Update Table 9A-8, and any other emission estimates of

natural gas releases to include hazardous air pollutants (i.e.

some volatile organic compounds may also be hazardous air

pollutants).

The VOCs that may be emitted during

natural gas releases (i.e., propane and

butane) are not considered Hazardous Air

Pollutants (HAPs). Per the gas analysis

provided in Appendix 9C, there are no

constituents in the natural gas that are

considered to be HAPs.

5. Indicate whether Millennium is, or plans to be, a participating

member of the US EPA's Natural Gas STAR Program or

Methane Challenge Program and discuss the scope of the

participation. In addition

Millennium does not plan to be a

participating member of the USEPA’s

Natural Gas STAR Program as participation

within this program is already covered by

Millennium’s operating company.

Millennium’s pipeline is operated by

Columbia Gas Transmission, L.L.C. On

July 1, 2016, TransCanada Corporation

acquired Columbia Pipeline Group, Inc.

TransCanada is a partner in the International

Sector of the STAR program and Methane

Challenge.

Resource Report 9 - Air and Noise Quality vii Eastern System Upgrade

FERC COMMENTS ON


LOCATION OR

RESPONSE TO COMMENT


a. indicate if Millennium would install specific equipment to

reduce fugitive methane emissions identified in EPA's

Natural Gas STAR recommended technologies, by state

agencies, or in peer-reviewed studies; and

Millennium does not plan to be a partner

(i.e., participating member) of the EPA

Natural Gas STAR program, however, to

the extent practical and in accordance with

40 CFR Part 60 Subparts OOOOa will

install equipment to minimize fugitive

methane emissions.

b. discuss how Millennium would identify leaking valves,

seals, or other equipment on the pipeline compressor

facilities, and the criteria for repair/replacement.

Millennium will comply with 40 CFR Part

60 Subpart OOOOa – Standards of

Performance for Crude Oil and Natural Gas

Production, Transmission and Distribution,

as codified in the Final Rule 81 FR 35824

June 3, 2016. Compliance with OOOOa

will identify leaking valves, seals and other

equipment at the compressor stations to

minimize fugitive methane emissions.

6. Provide an air quality screening (AERSCREEN) or refined

analysis (AERMOD or EPA-approved alternative) analysis of

the Highland Compressor Station identifying the air quality

impact of criteria pollutants from the facility in comparison

with the National Ambient Air Quality Standards (NAAQS).

Provide all source input parameters (emission rate, stack

height, stack temperature, exit velocity, etc.), and justify the

bases for any assumptions. For any analysis using refined

modeling (AERMOD or another EPA-accepted model), you

should provide a description on how the modeling was

performed (for example, identify the specific model number,

meteorological data source, terrain data, source parameters,

building information, receptor grids, NO2/NOX conversion,

post-processing assumptions, etc.). You should also provide

the input and output files in a form such that staff or staff

contractors can reproduce the analysis (these may need to be

submitted as text files for compatibility with eLibrary).

A refined air quality modeling assessment

of the Highland Compressor Station is

included as Appendix 9D and summarized

in Section 9.1.3.2. The input and output

files have been included as text files in

Appendix 9C as part of the NYSDEC Air

Permit Application for the Highland

Compressor Station.

7. Provide an air quality screening (AERSCREEN) or refined

analysis (AERMOD or EPA-approved alternative) of the

Hancock Compressor Station identifying the incremental

increase in air quality impact of criteria pollutants from the

entire facility in comparison with the NAAQS. This modeling

should:

A refined air quality modeling assessment

of the Hancock Compressor Station is

included as Appendix 9D and summarized

in Section 9.1.3.2. The input and output

files have been included as text files in

Appendix 9C as part of the NYSDEC Air

Permit Application for the Hancock

Compressor Station. a. identify existing emission rates of criteria pollutants from

the station, and provide modeling results to identify

existing local impact levels of criteria pollutants; and

b. identify proposed emission rates of criteria pollutants from

the station and provide modeling results to identify the

local impacts of the new turbines in addition to the existing

equipment at the compressor station.

Resource Report 9 - Air and Noise Quality viii Eastern System Upgrade

FERC COMMENTS ON


LOCATION OR

RESPONSE TO COMMENT


Provide all source input parameters (emission rate, stack

height, stack temperature, exit velocity, etc.), and justify

the bases for any assumptions. Provide a description on

how the modeling was performed (for example, identify

the specific model number, meteorological data source,

terrain data, source parameters, building information,

receptor grids, NO2/NOx conversion, post-processing

assumptions, etc.). Provide input data, as well as output

data showing maximum impacts outside the fence line (the

EPA-defined ambient air boundary), and at sensitive

receptors in the area (schools, hospitals, nursing homes,

etc.). Also provide the input and output files in a form

such that staff or staff contractors can reproduce the

analysis (these may need to be submitted as text files for

compatibility with eLibrary.

8. Clarify whether Millennium commits to implementing the

site-specific noise mitigation measures recommended in

appendix 9E in the event of overnight construction at HDD

#1, and for construction at HDD #2.

Millennium will commit to implementing

the site-specific noise mitigation measures

recommended in Appendix 9E in the event

of overnight construction at HDD #1 and or

construction at HDD #2

9. In section 9.2.4.1 clarify how vibration would be adequately

mitigated

Section 9.2.4

10. Revise Figure 3, "Proposed Hancock Compressor Station Plot

Plan," of appendix 9G to include a plot plan that depicts the

planned new compressor unit at the Hancock Compressor

Station; the current figure only depicts the existing Hancock

Compressor Station.

Appendix 9G includes three Noise

Assessment Reports for the Hancock CS: 1)

2012 pre-construction, 2) 2014 post-

construction, 3) 2016 proposed

modifications. Figure 3 of the 2016 report

depicts the planned new compressor unit at

the Hancock CS.

Resource Report 9 - Air and Noise Quality ix Eastern System Upgrade

LIST OF ACRONYMS AND ABBREVIATIONS

6 NYCRR Title 6 of the New York Code of Rules and Regulations

AGC Annual Guideline Concentrations

AQCR air quality control region

CAA Clean Air Act

CFR Code of Federal Regulations

CH4 methane

CO carbon monoxide

CO2 carbon dioxide

CO2e carbon dioxide equivalents

dB decibel

dBA “A” weighting frequency scale

FERC or Commission Federal Energy Regulatory Commission

Hancock CS Hancock Compressor Station

HAP hazardous air pollutant

HDD Horizontal Directional Drill

Highland CS Highland Compressor Station

H&K Hoover and Keith, Inc.

Hp horsepower

Huguenot M&R Huguenot Meter Station

Ldn Day-Night Level

Leq Equivalent Sound Level

m3 cubic meters

Millennium Millennium Pipeline Company, L.L.C.

MMBtu/hr million British thermal units per hour

MOVES 2014 Mobile Vehicle Emissions Simulator, version 2014

MP milepost

NAAQS National Ambient Air Quality Standards

NO2 nitrogen dioxide

NOx nitrogen oxides

NSA Noise Sensitive Area

NSPS New Source Performance Standards

Resource Report 9 - Air and Noise Quality x Eastern System Upgrade

NSR New Source Review

NYNAAQS New York NAAQS

NYSDEC New York State Department of Environmental Conservation

O3 ozone

OTR Ozone Transport Region

Pb lead

PM particulate matter

PM10 particulate matter with a diameter ≤ 10 microns

PM2.5 particulate matter with a diameter ≤ 2.5 microns

ppmvd @ 15% O2 parts per million by volume at 15% oxygen

Project Eastern System Upgrade

PSD Prevention of Significant Deterioration

Ramapo M&R Ramapo Meter Station

RICE reciprocating internal combustion engines

RMP risk management plan

SGC Short-term Guideline Concentrations

SIP State Implementation Plan

SO2 sulfur dioxide

TAP Toxic air pollutants

Tpy tons per year

USDOT United States Department of Transportation

USEPA United States Environmental Protection Agency

VOC volatile organic compounds

Westtown M&R Westtown Meter Station

Resource Report 9 - Air and Noise Quality 9-1 Eastern System Upgrade

9.0 RESOURCE REPORT 9 - AIR AND NOISE QUALITY

Millennium Pipeline Company, L.L.C. (Millennium) is seeking authorization from the Federal Energy

Regulatory Commission (FERC or Commission) pursuant to Section 7(c) of the Natural Gas Act to

construct, install, operate, and maintain the Eastern System Upgrade (Project). The Project includes

construction of approximately 7.8 miles of 30- and 36-inch pipeline loop in Orange County, New York

(Huguenot Loop). Millennium proposes to locate a majority of the pipeline loop overlapping with and

adjacent to the permanent easement associated with its existing mainline (Millennium Pipeline).

Additionally, as part of the Project, Millennium proposes to construct and operate (1) a new compressor

station (Highland CS) in Sullivan County, New York, (2) additional horsepower (hp) at the existing

Hancock Compressor Station (Hancock CS) in Delaware County, New York, (3) modifications to the

existing Ramapo Meter and Regulator Station (Ramapo M&R) in Rockland County, New York, (4)

modifications to the existing Wagoner Interconnect in Orange County, New York and (5) additional

pipeline appurtenant facilities at the existing Huguenot Meter Station (Huguenot M&R) and Westtown

Meter Station (Westtown M&R) in Orange County, New York. Dependent upon receipt of necessary

approvals, construction of the Project would be anticipated to commence in the fall of 2017 to meet a target

in-service date in September 2018.

The Project consists of the following components and facilities:

approximately 7.8 miles of new 30- and 36-inch diameter pipeline looping generally overlapping

with and adjacent to Millennium’s existing pipeline right-of-way in Orange County, New York

(Huguenot Loop);

construction and operation of a new 22,400 hp compressor station, Highland CS in Sullivan County,

New York;

construction and operation of an additional 22,400 hp at the existing Hancock CS in Delaware

County, New York;

modifications to the Ramapo M&R in Rockland County, New York;

modifications to the Wagoner Interconnect in Orange County, New York;

addition of pipeline appurtenant facilities, which includes pigging facilities, at the Huguenot M&R

and the Westtown M&R in Orange County, New York; and

addition of an alternate interconnect to the 16-inch Valley Lateral at milepost (MP) 7.6.

Resource Report 9 describes the existing air and noise quality within the vicinity of the Project areas, the

potential impacts on air and noise quality associated with construction and operation of the Project, and the

proposed measures to avoid or minimize those impacts. A description of the Project components is included

in Resource Report 1, Section 1.3.2 and Table 1.3-3.

Table 9.0-1, below, summarizes the compressor units at each compressor station.


TABLE 9.0-1 Project Compressor Station Summary

Station and Unit

Manufacturer and Model No.

Type/Energy Source

Rated Output (hp)

Existing Proposed Removal

Proposed Addition

Proposed Total

Highland CS

Unit 1 Solar Turbines Titan 130E CT / NG N/A N/A 22,400 22,400

Total N/A N/A 22,400 22,400

Hancock CS

Unit 1 Solar Turbines Mars 100 CT / NG 15,900 N/A N/A 15,900

Unit 2 Solar Turbines Titan 130E CT / NG N/A N/A 22,400 22,400

Total 15,900 N/A 22,400 38,300

Notes: CT = Combustion Turbine NG = Natural Gas N/A – not applicable

9.1 AIR QUALITY

9.1.1 Existing Conditions

Climate

The Project would be located in south-central New York State. The climate is humid continental in

character, but is modified by the Atlantic Ocean, with cold winter temperatures, hot summers and ample

precipitation throughout the year. However, annual precipitation amounts can vary greatly year to year.

The regional climate can be represented by National Climatic Data Center data for Avoca, Pennsylvania,

which is located approximately 50 miles west of the Project. Table 9A-1 provides climate data for Avoca.

The wind is most often out of the southwest, northwest, and north. The wind is least often out of the

southeast.

National Ambient Air Quality Standards

The United States Environmental Protection Agency (USEPA) has promulgated National Ambient Air

Quality Standards (NAAQS). The NAAQS include primary standards, which are designed to protect

human health, including the health of sensitive subpopulations such as children and those with chronic

respiratory problems, and secondary standards, which are designed to protect public welfare, including

economic interests, visibility, vegetation, animal species, and other concerns. The current NAAQS apply

to the following criteria pollutants:

particulate matter with a diameter ≤ 10 microns (PM10)

particulate matter with a diameter ≤ 2.5 microns (PM2.5)

nitrogen dioxide (NO2)


sulfur dioxide (SO2)

carbon monoxide (CO)

ozone (O3)

lead (Pb)

Each NAAQS is expressed in terms of a pollutant concentration level and an associated averaging period.

The current NAAQS are summarized in Table 9A-2. Notes to Table 9A-2 list the form of the statistic used

to assess compliance with each NAAQS.

New York State Ambient Air Quality Standards

States may adopt standards that are more stringent or encompassing than the NAAQS. The New York State

Department of Environmental Conservation (NYSDEC) has established New York State Ambient Air

Quality Standards for SO2, particulate matter (PM), NO2, CO, photochemical oxidants, non-methane

hydrocarbons, fluorides, beryllium, and hydrogen sulfide. These are listed in Title 6 of the New York Code

of Rules and Regulations (6 NYCRR) Part 257 and summarized in Table 9A-3.

Attainment Status

Section 107 of the Clean Air Act (CAA) directs the USEPA to designate air quality control regions (AQCR)

for any interstate area or major intrastate area which it deems necessary or appropriate. An implementation

plan is developed for each AQCR describing how ambient air quality standards will be achieved and/or

maintained. For each applicable pollutant and averaging period, USEPA designates an area’s attainment

status based on monitoring data from the region. Areas that meet the NAAQS are termed “attainment

areas.” Areas that do not meet the NAAQS are termed “nonattainment areas.” Areas for which insufficient

data are available to determine attainment status are termed “unclassifiable areas.” Areas formerly

designated as nonattainment that subsequently reached attainment are termed “maintenance areas.” The

attainment status designations appear in Title 40 of the Code of Federal Regulations (CFR) Part 81.

The Project would be located in the following:

Huguenot Loop, Huguenot M&R, and Westtown M&R (Orange County) - AQCR 161 (Hudson

Valley Intrastate AQCR)

Highland CS (Sullivan County) and Hancock CS (Delaware County) - AQCR 163 (Southern Tier

East Intrastate AQCR)

Ramapo M&R (Rockland County) - AQCR 43 (New Jersey-New York-Connecticut Interstate

AQCR)

Table 9A-4 summarizes the attainment status of the Project areas.


Ambient Air Quality in the Project Area

Pollutant concentration data to characterize air quality in the Project areas were obtained from the USEPA

AIRDATA database. Typically, the monitoring station nearest a project is used for this purpose. The

Project site is located inland in a semi-rural area at least 50 miles from the nearest seacoast. Therefore, for

some pollutants, more representative inland monitoring stations situated more distant from the Project areas

are used in lieu of closer monitoring stations situated in New York City or the northern New Jersey

communities located near the coast. Ambient air quality monitoring data for the most recent available

three-year period are summarized in Table 9A-5.

9.1.2 Regulatory Requirements

General Conformity

Section 176(c) of the CAA prohibits federal agencies from taking actions which do not conform to the State

Implementation Plan (SIP) for the attainment and maintenance of the NAAQS. The purposes of conformity

are to (1) ensure federal activities do not interfere with the emissions budgets in the SIPs, (2) ensure actions

do not cause or contribute to new violations, and (3) ensure attainment and maintenance of the NAAQS.

General conformity applies only in areas that are designated as NAAQS nonattainment areas or

maintenance areas, and a conformity review is required only for those pollutants designated as

nonattainment or maintenance pollutants. A general conformity analysis must consider both direct and

indirect emissions. Direct emissions are those that occur as a direct result of the action, and occur at the

same time and place as the action. Indirect emissions are those that occur at a later time or distance from

the place where the action takes place, but may be reasonably anticipated as a consequence of the proposed

action.

Some emissions are excluded from the conformity determination, such as those already subject to federal

New Source Review (NSR), those from the type of action included in the SIP, those covered by the

Comprehensive Environmental Response, Compensation, and Liability Act or compliance with other

environmental laws, actions not reasonably foreseeable, and those for which the Agency has no continuing

program responsibility. If the sum of the proposed action’s direct and indirect emissions that would

otherwise be subject to a conformity determination are less than de minimis levels, the proposed actions are

not subject to general conformity.

The Ramapo M&R will be located in New York-New Jersey-Long Island, NY-NJ-CT nonattainment area,

a marginal nonattainment for the 8-hour O3 (2008) standards and in the Ozone Transport Region (OTR).

The de minimis emission rate thresholds for general conformity in such an area are 100 and 50 tons per year

(tpy) of, respectively, nitrogen oxides (NOx) and volatile organic compounds (VOC). As is shown in Table

9A-6, the annual Project construction emission rates in this nonattainment area are far less than these

thresholds.

The Huguenot Loop, Huguenot M&R, and Westtown M&R are located in Orange County, New York. The

Ramapo M&R is located in Rockland County, New York. On April 18, 2014 USEPA published in the

Federal Register a notice approving the re-designation certain counties, including Orange County and


Rockland County, from nonattainment to attainment for the PM2.5 annual and 24-hour NAAQS. USEPA

also approved New York State’s SIP revision containing a maintenance plan for the affected counties. The

de minimis emission rate thresholds for general conformity in such a maintenance area are 100 of PM2.5 or

any of its precursors (SO2 and possibly NOx, VOCs, and/or ammonia). As is shown in Tables 9A-6 and

9A-7, the annual Project construction emission rates of PM2.5 and its possible precursors are far less than

this threshold.

The remaining Project facilities are located in areas designated as attainment or the equivalent. As such, the

Project is not subject to general conformity.

New Source Review

Preconstruction air permitting programs that regulate the construction of new stationary sources of air

pollution and the modification of existing stationary sources are commonly referred to as NSR. NSR can

be divided into major NSR and minor NSR. Major NSR is comprised of the Prevention of Significant

Deterioration (PSD) and the Nonattainment New Source Review permitting programs. Major NSR

requirements are established on a federal level but may be implemented by state or local permitting

authorities under either a delegation agreement with USEPA or as a SIP program approved by USEPA.

NYSDEC administers its major NSR permitting program through 6 NYCRR Part 231, which establishes

preconstruction, construction, and operation requirements for new and modified sources. Non-major

facilities that meet the criteria of 6 NYCRR 201-4 can register under NYSDEC's permitting program rather

than obtain a permit. Pursuant to 6 NYCRR 201-3.2(c)(1)(i), natural gas-fired heaters with a maximum

rated heat input capacity less than 10 million British thermal units per hour (MMBtu/hr) are exempt from

requirements to obtain a minor facility registration.

The State of New York’s major source operating permit program is administered through a USEPA-

approved program at 6 NYCRR 201-6. NYSDEC also administers a state operating permit program

through 6 NYCRR 201-5 for certain non-major facilities that do not qualify for a minor facility registration

under 6 NYCRR Subpart 201-4, including synthetic minor facilities and facilities with actual emissions

greater than fifty percent of Title V major source thresholds. Emission sources or activities listed under

NYCRR 201-3 are exempt from the registration and permitting provisions of 6 NYCRR Subparts 201-4,

201-5, and 201-6.

The NSR permit status for Project facilities is as follows:

The Ramapo M&R is an existing non-major facility that was originally permitted by Algonquin

under and operates according to Air State Facility Permit ID: 3-3922-00204/00001. Millennium

proposes to modify its existing Ramapo M&R Station, and the modifications will include a new

natural gas-fired inlet gas heater. The inlet gas heater is currently expected to exceed a maximum

rated heat input capacity of 10 MMBtu/hr and is therefore expected to be subject to permitting by

Algonquin under 6 NYCRR Subpart 201-4. Upon finalization of the station design information,

Millennium will file the appropriate minor source NSR application with the NYSDEC by October

2016.


The Hancock CS is an existing non-major facility that operates according to Air State Facility

Permit ID: 4-1236-00708/00001. The proposed Project involves the installation of new emission

units at an existing minor source with respect to NSR permitting requirements at 6 NYCRR Part

231 and Title V major source permitting requirements at 6 NYCRR Part 201-6. With the addition

of the new emission units, the facility wide potential to emit for one or more criteria air pollutants

will exceed the Title V major source permitting thresholds. As such, Millennium submitted an

initial major source Title V permit application for the modifications to the Hancock Compressor

Station to the NYSDEC in July 2016. A copy of the Title V permit application is provided in

Appendix 9C.

The Highland CS is a proposed new non-major facility. The proposed Project involves the

installation of new emission units that will be considered a minor source with respect to NSR

permitting requirements at 6 NYCRR Part 231 and Title V major source permitting requirements

at 6 NYCRR Part 201-6. As such, Millennium submitted an initial minor source State Facility air

permit application for the new Highland Compressor Station to the NYSDEC in July 2016. A copy

of the application for a permit to construct is provided in Appendix 9C.

Class I Areas

Federal Class I areas are areas established by Congress, such as wilderness areas and national parks, that

are afforded special protection under the Clean Air Act. Class I areas are allowed the smallest degree of

air quality deterioration through major NSR permitting and special considerations must be made during the

PSD permitting process when a Class I area is located close to a proposed site. If a proposed facility does

not require PSD review, Class I modeling is not required regardless of the Project’s distances from the Class

I areas. The Project facilities are not subject to PSD review, and hence not subject to Class I modeling.

Title V Operating Permit and State Operating Permit Programs

The Title V permit program in 40 CFR Part 70 requires major sources of air pollutants to obtain federal

operating permits. The major source thresholds under the Title V program, as defined in 40 CFR 70.2 and

which are different from the federal NSR major source thresholds, are 100 tpy of any air pollutant, 10 tpy

of any single hazardous air pollutant (HAP), or 25 tpy of total HAPs. More stringent Title V major source

thresholds apply for VOC and NOx in ozone nonattainment areas, namely 50 tpy of VOC or NOx in areas

defined as serious, 25 tpy in areas defined as severe, and 10 tpy in areas classified as extreme.

The State of New York’s Title V Operating Permit Program is administered through a USEPA-approved

program at 6 NYCRR 201-6. NYSDEC also administers a state operating permit program through 6

NYCRR 201-5 for certain non-Title V facilities that do not qualify for a minor facility registration under 6

NYCRR Subpart 201-4, including synthetic minor facilities and facilities with actual emissions greater than

fifty percent of Title V thresholds. Emission sources or activities listed under NYCRR 201-3 are exempt

from the registration and permitting provisions of 6 NYCRR Subparts 201-4, 201-5, and 201-6. Millennium

submitted an application for an Air Title V Facility permit for the Hancock CS and a new State Facility air

permit application for the Highland CS in July 2016


Standards of Performance for New Stationary Sources

New Source Performance Standards (NSPS) in 40 CFR Part 60 regulate certain emissions from specific

source categories. The applicability to the Project of several NSPS is discussed below.

40 CFR Part 60 Subpart Dc (Standards of Performance for Small Industrial-Commercial-Institutional Steam

Generating Units)

Subpart Dc applies to steam generating units, as defined in 40 CFR 60.41c, with a maximum design heat

input capacity of greater than or equal to 10 MMBtu/hr but less than or equal to 100 MMBtu/hr for which

construction, modification, or reconstruction is commenced after June 9, 1989. There are no subject steam

generating units with a maximum design heat input capacity of greater than or equal to 10 MMBtu/hr

proposed for any Project facilities. Therefore, this subpart will not apply.

40 CFR Part 60 Subpart Kb (Standards of Performance for Volatile Organic Liquid Storage Vessels

(Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification

Commenced After July 23, 1984)

Subpart Kb potentially applies to storage vessels with a capacity greater than 75 cubic meters (m3) (19,813

gallons) that will store volatile organic liquids. Tanks with a capacity greater than 75 m3 are not proposed

to be constructed, reconstructed, or modified at any Project facilities. Therefore, this subpart will not apply.

40 CFR Part 60 Subpart JJJJ (Standards of Performance for Stationary Spark Ignition Internal Combustion

Engines)

Subpart JJJJ, applies to an owner or operator of a new or existing stationary spark ignition internal

combustion engine that commence construction, modification, or reconstruction after June 12, 2006. The

Project includes new emergency stationary spark ignition internal combustion engine greater than 25 hp at

the Hancock and Highland Compressor Stations. Therefore, requirements of Subpart JJJJ will apply to the

proposed Project.

40 CFR Part 60 Subpart KKKK (Standards of Performance for Stationary Combustion Turbines)

Subpart KKKK applies to stationary combustion turbines with a heat input rate at peak load of 10

MMBtu/hr or greater that commenced construction, modification, or reconstruction) after February 18,

2005. Subpart KKKK limits emissions of NOx as well as the sulfur content of fuel that is combusted by

subject units. The Project involves the installation of new stationary combustion turbines at Hancock CS

and Highland CS. These new combustion turbines will be subject emissions limitations and the monitoring,

reporting, recordkeeping, and testing requirements under this subpart.

40 CFR Part 60 Subpart OOOO (Standards of Performance for Crude Oil and Natural Gas Production,

Transmission and Distribution)

Subpart OOOO applies to affected facilities that commence construction, reconstruction, or modification

after August 23, 2011. Affected facilities include the following:

Hydraulically fractured natural gas wells.


Centrifugal and reciprocating compressors.

Continuous bleed pneumatic controllers.

Storage vessels with potential VOC emissions of 6 tpy or greater.

Fugitive equipment components at onshore natural gas processing plants.

Sweetening units at onshore natural gas processing plants.

The Project will not include natural gas wells or natural gas processing plants. Centrifugal and reciprocating

compressors and continuous bleed gas driven pneumatic controllers located at the transmission facilities

(e.g., compressor stations) are not subject to Subpart OOOO. The Project’s compressor stations will not

use continuous bleed pneumatic controllers or storage vessels with potential VOC emissions of 6 tpy or

greater. Therefore, the Project will not be subject to this regulation.

40 CFR Part 60 Subpart OOOOa (Oil and Natural Gas Sector: Emission Standards for New and Modified

Sources)

On August 18, 2015, USEPA proposed amendments to 40 CFR 60, Subpart OOOO and proposed an entirely

new Subpart OOOOa. Based on the effective date of August 2, 2016 for the new Subpart, the Project will

be required to comply with the requirements of NSPS Subpart OOOOa. While storage tanks remain

covered, Subpart OOOOa also includes provisions intended to reduce emissions from compressors and

equipment leaks at compressor stations. For equipment leaks, Subpart OOOOa proposes requiring periodic

surveys using optical gas imaging (OGI) technology and subsequent repair of any identified leaks. The

Project will comply with all applicable leak detection provisions of proposed Subpart OOOOa.

National Emission Standards for Hazardous Air Pollutants

The USEPA has established National Emission Standards for Hazardous Air Pollutants (NESHAP) for

specific pollutants and industries in 40 CFR Part 61. The Project does not include any of the specific

sources for which NESHAP have been established in Part 61. Therefore, Part 61 NESHAP requirements

will not apply to the Project. The USEPA has also established NESHAP requirements in 40 CFR Part 63

for various source categories. The Part 63 NESHAP apply to certain emission units at facilities that are

major sources of HAP. The applicability to the Project of several NESHAP rules is discussed below.

40 CFR Part 63 Subpart HHH (National Emission Standards for Hazardous Air Pollutants from Natural

Gas Transmission and Storage Facilities)

Subpart HHH applies to natural gas transmission and storage facilities that are major sources of HAPs and

that transport or store natural gas prior to entering the pipeline to a local distribution company or to a final

end user (if there is no local distribution company). All Project facilities are area sources (i.e., not major

sources) of HAPs. Therefore, this subpart will not apply because it only applies to major sources.


40 CFR Part 63 Subpart YYYY (National Emission Standards for Hazardous Air Pollutants for Stationary

Combustion Turbines)

Subpart YYYY applies to stationary combustion turbines at major sources of HAPs. Emissions and

operating limitations under Subpart YYYY apply to new and reconstructed stationary combustion turbines.

All Project facilities are area sources (i.e., not major sources) of HAPs. Therefore, this subpart will not

apply because it only applies to major sources.

40 CFR Part 63 Subpart ZZZZ (National Emission Standards for Hazardous Air Pollutants for Stationary

Reciprocating Internal Combustion Engines)

Subpart ZZZZ, applies to existing, new, and reconstructed stationary reciprocating internal combustion

engines (RICE) depending on size, use, and whether the engine is located at a major or area source of HAP.

The Project includes the installation of one new emergency stationary RICE with a site rating greater than

500 hp at the Hancock and Highland Compressor Stations. New stationary RICE located at area sources

of HAP, such as the emergency engines proposed for the Project, must meet the requirements of Subpart

ZZZZ by meeting the NSPS. As discussed above in Section 9.1.2.5, the new emergency engines proposed

for these facilities are subject to the NSPS at 40 CFR Part 60, Subpart JJJJ, therefore the requirements of

Subpart ZZZZ will be met.

40 CFR Part 63 Subpart DDDDD (National Emission Standards for Hazardous Air Pollutants for Major

Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters)

Subpart DDDDD applies to certain new and existing boilers and process heaters at major HAP sources. All

Project facilities are area sources (i.e., not major sources) of HAPs. Therefore, this subpart will not apply

because it only applies to major sources.

40 CFR Part 63 Subpart JJJJJJ (National Emission Standards for Hazardous Air Pollutants for Industrial,

Commercial, and Institutional Boilers Area Sources)

Subpart JJJJJJ applies to certain new and existing boilers at area sources, where a boiler is defined as “an

enclosed device using controlled flame combustion in which water is heated to recover thermal energy in

the form of steam and/or hot water.” The rule does not apply to natural gas fired boilers and does not apply

to process heaters at area sources. All Project facilities are area sources of HAPs, and the Project does not

involve boilers. Therefore, this subpart will not apply.

Risk Management Program

40 CFR Part 68 is a federal regulation established to prevent the accidental release of hazardous substances

and minimize the impacts if releases occur. The regulation contains a list of substances and threshold

quantities. If a facility stores, handles, or processes a listed substance in an amount equal to or greater than

its threshold quantity, the facility must prepare and submit a risk management plan (RMP). If a facility

does not have a listed substance onsite, or the quantity of a listed substance is below the applicability

threshold, the facility is not required to prepare an RMP. However, it must still comply with requirements

of the general duty clause if it has any regulated substance or other extremely hazardous substance onsite.


Natural gas compressor stations, meter stations, and pipelines are not required to have an RMP because

they are regulated by the U.S. Department of Transportation (USDOT) or an equivalent state natural gas

program certified by USDOT in accordance with 49 U.S.C. Part 6010-5. Because the Project will be

regulated by USDOT, an RMP is not required for any Project facilities.

Greenhouse Gas Mandatory Reporting Rule

The GHG Mandatory Reporting Rule, at 40 CFR Part 98, requires certain facilities that emit 25,000 metric

tons or more of CO2e per year to report annual emissions of specified GHGs from various processes within

the facility and conduct associated monitoring. Compressor stations include source types that are subject

to the GHG Mandatory Reporting Rule: Subpart C – General Fuel Combustion Sources, which became

effective on December 29, 2009, and Subpart W – Petroleum and Natural Gas Systems, which became

effective on December 30, 2010. The GHG Mandatory Reporting Rule is managed directly by the USEPA

and not through a source’s Title V permit. The Hancock and Highland Compressor Stations associated

with the Project will be required to report GHG emissions under this rule.

9.1.3 Air Quality Impacts

Project Construction

Construction emissions will include the following:

Exhaust emissions from construction equipment and vehicles;

Emissions from vehicles used for transporting construction workers and delivering equipment and

materials to the Project site; and

Fugitive dust from construction activities and wind erosion of disturbed areas prior to revegetation.

Calculations for construction emissions were performed using the following EPA modeling and data

resources in order of precision: (1) Motor Vehicle Emission Simulator, (2) NONROAD model, and (3) AP

42, Compilation of Air Pollutant Emission Factors. Tables 9A-6 and 9A-7 summarize the estimated air

emissions that will result from construction of the Project. Appendix 9B provides detailed emissions

calculations. The following methodologies were used to estimate construction emissions:

Emission factors (grams per vehicle mile traveled) for NOx, CO, PM10, PM2.5, SO2, VOC, HAPs,

and carbon dioxide equivalents (CO2e) for on-road vehicles in New York State during 2017 and

2018 were obtained from the USEPA Mobile Vehicle Emissions Simulator, version 2014 (MOVES

2014).

Annual average emission factors (grams per horsepower hour) for NOx, CO, PM, SO2, VOC1, and

carbon dioxide (CO2) for non-road equipment engines in New York State during 2017 and 2018

were obtained using the most recent version of USEPA’s NONROAD model (NONROAD, 2008a).

1 NONROAD does not provide VOC emission factors. Emission factors for total hydrocarbons were used as VOC surrogates.


Non-road equipment emission factors (grams per gallon of fuel) for CH4 and nitrous oxide were

obtained from the 2015 Climate Registry Default Emission Factors2, and apportioned based on CO2

emissions.

The NONROAD model does not provide factors for HAP emission from non-road equipment.

HAP emissions for combustion of diesel and natural gas in RICE were obtained from AP 423.

AP 42 does not provide emission factors for combustion of gasoline in reciprocating internal

combustion engines. HAP emissions were estimated by multiplying the HC emissions from

NONROAD multiplied by ratios of the HAPs to VOC for gasoline engines obtained from MOVES

2014.

Fugitive dust emissions were estimated using the methodology described in Section 3.4 of the

Western Regional Air Partnership Fugitive Dust Handbook4. Use of this methodology is

conservative, as the climates typical of most western states are more arid than in the Project areas.

The impacts of these emissions on air quality are expected to be minor. Construction emissions will be

intermittent, temporary, and local. Mitigation measures will include the following:

Low-sulfur diesel fuel will be used;

The construction equipment will comply with USEPA mobile source emissions performance

standards and will be properly maintained in accordance with manufacturer guidance and industry

best practices. Equipment will be operated on an as-needed basis, primarily during daylight hours5.

Equipment idling will be limited to the extent practical;

To the extent practicable, busses or vans will be used to transport construction workers to the job

site; and

Fugitive dust emissions will be mitigated by minimizing the extent of the areas disturbed,

application of dust suppressants, rinsing construction vehicles before they leave the work site, and

avoiding excessive vehicle speeds on unpaved roads. Disturbed areas will be appropriately

revegetated. Additionally, all areas disturbed by construction will be stabilized in accordance with

FERC’s Plan and Procedures6.

2 http://www.theclimateregistry.org/wp-content/uploads/2015/04/2015-TCR-Default-EF-April-2015-FINAL.pdf Accessed

3/1/2016. 3 AP 42, Fifth Edition Compilation of Air Pollutant Emission Factors, Volume 1: Stationary Point and Area Sources

https://www3.epa.gov/ttnchie1/ap42/ Accessed 3/1/2016. 4 WRAP Fugitive Dust Handbook, Countess Environmental, September 2006 5 The atmospheric stability conditions during daytime typically promote more rapid dispersion of pollutants than during nighttime. 6 Upland Erosion Control, Revegetation, and Maintenance Plan, FERC, May 2013

http://www.theclimateregistry.org/wp-content/uploads/2015/04/2015-TCR-Default-EF-April-2015-FINAL.pdf

https://www3.epa.gov/ttnchie1/ap42/


Project Operation

Natural Gas Releases

Natural gas releases included fugitive and vented emissions. Fugitive emissions are defined as those

emissions which do not pass through a stack, vent, or other functionally equivalent opening7, and include

natural gas leaks from valves, flanges, pumps, compressors, seals, connections, etc. Vented emissions are

defined as those emissions which pass through a stack, vent, or equivalent opening. A compressor may be

vented for startup, shutdown, maintenance, or for protection of gas seals from contamination. An individual

compressor or the entire station may be blown down (i.e., vented) for testing, or in the event of an

emergency.

Operational emission estimates associated with fugitive gas releases from the pipeline, valves, meter

stations, regulation facilities, and pig launcher/receivers along the pipeline, quantified in tpy as CH4 and as

greenhouse gases as CO2e are provided in Appendix 9C. The calculations in Appendix 9C are based on a

methodology described in Interstate Natural Gas Association of America guidelines8 and a recent analysis

of a Millennium Pipeline natural gas sample collected at the Minisink Compressor Station, which is also

included in Appendix 9C.

The calculations for operational vented emissions in Appendix 9C conservatively assume that the Hancock

CS and Highland CS each conduct two full-station blowdowns per year. Millennium is inserting valving

on the station blowdown piping at both the Hancock CS and the Highland CS to contain (not vent) almost

all of the gas normally vented during scheduled testing of the station blowdown. Additionally, Millennium

is implementing a new design on its gas seal compression system whereby electric pumps are being utilized

in place of pneumatic pumps to minimize unit blowdowns. Vented emissions are transmission quality

natural gas.

Other Operational Emissions

Estimated operational emissions, not including natural gas releases, from the compressor and meter stations,

expressed in pounds per hour and tpy are summarized in Tables 9A-9 and 9A-10, respectively. The

combustion turbines will be equipped with Solar’s dry low NOx emissions combustion system, known as

SoLoNOx. This is a lean-premixed combustion technology designed to ensure uniform air/fuel mixture and

to reduce formation NOx, CO, and unburned hydrocarbons without penalizing stability or transient

capabilities. Warrantied emissions during normal operation are as follows:

NOx - 15 parts per million by volume at 15% oxygen (ppmvd @ 15% O2)

CO - 25 ppmvd @ 15% O2

Unburned hydrocarbons - 25 ppmvd @ 15% O2 (as CH4)

7 40 CFR 52.21(b)(20) 8 Greenhouse Gas Emission Estimation Guidelines for Natural Gas Transmission and Storage, Volume 1 - GHG Emission

Estimation Methodologies and Procedures, Interstate Natural Gas Association of America, September 28, 2005


An ambient air quality analysis of the increase in emissions of criteria pollutants from the Highland and

Hancock Stations was performed using AERMOD. The AERMOD assessment utilized five (5) years

(2011–2015) of concurrent meteorological data collected from a meteorological tower at the Binghamton

Edwin A Link Field and from radiosondes launched from Albany, New York. Both the surface and upper

air sounding data were processed by the NYSDEC using AERMOD’s meteorological processor, AERMET

(version 15181). The results are summarized in Table 9A-11. The air quality modeling analysis of the

Hancock and Highland Compressor Stations is provided in Appendix 9D along with additional details on

the selection of representative monitoring sites for use as background and associated modeling inputs. An

electronic copy of the input and output files utilized in the modeling assessment is included in Appendix

9C as part of the air permit applications submitted to the NYSDEC (Appendix 9C).

Emissions Health Effect Evaluation

This section addresses the potential health effects of criteria and toxic air pollutants (TAP) emitted from

the natural gas-fired engines as well as the health effects related to releases of pipeline natural gas from

fugitive emissions and venting operations. As described above, Millennium is proposing to construct a new

Highland CS and to construct additional compression at the existing Hancock CS.

Combustion Emissions

Air emissions resulting from the operation of the compressor stations includes: exhaust emissions from

natural gas combustion from the combustion turbines and ancillary equipment; and emissions resulting

from releases of natural gas from fugitive emissions and from venting.

As outlined in the Ambient Air Quality Modeling Assessment (Appendix 9D), a modeling analysis

addressing criteria pollutants and TAP were performed for the Hancock CS and Highland CS in accordance

with NYSDEC’s Policy DAR-1 guidance. The criteria pollutants were compared against the applicable

NAAQS and New York Ambient Air Quality Standards (NYAAQS) standard, while the TAPs were

compared against NYSDEC’s Short-term and Annual Guideline Concentrations (SGCs and AGCs). The

primary NAAQS/NYAAQS standards have been set to protect human health, including the health of at-risk

populations such as people with pre-existing heart or lung disease (such as asthmatics), children and older

adults (USEPA, 2016). The SGCs are chosen to protect the general population from adverse acute one-

hour exposures, while the AGCs are chosen to protect against adverse chronic exposure and based upon the

most conservative (i.e., health protective) carcinogenic or non-carcinogenic annual exposure limit. When

an AGC is based upon carcinogenic effects, the concentration is equivalent to an excess, lifetime cancer

risk of one-in-one-million (NYSDEC, 2010).

As shown in Appendix 9D, Tables 3-5 (Highland CS) and 3-7 (Hancock CS), the maximum modeled air

quality concentrations of the criteria pollutants are well below the applicable NAAQS and NYAAQS

standards, even when combined with a representative background concentration. Therefore, there are no

expected health effects from the emission of criteria pollutants from the proposed compressor stations.


Maximum short-term and annual ground level concentrations of each toxic air pollutant were modeled as

described in Appendix 9D. Unit concentrations (ug/m3 per 1.0 g/s emitted) for the 1-hour and annual

averaging periods were calculated for the combustion turbines using AERMOD. The maximum toxic air

pollutant-specific emission rate was multiplied by the modeled unit concentration to determine the

maximum pollutant-specific concentration. Note that summing the individual maximum source

concentrations, regardless of time and location, provides a conservative estimate of the actual toxic air

pollutant concentrations resulting from the facility. As shown in Appendix 9D, Tables 3-6 (Highland CS)

and 3-8 (Hancock CS) all of the maximum modeled TAPs are well below the corresponding NYSDEC

SGC and AGC. Therefore, there are no expected health effects related to the emissions of TAPs from the

proposed compressor stations. The evaluation for the Hancock CS takes into account total facility

emissions from both the existing Solar Mars 100 and the addition of the Solar Titan 130E.

The results of this analysis are consistent with comprehensive risk assessments recently conducted by the

Center for Disease Control’s Agency for Toxic Substances Disease Registry (2011) in Georgia and by

FERC (2015) Dominion Transmission, Inc.’s New Market Project, approved by FERC on April 28, 2016,

which indicate that the air concentrations associated with natural gas pipeline compressor stations are not

considered a health concern.

Natural Gas Releases

Natural gas, comprised primarily of methane, is commonly found in nature mixed with other hydrocarbons

and varying amounts of contaminants. While the exact composition of natural gas is chiefly dependent

upon the geological source from which it was extracted, all gas must be processed to “pipeline quality”

before it is allowed into interstate transmission pipelines (Branosky et al., 2012; Moore et al., 2014). In

addition, interstate transmission pipelines interconnect with many other transmission pipeline systems,

developing a network that may cross various geological gas sources. Therefore, the resulting natural gas

in most transmission pipelines is well mixed and cannot be pinpointed to a single source.

The term “pipeline quality” is defined in each individual pipeline’s tariff9, and these definitions vary from

pipeline to pipeline. Gas quality terms and conditions of the pipeline’s tariff ensure the hydrocarbons and

contaminants are within acceptable limits for safe and efficient operation of the pipeline. At typical

interstate pipeline operating pressures and temperatures, “pipeline quality” natural gas remains in a gaseous

state and pipelines, distribution facilities, and end-user equipment are all designed to handle and burn this

gas. Individual pipelines may have different standards, practices, and enforcement mechanisms; however,

the specifications for gas quality should be based upon sound technical, engineering, and scientific

considerations. Columbia has specific Gas Quality Standards in place for its pipeline system. All gas

received by Columbia’s pipeline system must meet these standards regardless of the source of the gas.

Natural gas releases from compressor stations consist of hydrocarbons plus small amounts of nitrogen (N2)

and CO2. The hydrocarbons are comprised primarily of methane, plus small amounts of ethane, propane,

9 Millennium’s FERC Tariff, General Terms & Conditions Section 25.


butane, pentane, and hexane. Natural gas would be released as a result of project related venting and

fugitive emissions.

Vented emissions are defined as those emissions which pass through a stack, vent, or equivalent opening.

A compressor may be vented for startup, shutdown, maintenance, or for protection of gas seals from

contamination. Individual system components, including the filter/separator, fuel gas meter, and/or fuel

filters may be vented for inspection and maintenance. An individual compressor or the entire station may

be vented for testing, maintenance, or in the event of an emergency. Fugitive emissions are defined as those

emissions which do not pass through a stack, vent, or other functionally equivalent opening10, and include

natural gas leaks from valves, flanges, pumps, compressors, seals, connections, etc.

The risk assessment conducted by FERC for the New Market Project (FERC, 2016) determined that natural

gas emissions due to venting events are below a level of human health concern. Because the calculated

volumes of natural gas that could be vented at the two compressor stations are approximately 30 percent

less than the volume of gas emitted from the facilities approved by FERC in the New Market Project, the

emissions from the Project will be below levels that present potential health concerns.

9.2 NOISE QUALITY

The unit of noise measurement is the decibel (dB), which measures the energy of the noise. Because the

human ear is not uniformly sensitive to noise frequencies, the “A” weighting frequency scale (dBA) was

devised to correspond with the human ear's sensitivity. The A-weighted frequency scale uses specific

weighting of a sound pressure level for the purpose of determining the human response to sound and the

resulting unit of measure is the dBA.

Because noise levels can vary over a given time period, they are further quantified using the Equivalent

Sound Level (Leq) and Day-Night Level (Ldn). The Leq is an average of the time-varying sound energy for

a specified time period. The Ldn is an average of the time-varying sound energy for one 24-hour period,

with a 10 dB addition to the sound energy for the time period of 22:00 to 07:00 hours.

9.2.1 Noise Regulations

The proposed Project is regulated by FERC. The FERC noise regulations and State, County and Local

noise regulations that may be applicable are presented below.

Federal Energy Regulatory Commission

The USEPA has identified an Ldn of 55 dBA as being the maximum sound level that will not adversely

affect public health and welfare by interfering with speech or other activities in outdoor areas, with an

adequate margin of safety (USEPA, 1971). If the sound energy does not vary with time, the Ldn level will

be equal to the Leq level plus 6.4 dB.

10 40 CFR 52.21(b)(20)


FERC regulations require that the noise attributable to new compressor stations or station modifications not

exceed an Ldn of 55 dBA at the nearest noise sensitive area (NSA) (schools, hospitals, or residences) unless

such noise sensitive areas are established after facility construction. In addition, typically the noise

attributable to the full load operation of the Station, including the compressor unit addition(s), should not

exceed the previously existing noise levels produced by the station at any nearby NSA that are above an

Ldn of 55 dBA. FERC regulations also require that new compressor stations or station modifications not

result in a perceptible increase in vibration at any NSAs.

State Regulations

There are no applicable noise regulations within New York State11.

County Regulations

Millennium conducted an initial review and did not identify any applicable Delaware, Sullivan, Orange or

Rockland county noise ordinances or regulations.

Local Regulations

Millennium conducted an initial review and did not identify any noise ordinances for the Town of Highland,

Town of Hancock, Town of Minisink, or Town of Greenville. The Town of Deerpark and the Town of

Ramapo have noise ordinances. The proposed facilities would be sited by FERC and as such are subject to

federal, rather than local, oversight on noise levels.

9.2.2 Existing Noise Levels

Hoover and Keith, Inc. (H&K), an acoustical engineering company, performed pre-construction and/or

ambient sound surveys for the Project facilities on behalf of Millennium. The existing sound levels are

depicted in the following tables:

Proposed Highland CS Table 9A-12

Existing Hancock CS Table 9A-13

Existing Ramapo M&R Table 9A-14

Existing Huguenot M&R Table 9A-15

11 The NYSDEC has a Policy Document (i.e., Program Policy DEP-00-1; Revised Feb. 2, 2001, “Assessing and Mitigating Noise

Impacts”) to provide guidance and clarify program issues for NYSDEC staff to ensure compliance with statutory and regulatory

requirements for facility operations regulated under New York State Environmental Quality Reviews or “SEQR”. The Project,

however, is not subject to SEQR.


9.2.3 Construction Noise Impacts

Aboveground Facilities

Construction of the proposed facilities will be temporary and short-term in nature, and primarily limited to

daytime hours. Construction will consist of earth work (e.g., site grading, clearing and grubbing) and

construction of the site foundations and equipment, and it is assumed that the highest level of construction

noise would occur during site earth work (i.e., time frame when the largest amount of construction

equipment would operate).

H&K estimates the following peak noise level of construction activities, at the closest NSAs, for the

aboveground facilities:

Proposed Highland CS 41 dBA Ldn

Proposed Compressor Unit Addition at the Hancock CS 64 dBA Ldn

Proposed Meter and Regulation Facilities (at the Ramapo M&R) 54 dBA Ldn

Proposed Huguenot Regulation Equipment (at the Huguenot M&R) 69 dBA Ldn

Pipeline Facilities

Construction of the Huguenot Loop will cause temporary increases in noise levels in the immediate vicinity

of the construction sites. On-site construction noise will occur mainly from heavy-duty construction

equipment (e.g., trucks, backhoes, excavators, loaders and cranes). Noise from on-site construction

activities that may occur near a noise-sensitive receptor along the pipeline route may be intermittent or

continuous, but will be limited to short durations over a period of three to four weeks at any one location

based on the nature of right-of-way construction sequencing.

Blasting, if required for ditch excavation in shallow bedrock conditions, may also be required during the

right-of-way construction sequencing. Controlled blasting for purposes of making shallow bedrock

excavation feasible will be completed in accordance with the Project blasting plan (see Appendix 1B of

Resource Report 1). The amount of explosives per borehole will be limited by the proximity of existing

structures and utilities. Instantaneous sound levels from typical construction blasting would be more than

typical project construction activities at a distance of 50 feet. In comparison with other construction noise,

the sound from blasting will be brief and infrequent, if blasting is determined to be required on the Project.

Horizontal Directional Drill Sites

Millennium proposes to utilize the Horizontal Directional Drill (HDD) construction method for the

following:

HDD #1: Neversink River (Town of Deerpark, Orange County)

HDD #2: Interstate 84 (Town of Greenville, Orange County)

HDD #3 (Mountain Road (HDD #3A and Bedell Drive (HDD #3B)


The HDD construction technique is an alternative to traditional "open cut" construction and is itself an

"environmental mitigation measure" for avoiding existing infrastructure and sensitive features. A

construction noise assessment was performed for both proposed HDD crossings, and the associated report

is located in Appendix 9E. A 55 dBA Ldn sound level contribution, resulting from HDD operations, at

nearby NSAs is typically utilized by the FERC as a guideline and/or criteria where HDD operations could

be employed for a 24-hour workday. For 24-hour HDD operations, FERC also requires mitigation measures

to minimize the noise impact on nearby NSAs. Table 9.2-1 summarizes the construction noise assessment

for the closest NSAs to the Entry and Exit sites for the proposed HDD sites:

TABLE 9.2-1 Construction Noise Assessment for the HDD Sites

Entry or

Exit Point

Distance and Direction of Closest NSA

Calculated Peak Ldn due

to HDD (without

added noise control

measures)

Calculated Peak Ldn due

to HDD (with added

noise control measures)

Measured Ambient

Ldn

Total Ldn of HDD + Ambient

Increase above

Ambient Ldn

(dBA) (dBA) (dBA) (dB)

HDD #1 Neversink

River

Entry/Exit 1,000 feet

SW 53.2 40.8 40.1 43.5 3.4

Entry/Exit 600 feet SW 62.4 49.3 56.2 57.0 0.8

HDD #2 Interstate

84

Entry/Exit 1,100 feet SE 52.2 N/A 53.7 56.0 2.3

Entry/Exit 950 feet NW 56.8 43.9 44.6 47.3 2.7

HDD #3A Mountain

Road

Entry/Exit 500 feet E to

SE 63.2 50.1 48.5 52.4 3.8

Entry/Exit 170 feet NE 78.8 64.7 44.6 64.8 20.2

HDD #3B Bedell Drive

Entry 150 feet NE 79.9 65.9 44.6 65.9 21.3

Exit 450 feet W to

N 52.5 N/A 44.6 53.2 8.6

Notes: HDD = Horizontal Directional Drill NSA = Noise Sensitive Area Ldn = Day-Night Level dBA = “A” weighting frequency scale dB = decibel SW = Southwest SE = Southeast N/A = Not applicable NW = Northwest


The results of the acoustical analysis indicates the following:

At three of the eight HDD entry or exit sites, noise levels would meet the FERC guideline of 55

dBA Ldn for a 24-hour drilling schedule with standard equipment with no noise mitigation

measures.

At three of the seven HDD entry or exit sites, noise levels would meet the FERC guideline of 55

dBA Ldn for a 24-hour drilling schedule with noise mitigation measures.

At two of the seven HDD entry or exit sites (Mountain Road and Bedell Road), noise levels would

exceed the FERC guideline of 55 dBA Ldn for a 24-hour drilling schedule with noise mitigation

measures. With respect to 24-hour or daytime only Operations, Millennium will determine with

the selected HDD contractor what hours will be worked at a later date upon receipt of HDD

contractor proposals. Additional noise control measures and noise control strategies will continue

to be developed for these HDD sites.

9.2.4 Operating Noise Impacts

Highland CS (New)

The Noise Impact Analysis for the proposed Highland CS was performed in the following report:

H&K RN 3354, dated July 27, 2016, Proposed Highland CS, Ambient Sound Survey and Noise

Impact Analysis (associated with the Project) (see Appendix 9F).

Table 9A-12 in Appendix 9A summarizes the Noise Quality Analysis, at the nearby NSAs, for the proposed

Highland CS.

The results of the acoustical analysis indicates that the noise attributable to the Highland CS will be

significantly less than an Ldn of 55 dBA at the closest NSAs, which is in compliance with FERC

requirements. Additionally, site sources that could cause perceptible vibration (such as turbine unit exhaust

noise) will be adequately mitigated; therefore, there should not be any perceptible increase in vibration at

the closest NSAs during operation of the Highland CS.

Hancock CS (Modified)

A noise impact analysis was conducted for the proposed compressor unit addition at the existing Hancock

CS (see Appendix 9G). Table 9A-13 in Appendix 9A summarizes the Noise Quality Analysis, at the nearby

NSAs for the modified Hancock CS.

The results of the acoustical analysis indicates that the total noise attributable to the modified Hancock CS

will be significantly less than an Ldn of 55 dBA at the closest NSAs, which is in compliance with FERC

requirements. Additionally, site sources that could cause perceptible vibration (such as turbine unit exhaust


noise) will be adequately mitigated; therefore, there should not be any perceptible increase in vibration at

the closest NSAs during operation of the modified Hancock CS.

Ramapo M&R (Modified)

The Noise Impact Analysis for the proposed modifications at the existing Ramapo M&R was performed in

the following report:

H&K RN 3355, dated July 27, 2016, Ramapo M&R, Pre-Construction Sound Survey and Noise

Impact Analysis (associated with the Project) (see Appendix 9H).

Table 9A-14 in Appendix 9A summarizes the Noise Quality Analysis, at the nearby NSAs, for the modified

Ramapo M&R.

The results of the acoustical analysis indicates that the noise attributable to the modified Ramapo M&R

will be less than an Ldn of 55 dBA at the closest NSAs, which is in compliance with FERC requirements.

Additionally, site sources that could cause perceptible vibration (such as control valve noise) will be

adequately mitigated; therefore, there should not be any perceptible increase in vibration at the closest

NSAs during operation of the modified Ramapo M&R.

Huguenot M&R (Modified)

A noise impact analysis was conducted for the proposed regulation equipment addition at the existing

Huguenot M&R (see Appendix 9I). Table 9A-15 in Appendix 9A summarizes the Noise Quality Analysis,

at the nearby NSAs for the modified Huguenot M&R.

The results of the acoustical analysis indicates that the total noise attributable to the modified Huguenot

M&R will be less than an Ldn of 55 dBA at the closest NSAs, which is in compliance with FERC

requirements. Additionally, site sources that could cause perceptible vibration (such as control valve and

water bath heater noise) will be adequately mitigated; therefore, there should not be any perceptible increase

in vibration at the closest NSAs during operation of the modified Huguenot M&R.

9.2.5 Noise Mitigation Measures

The noise reports included in Appendices 9E through 9H provide detailed noise control recommendations

and equipment noise requirements for the compressor stations and meter station, along with assumptions

that may affect the level of noise during normal operations of the facilities and construction operations.

Millennium intends to implement the recommended noise control measures for the Project facilities. In

general, these noise control measures may include:

High performance acoustically designed compressor buildings;

High performance turbine unit exhaust and air inlet systems;

Low noise lube oil coolers;


Low noise gas aftercoolers;

Locating high pressure gas piping below grade;

Acoustical pipe lagging for aboveground piping, where required;

Low noise control valves and/or buried control valves; and

High performance unit blowdown silencers.

9.2.6 Post-Construction Sound Surveys

Highland CS (New)

Within 60 days of startup of the proposed Highland CS, a Post-Construction Sound Survey will be

performed to document that the full load Station sound level contribution does not exceed an Ldn of 55 dBA

at the surrounding NSAs. The results of the sound survey will be submitted to the Commission.

Hancock CS (Modified)

Within 60 days of startup of the modified Hancock CS, a Post-Construction Sound Survey will be

performed to document that the full capacity station sound level contribution does not exceed an Ldn of 55

dBA at the surrounding NSAs. The results of the sound survey will be submitted to the Commission.

Ramapo M&R (Modified)

Within 60 days of startup of the modified Ramapo M&R, a Post-Construction Sound Survey will be

performed to document that the full load station sound level contribution does not exceed an Ldn of 55 dBA


Huguenot M&R (Modified)

Within 60 days of startup of the modified Huguenot M&R, a Post-Construction Sound Survey will be

performed to document that the full load station sound level contribution does not exceed an Ldn of 55 dBA


9.3 REFERENCES

Branosky, E., Stevens, A., Forbes, S. Defining the Shale Gas Life Cycle: A Framework for Identifying

and Mitigating Environmental Impacts; World Resources Institute: Washington, DC, 2012.

Center for Disease Control’s Agency for Toxic Substances Disease Registry, 2011. Agency for Toxic

Substances and Disease Registry. Health Consultation. Review of Formaldehyde Emissions

from Transcontinental Pipeline, Compressor Station #130. Comer, Georgia. U.S. Department of

Health and Human Services. April 18.

FERC 2015. New Market Project. Environmental Assessment. Docket No. CP14-497-000. October.


H&K RN 3353, dated July 27, 2016, Hancock Compressor Station, Noise Impact Analysis (Eastern System

Upgrade).

H&K RN 3354, dated July 27, 2016, Proposed Highland Compressor Station, Ambient Sound Survey and

Noise Impact Analysis (Eastern System Upgrade).

H&K RN 3355, dated July 27, 2016, Ramapo Compressor Station, Pre-Construction Sound Survey and

Noise Impact Analysis (Eastern System Upgrade).

H&K RN 3356, dated July 27, 2016, HDD Construction Noise Assessment (Eastern System Upgrade).

H&K RN 2725, dated August 31, 2013, Hancock Compressor Station, Ambient Sound Survey and Noise

Impact Analysis (associated with the Hancock Compressor Project), FERC Docket No. CP-13-14-

000.

H&K RN 2725, dated May 22, 2014, Hancock Compressor Station, Post-Construction Sound Survey,

FERC Docket No. CP-13-14-000.

Moore, C.W., Zielinska, B., Petron, G., and Jackson, R.B. 2014. Air Impacts of Increased Natural Gas

Acquisition, Processing, and Use: A Critical Review. Environ. Sci. Technol., 48, 8349−8359.

NYSDEC 2010. Division of Air Resources (DAR) – 1 AGC/SGC Tables. October 18.

[USEPA] United States Environmental Protection Agency. 1971. Community Noise, NTID 300.3,

Washington, DC, 1974. Information on Levels of Noise Requisite to Protect Public Health and

Welfare with an Adequate Margin of Safety. Washington, DC.

USEPA 2016. Reviewing National Ambient Air Quality Standards – Scientific and Technical Information,

on-line at: https://www3.epa.gov/ttn/naaqs/.

United States Code of Federal Regulations. 1983. Title 18, Part 157, Section 157.206(d)(5) Environmental

Compliance, Sound Levels. U.S. Government Printing Office, Washington, DC.

Resource Report 9 - Air and Noise Quality 9A-i Eastern System Upgrade

APPENDIX 9A

Supplemental Tables

TABLE 9A-1 Regional Climate Data .................................................................................................. 9A-1

TABLE 9A-2 National Ambient Air Quality Standards ...................................................................... 9A-2

TABLE 9A-3 New York State Ambient Air Quality Standards .......................................................... 9A-3

TABLE 9A-4 Attainment Status of the Project Areas ......................................................................... 9A-4

TABLE 9A-5 Ambient Air Quality Data for the Project Areas........................................................... 9A-5

TABLE 9A-6 Project Construction Emissions in the New York-New Jersey-Long Island,

NY-NJ-CT O3 Nonattainment Area .............................................................................. 9A-6

TABLE 9A-7 Project Construction Emissions in Attainment Areas ................................................... 9A-7

TABLE 9A-8 Operational Emissions Summary - Natural Gas Releases ............................................ 9A-9

TABLE 9A-9 Hourly Operational Emissions Summary (Excludes Natural Gas Releases) .............. 9A-10

TABLE 9A-10 Annual Operational Emissions Summary (Excludes Natural Gas Releases) .............. 9A-11

TABLE 9A-11 Compressor Station AERSCREEN / AERMOD Modeling Results ........................... 9A-12

TABLE 9A-12 Noise Quality Analysis for the Proposed Highland CS .............................................. 9A-13

TABLE 9A-13 Noise Quality Analysis for the Modified Hancock CS ............................................... 9A-14

TABLE 9A-14 Noise Quality Analysis for the Modified Ramapo M&R ........................................... 9A-15

TABLE 9A-15 Noise Quality Analysis for the Modified Huguenot M&R ......................................... 9A-16

Resource Report 9 - Air and Noise Quality 9A-1 Eastern System Upgrade

TABLE 9A-1 Regional Climate Data

Parameter Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Normal Daily Minimum Temperature (⁰F)

18.5 20.7 27.6 38.2 47.6 56.5 60.9 59.5 52.1 41.1 33.3 23.8 40.1

Normal Daily Maximum Temperature (⁰F)

33.2 36.8 46.2 59.1 69.7 77.7 81.9 79.9 72.3 60.7 49.4 37.5 58.8

Normal Daily Mean Temperature (⁰F)

25.8 28.8 36.9 48.6 58.6 67.1 71.4 69.7 62.2 50.9 41.4 30.6 49.4

Average Wind Speed (mph)

7.8 8.1 8.4 8.2 7.1 6.4 6.0 5.7 6.1 6.5 7.3 7.5 7.1

Mean Number of Days with ≥ 0.01 in. Precipitation

12 11 12 12 13 12 11 11 10 10 11 12 136

Normal Precipitation (in.)

2.37 2.03 2.55 3.33 3.52 4.03 3.79 3.41 4.07 3.34 3.14 2.68 38.26

Average Snow Fall (in.)

11.3 10.6 5.5 2.3 0.1 0.0 0.0 0.0 0.0 0.4 3.5 8.6 45.3

Source: Data reported for Avoca, Pennsylvania in Comparative Climatic Data for the United States Through 2014, National Climatic Data Center. The approximates distances and directions from Project facilities to the meteorological data station are as follows:

Hancock CS 52 miles SW

Highland CS 61 miles SSW

Huguenot M&R 56 miles WSW

Ramapo M&R 86 miles W

Westtown M&R 75 miles W Notes: ⁰F = degrees Fahrenheit in. = inches T = Trace


TABLE 9A-2 National Ambient Air Quality Standards

Pollutant Averaging

Time

Primary Standard

Secondary Standard Rank

ppm μg/m3 ppm μg/m3

SO2 1-hour 0.075 196 N/A N/A

99th percentile of 1-hour daily maximum concentrations, averaged over 3 years

3-hour N/A N/A 0.5 1,300 Not to be exceeded more than once per year

PM10 24-hour N/A 150 N/A 150 Not to be exceeded more than once per year on average over 3 years

PM2.5 24-hour N/A 35 N/A 35 98th percentile, averaged over 3 years

Annual N/A 12 N/A 15 Annual mean, averaged over 3 years

NO2 1-hour 0.100 188 N/A N/A

98th percentile of 1-hour daily maximum concentrations, averaged over 3 years

Annual 0.053 100 0.053 100 Annual Mean

CO 8-hour 9 10,000 N/A N/A Not to be exceeded more than once per year

1-hour 35 40,000 N/A N/A Not to be exceeded more than once per year

O3

8-hour (2015)

0.070 143 0.070 143 Annual fourth-highest daily maximum 8-hr concentration, averaged over 3 years

8-hour (2008)

0.075 150 0.075 150 Annual fourth-highest daily maximum 8-hr concentration, averaged over 3 years

Pb 3-month rolling

N/A 0.15 N/A 0.15 Not to be exceeded

Source: http://www.epa.gov/air/criteria.html accessed 03/01/2016 Notes: ppm = parts per million μg/m3 = micrograms per cubic meter SO2 = sulfur dioxide

PM2.5 particulate matter with an aerodynamic diameter ≤2.5 μm

PM10 = particulate matter with an aerodynamic diameter ≤10 μm

NOx = nitrogen oxides CO = carbon monoxide O3 = ozone Pb = lead N/A – not applicable

http://www.epa.gov/air/criteria.html


TABLE 9A-3 New York State Ambient Air Quality Standards

Pollutant Averaging

Time

Primary Standard Rank

ppm μg/m3

SO2 24-hour

0.10 260 99th percentile of 24-hour average concentrations

0.14 365 Not to be exceeded more than once per year

Annual 0.03 80 Not to be exceeded

PM

See 6 NYCRR 257-3 (https://govt.westlaw.com/nycrr/Browse/Home/NewYork/NewYorkCodesRulesandRegulations?guid=Ic4010960b5a011dda0a4e17826ebc834&originationContext=documentto

c&transitionType=Default&contextData=(sc.Default))

NO2 Annual 0.05 100 Annual average of 24-hour concentrations

CO 8-hour 9 10,000 Not to be exceeded more than once per year

1-hour 35 40,000 Not to be exceeded more than once per year

Photochemical Oxidants

1-hour 0.08 160 Not to be exceeded more than once per year

NMHC 1-hour 0.24 160 Not to be exceeded more than once per year

Gaseous Fluorides

12-hour 0.0045 3.7 Not to be exceeded

24-hour 0.0035 2.85 Not to be exceeded

1-week 0.0020 1.65 Not to be exceeded

1-month 0.0010 0.8 Not to be exceeded

Be 1-month N/A 0.01 Not to be exceeded

H2S 3-month rolling

0.01 14 Not to be exceeded

Source: 6 NYCRR Subchapter B (http://www.dec.ny.gov/regs/2492.html) accessed 03/01/2016 Notes: ppm = parts per million μg/m3 = micrograms per cubic meter SO2 = sulfur dioxide PM = particulate matter NO2 = nitrogen dioxide CO = carbon monoxide NMHC = non-methane hydrocarbons Be = beryllium H2S = hydrogen sulfide N/A – not applicable

https://govt.westlaw.com/nycrr/Browse/Home/NewYork/NewYorkCodesRulesandRegulations?guid=Ic4010960b5a011dda0a4e17826ebc834&originationContext=documenttoc&transitionType=Default&contextData=(sc.Default)



http://www.dec.ny.gov/regs/2492.html


TABLE 9A-4 Attainment Status of the Project Areas

Pollutant Project Area Status / Designation

SO2 All Project Counties Better Than National Standard

PM10 Rockland and Orange Counties Attainment

Delaware and Sullivan Counties Unclassifiable / Attainment

24-hour PM2.5 (1997 Standard)

All Project Counties Unclassifiable / Attainment

Annual PM2.5 (2006 Standard)

Rockland and Orange Counties Attainment



Rockland and Orange Counties Attainment



All Project Counties Unclassifiable / Attainment

1-hour NO2 All Project Counties Unclassifiable / Attainment

Annual NO2 All Project Counties Cannot be Classified / Better Than National

Standard

CO All Project Counties Unclassifiable / Attainment

1-hour O3 a/ Rockland and Orange Counties Severe Nonattainment


8-hour O3 b/ (1997 Standard)

Rockland and Orange Counties Moderate Nonattainment


8-hour O3 (2008 Standard)

Rockland County Marginal Nonattainment

Delaware, Orange, and Sullivan Counties

Unclassifiable / Attainment

Pb (1978 Standard)

All Project Counties Unclassifiable

Pb

Orange County Unclassifiable

Delaware, Rockland, and Sullivan Counties

Unclassifiable / Attainment

Source: 40 CFR 81.333 and USEPA Green Book (http://www.epa.gov/oaqps001/greenbk/ancl.html) Notes: NA = Not Applicable a/ Standard revoked effective June 15, 2005. b/ Standard revoked effective April 5, 2015. (see 80 FR 12264 - 12319, March 6, 2015) SO2 = sulfur dioxide



NO2 = nitrogen dioxides CO = carbon monoxide O3 = ozone Pb = lead

http://www.epa.gov/oaqps001/greenbk/ancl.html


TABLE 9A-5 Ambient Air Quality Data for the Project Areas

Pollutant Averaging

Period Rank Years

Concentration Monitoring Station ID (ppm) (μg/m³)

SO2 1-Hour 99th Percentile 2012 - 2014 0.010 25.3 34-027-3001 a/

3-hour H2H 2012 - 2014 0.011 28.8

PM10 24-Hour H2H 2011 - 2013 N/A 53.0 42-095-1000 b/

PM2.5 24-Hour 98th Percentile 2011 - 2013 N/A 19.7 36-071-0002 c/

Annual Arithmetic Mean 2012 - 2014 N/A 7.4

NO2 1-Hour 98th Percentile 2012 - 2014 0.036 68.4 34-027-3001 a/

Annual Arithmetic Mean 2012 - 2014 0.005 9.8

CO 1-Hour H2H 2012 - 2014 1.8 2,062.1 42-069-2006 d/

8-Hour H2H 2012 - 2014 1.4 1,603.8

O3 1-Hour H2H 2012 - 2014 0.082 161.0 36-071-5001 e/

8-Hour 4H 2012 - 2014 0.061 120.4

Pb 3-Month Certified current 3-month average Pb data are unavailable. The best available data are 24-hour average data collected in 2012 through 2014 at monitoring station 42-101-0004 f/. The maximum and average 24-hour Pb values during this 3-year period were 0.11 μg/m3 and 0.03 μg/m3, respectively.

Source: EPA AirData; http://www.epa.gov/airdata/ accessed March 2016. Notes: a/ Building #1, Department of Public Works (DPW) off Route 513, Chester, NJ b/ South Green & Delaware, Nazareth, PA c/ 155 Broadway, Newburg, NY; 26 miles east northeast d/ George Street Troop and the City of Scranton, Scranton, PA; 60 e/ 1175 Route 17K, Montgomery Valley Central HS, Montgomery, NY f/ 1501 E. Lycoming Ave., Philadelphia, PA H2H = High 2nd High 4H = 4th High ppm = parts per million μg/m³= micrograms per cubic meter SO2 = sulfur dioxide



NO2 = nitrogen dioxides CO = carbon monoxide O3 = ozone Pb = lead N/A – not applicable

http://www.epa.gov/airdata/


TABLE 9A-6 Project Construction Emissions in the New York-New Jersey-Long Island, NY-NJ-CT O3 Nonattainment Area

Construction Activity

Emissions (tons)

NOx SO2 CO PM10 PM2.5 VOC CO2e Total HAPs

2017

Ramapo M&R

Commuter transit N/A N/A N/A N/A N/A N/A N/A N/A

On-road vehicles N/A N/A N/A N/A N/A N/A N/A N/A

Off-road equipment N/A N/A N/A N/A N/A N/A N/A N/A

Open burning N/A N/A N/A N/A N/A N/A N/A N/A

Fugitive dust N/A N/A N/A N/A N/A N/A N/A N/A

Project Total N/A N/A N/A N/A N/A N/A N/A N/A

2018

Ramapo M&R

Commuter transit 0.13 5.5E-04 0.71 3.4E-03 3.1E-03 0.01 78 3.6E-03

On-road vehicles 7.5E-03 2.0E-05 1.7E-03 2.3E-04 2.1E-04 2.8E-04 2 5.8E-05

Off-road equipment 0.19 4.9E-04 0.62 0.01 0.01 0.32 39 4.0E-03


Fugitive dust N/A N/A N/A 1.17 0.12 N/A N/A N/A

Project Total 0.33 1.1E-03 1.33 1.19 0.14 0.34 120 7.7E-03

Notes: CO = carbon monoxide CO2e = carbon dioxide equivalent HAP = hazardous air pollutant NOx = nitrogen oxides



SO2 = sulfur dioxide VOC = volatile organic compound N/A – not applicable




Emissions (tons)


2017

Highland CS


On-road vehicles 0.05 1.3E-04 0.06 1.5E-03 1.4E-03 2.5E-03 15 1.5E-03




Subtotal 0.88 2.5E-03 1.58 2.45 0.29 0.10 335 0.01

Hancock CS 0.00 0.00 0.00 0.00 0.00 0.00 0 0.00






Subtotal 0.42 1.1E-03 0.61 1.71 0.19 0.05 144 5.1E-03

Huguenot Loop, Huguenot M&R, and Westtown M&R

Commuter transit 0.40 1.7E-03 2.47 9.0E-03 8.1E-03 0.05 243 0.01


Off-road equipment 11.89 0.02 9.06 0.68 0.68 1.18 3,019 0.07



Subtotal 12.46 0.02 11.57 14.45 2.14 1.24 3,309 0.09

Project Total 13.76 0.03 13.76 18.62 2.63 1.38 3,788 0.11

2018

Highland CS

Commuter transit 0.45 2.1E-03 2.70 0.01 0.01 0.05 294 0.01

On-road vehicles 0.35 9.4E-04 0.08 0.01 9.6E-03 0.01 107 2.7E-03

Off-road equipment 3.24 7.3E-03 3.04 0.32 0.32 1.03 921 0.03



Subtotal 4.03 0.01 5.82 6.24 0.95 1.10 1,322 0.04

Hancock CS


On-road vehicles 0.32 9.0E-04 0.30 9.2E-03 8.5E-03 0.01 107 3.1E-03

Off-road equipment 2.20 4.9E-03 2.06 0.22 0.22 0.70 626 0.02





Emissions (tons)


Fugitive dust 0.00 0.00 0.00 4.15 0.43 0.00 0 0.00

Subtotal 2.83 7.2E-03 4.20 4.38 0.66 0.75 933 0.03

Huguenot Loop, Huguenot M&R, and Westtown M&R

Commuter transit 0.79 3.7E-03 5.34 0.02 0.02 0.09 544 0.02

On-road vehicles 0.35 9.4E-04 0.08 0.01 9.6E-03 0.01 107 2.7E-03

Off-road equipment 19.70 0.05 17.80 1.15 1.15 2.20 6,360 0.16



Subtotal 20.84 0.05 23.22 25.49 4.08 2.30 7,011 0.18

Project Total 27.70 0.07 33.24 36.11 5.69 4.16 9,266 0.25






TABLE 9A-8 Operational Emissions Summary - Natural Gas Releases


Emissions (tons per year)


Huguenot Loop N/A N/A N/A N/A N/A 4.6E-06 1.5 N/A

Huguenot M&R N/A N/A N/A N/A N/A 1.9E-04 6.3 N/A

Westtown M&R N/A N/A N/A N/A N/A 1.9E-04 6.3 N/A

Ramapo M&R N/A N/A N/A N/A N/A 1.9E-04 6.3 N/A

Highland CS N/A N/A N/A N/A N/A 0.53 8,466.2 N/A

Hancock CS N/A N/A N/A N/A N/A 0.54 8,652.0 N/A

Project Total N/A N/A N/A N/A N/A 1.07 17,138.6 N/A






TABLE 9A-9 Hourly Operational Emissions Summary (Excludes Natural Gas Releases)

Facility/ Emission Source

Emissions (pounds per hour)


Ramapo M&R

Existing

Heater A 1.74 0.01 2.65 0.13 0.13 0.53 2,128 0.18

Heater B 1.21 0.007 1.84 0.09 0.09 0.37 1,477 0.13

Proposed New

Heater C TBD TBD TBD TBD TBD TBD TBD TBD

Highland CS

Proposed New

Solar Titan 130E 11.09 4.57 17.8 12.27 12.27 5.53 21,847 0.57

Waukesha VGF48GL Emergency Generator A

5.42 0.006 10.85 0.10 0.10 2.71 1,139 0.70

Fuel Gas Heater A 0.12 0.007 0.10 0.01 0.01 0.007 144 0.002

Hancock CS

Existing

Solar Mars 100 7.82 1.89 10.87 2.85 2.85 0.90 15,867 0.14

Waukesha VGF36 Emergency Generator A

3.88 0.004 7.76 0.07 0.07 1.94 874 0.54

Proposed New

Solar Titan 130E 10.94 1.03 17.64 2.76 2.76 1.25 21,546 0.56


5.42 0.006 10.85 0.10 0.10 2.71 1,139 0.71

Fuel Gas Heater A 0.12 0.007 0.10 0.01 0.01 0.007 144 0.002




SO2 = sulfur dioxide VOC = volatile organic compound


TABLE 9A-10 Annual Operational Emissions Summary (Excludes Natural Gas Releases)

Facility/ Emission Source

Emissions (tons per year)


Ramapo M&R

Existing

Heater A 7.61 0.05 11.60 0.59 0.59 2.32 9,319 0.80

Heater B 5.28 0.03 8.05 0.41 0.41 1.61 6,469 0.55

Proposed New

Heater C TBD TBD TBD TBD TBD TBD TBD TBD

Facility Total TBD TBD TBD TBD TBD TBD TBD TBD

Highland CS

Proposed New

Solar Titan 130E 48.59 4.57 78.08 12.27 12.27 5.53 95,690 2.48


1.36 0.001 2.71 0.02 0.02 0.68 285 0.18

Fuel Gas Heater A 0.53 0.03 0.44 0.04 0.04 0.03 631 0.01

Facility Total 50.47 4.60 8.23 12.33 12.33 6.23 96,606 2.67

Hancock CS

Existing

Solar Mars 100 34.24 8.26 47.62 12.47 12.47 3.94 69,499 0.61

Waukesha VGF36 Emergency Generator A

0.97 0.001 1.94 0.02 0.02 0.49 219 0.13

Proposed New

Solar Titan 130E 47.92 4.51 77.28 12.10 12.10 5.45 94,373 2.45


1.36 0.001 2.71 0.02 0.02 0.68 285 0.18

Fuel Gas Heater A 0.53 0.03 0.44 0.04 0.04 0.03 631 0.01

Facility Total 85.0 12.8 130.0 24.7 24.7 10.6 165,007 3.4




SO2 = sulfur dioxide VOC = volatile organic compound


TABLE 9A-11 Compressor Station AERSCREEN / AERMOD Modeling Results

Pollutant Averaging

Period

Maximum Combined

Model Concentration

(μg/m3)

Ambient Background

(μg/m3)

Total Concentration

(μg/m3)

NAAQS (μg/m3)

Highland CS (New)

CO 1-hour 312 2,070 2,382 10,000

8-hour 89 1,495 1,584 40,000

NO2 1-hour 20.9 75.8 96.7 188

Annual 1.6 20.0 21.6 100

PM2.5 24-hour 0.7 22.3 23.0 35

Annual 0.1 9.5 9.6 12

PM10 24-hour 2.1 45 47.1 150

SO2 1-hour 1.8 21.0 22.8 196

Hancock CS (Existing and Proposed Equipment Cumulative Impacts)

CO 1-hour 452 2,070 2,522 10,000

8-hour 192 1,495 1,687 40,000

NO2 1-hour 34.9 75.8 110.7 188

Annual 5.0 20.0 25.0 100

PM2.5 24-hour 3.8 22.3 26.1 35

Annual 0.5 9.5 10.0 12

PM10 24-hour 7.8 45 52.8 150

SO2 1-hour 9.2 21.0 30.2 196

Notes: μg/m3 = microgram per cubic meter CO = carbon monoxide NOx = nitrogen oxides PM2.5 particulate matter with an aerodynamic diameter ≤2.5 μm PM10 = particulate matter with an aerodynamic diameter ≤10 μm SO2 = sulfur dioxide


TABLE 9A-12 Noise Quality Analysis for the Proposed Highland CS

NSAs

Distance and Direction to Proposed

Compressor Station

Existing Ambient Ldn

Estimated Leq of

Proposed Compressor

Station

Estimated Ldn of

Proposed Compressor

Station

Total Ldn

(Ambient + Proposed

Compressor Station)

Potential Increase Above

Existing Ambient

Level

(dBA) (dBA) (dBA) (dBA) (dB)

NSA #1 (Houses)

3,300 feet NW 41.0 29.0 35.4 42.0 1.0

NSA #2 (Houses)

3,000 feet W 41.0 29.8 36.2 42.2 1.2

NSA #3 (House)

2,900 feet SW 41.0 30.1 36.5 42.3 1.3

NSA #4 (House)

3,750 feet N-NW 41.0 27.9 34.3 41.8 0.8

Notes: dBA = “A” weighting frequency scale dB = decibel Ldn = Day-Night Level Leq = Equivalent Sound Level NSA = Noise Sensitive Area NW = northwest W = West N-NW = North, northwest SW = Southwest


TABLE 9A-13 Noise Quality Analysis for the Modified Hancock CS

NSAs

Distance and Direction to

Center of Proposed

Compressor Unit

Existing Ambient

Ldn

Ldn of Existing

Station at Full Load Operation

Ldn of Proposed

Compressor Unit Addition

(Unit 2)

Total Ldn (Existing Station + Proposed

Unit 2)

Total Ldn (Existing Station + Proposed Unit 2 +

Ambient)


Existing Station Sound Level


Existing Ambient Sound Level

(dBA) (dBA) (dBA) (dBA) (dBA) (dB) (dB)

NSA #1 (House)

675 feet E 42.6 40.8 44.7 46.2 47.8 5.4 5.2

NSA #2 (House)

1,550 feet W-SW

41.5 35.1 37.9 39.7 43.7 4.6 2.2

NSA #3 (House)

2,175 feet NE 41.1 30.4 33.6 35.3 42.1 4.9 1.0

NSA #4 (House)

3,775 feet S-SE

41.6 24.9 29.0 30.4 42.0 5.5 0.4

NSA #5 (Houses)

3,475 feet E-NE

41.4 25.5 29.4 30.9 41.8 5.4 0.4

Notes: dBA = “A” weighting frequency scale dB = decibel E = East E-NE = East, northeast Ldn = Day-Night Level NE = Northeast NSA = Noise Sensitive Area S-SE = South, southeast W-SW = South- southwest


TABLE 9A-14 Noise Quality Analysis for the Modified Ramapo M&R

NSAs

Distance and Direction to

Proposed M&R Addition

Ambient Ldn Estimated Leq of M&R Addition

Estimated Ldn of M&R

Addition

Total Ldn (Ambient +

M&R Addition)


Ambient


NSA #1 (Houses)

975 feet E to SE 58.7 35.9 42.3 58.8 0.1

NSA #2 (Houses)

1,900 feet N-NE to NE

45.4 28.7 35.1 45.8 0.4

NSA #3 (County Park)

1,900 feet S-SW

43.3 28.5 34.9 43.9 0.6

Notes: dBA = “A” weighting frequency scale dB = decibel E = East Ldn = Day-Night Level Leq = Equivalent Sound Level M&R = Metering and Regulating facilities N-NE = North, northeast NE = Northeast NSA = Noise Sensitive Area S-SW = South, southwest SE = Southeast


TABLE 9A-15 Noise Quality Analysis for the Modified Huguenot M&R

NSAs Distance and Direction

to Proposed M&R Addition

Ambient Ldn Estimated Leq of M&R Addition

Estimated Ldn of M&R

Addition

Total Ldn (Ambient +

M&R Addition)


Ambient


NSA #1 (Houses)

250 feet S to NE 48.9 42.9 49.3 52.1 3.2

NSA #2 (Houses)

475 feet NE to NW 48.8 36.9 43.3 49.9 1.1

NSA #3 (Houses)

700 feet NW to W-NW 46.5 33.1 39.5 47.3 0.9

Notes: dBA = “A” weighting frequency scale dB = decibel Ldn = Day-Night Level Leq = Equivalent Sound Level M&R = Metering and Regulating facilities NE = Northeast NW = Northwest NSA = Noise Sensitive Area S = South W-NW = West, northwest

Resource Report 9 – Air and Noise Quality 9B-i Eastern System Upgrade

APPENDIX 9B

Construction Emission Calculations

Table 9.B.1.1: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Huguenot Loop, Huguenot M&R, and Westtown M&R2017 Construction Equipment Criteria Pollutant Emissions

(Continued)Nonroad Equipment Type/ On Road Vehicle Type

Fuel Engine Rating (hp)

No. Pollutant Emission Factor(g/hp‐hr)³(g/mile) ⁴

Equipment Operating Schedule

Pollutant Emissions(tons)

CO NOx SO₂ VOC PM₁₀ PM₂.₅ weeks days/ week

hr/daymi/day

CO NOx SO₂ VOC PM₁₀ PM₂.₅

Commuter TransitBuses Diesel 2017364323 1 2 1 1.73 5.69 7.7E‐3 0.36 0.23 0.21 11 6 50 0.01 0.04 5.6E‐5 2.6E‐3 1.7E‐3 1.6E‐3

Light Trucks Diesel 2017363223 1 4 1 1.08 1.73 5.8E‐3 0.26 0.09 0.08 11 6 100 0.03 0.05 1.7E‐4 7.4E‐3 2.6E‐3 2.4E‐3

Passenger Cars Gasoline 2017362113 1 48 1 1.49 0.16 2.0E‐3 0.02 5.3E‐3 4.7E‐3 11 6 80 0.42 0.04 5.5E‐4 6.4E‐3 1.5E‐3 1.3E‐3

Passenger Trucks Gasoline 2017363113 1 48 1 7.21 0.93 3.2E‐3 0.12 0.01 0.01 11 6 80 2.01 0.26 8.9E‐4 0.03 3.2E‐3 2.8E‐3

Total 2.47 0.40 1.7E‐3 0.05 9.0E‐3 8.1E‐3

On Road VehiclesMaterials Delivery

Heavy Trucks Diesel 2017366123 1 4 1 1.36 6.12 0.01 0.23 0.20 0.18 11 6 100 0.04 0.18 4.2E‐4 6.8E‐3 5.7E‐3 5.2E‐3

Total 0.04 0.18 4.2E‐4 6.8E‐3 5.7E‐3 5.2E‐3

Off Road EquipmentLowboy Truck Diesel 2270002051 400 9 59% 0.37 1.06 3.8E‐3 0.14 0.06 0.06 11 6 5 0.29 0.82 2.9E‐3 0.11 0.04 0.04

Flatbed Truck Diesel 2270002051 125 16 59% 0.24 0.67 3.6E‐3 0.14 0.04 0.04 11 6 5 0.10 0.29 1.6E‐3 0.06 0.02 0.02

Dozer Diesel 2270002069 250 12 59% 0.42 1.28 3.9E‐3 0.15 0.08 0.08 11 6 5 0.27 0.82 2.5E‐3 0.10 0.05 0.05

Backhoe/Excavator Diesel 2270002066 300 12 21% 1.77 3.45 5.1E‐3 0.50 0.34 0.34 11 6 5 0.49 0.95 1.4E‐3 0.14 0.09 0.09

Backhoe Diesel 2270002066 80 6 21% 4.89 3.94 5.8E‐3 0.76 0.71 0.71 11 6 5 0.18 0.14 2.1E‐4 0.03 0.03 0.03

Side Booms Diesel 2270002069 260 8 59% 0.42 1.28 3.9E‐3 0.15 0.08 0.08 11 6 5 0.19 0.57 1.7E‐3 0.07 0.03 0.03

Crane Diesel 2270002045 250 3 43% 0.37 1.67 4.0E‐3 0.17 0.08 0.08 11 6 5 0.04 0.20 4.7E‐4 0.02 9.0E‐3 9.0E‐3

Crane Diesel 2270002045 680 3 43% 0.92 2.60 4.3E‐3 0.17 0.11 0.11 11 6 5 0.29 0.83 1.4E‐3 0.05 0.04 0.04

Loaders / Graders Diesel 2270002048 250 2 59% 0.41 1.25 3.9E‐3 0.15 0.08 0.08 11 6 5 0.04 0.13 4.2E‐4 0.02 8.1E‐3 8.1E‐3

Farm Tractors Diesel 2270002066 175 1 21% 1.77 3.45 5.1E‐3 0.50 0.34 0.34 11 6 5 0.02 0.05 6.8E‐5 6.7E‐3 4.5E‐3 4.5E‐3

Forklift / Manlift Diesel 2270002057 60 3 59% 2.01 3.47 4.8E‐3 0.23 0.23 0.23 11 6 5 0.08 0.13 1.9E‐4 9.0E‐3 8.9E‐3 8.9E‐3

Bending Machine Diesel 2270002081 85 1 59% 2.34 2.55 4.8E‐3 0.25 0.31 0.31 11 6 5 0.04 0.05 8.7E‐5 4.6E‐3 5.7E‐3 5.7E‐3

Road Boring Machine Diesel 2270002033 90 1 43% 2.17 4.03 5.0E‐3 0.43 0.40 0.40 11 6 5 0.03 0.06 7.0E‐5 6.0E‐3 5.6E‐3 5.6E‐3

Fill / Test Pumps Diesel 2270006010 40 2 43% 1.32 4.23 4.8E‐3 0.31 0.26 0.26 11 6 5 0.02 0.05 6.1E‐5 3.9E‐3 3.2E‐3 3.2E‐3

185 acfm Compressor Diesel 2270006015 60 2 43% 1.69 3.67 4.8E‐3 0.25 0.22 0.22 11 6 5 0.03 0.07 9.0E‐5 4.7E‐3 4.2E‐3 4.2E‐3


1200 acfm Compressor Diesel 2270006015 350 2 43% 0.83 3.02 4.3E‐3 0.20 0.13 0.13 11 6 5 0.09 0.33 4.7E‐4 0.02 0.01 0.01

Welding Machine Diesel 2270006025 40 16 21% 3.59 4.72 5.8E‐3 0.80 0.58 0.58 11 6 5 0.18 0.23 2.8E‐4 0.04 0.03 0.03

Generator Diesel 2270006005 50 14 43% 2.29 4.64 5.0E‐3 0.45 0.38 0.38 11 6 5 0.25 0.51 5.5E‐4 0.05 0.04 0.04Misc Saws, Trowel Machine, Compactor Plate, etc.

Diesel 2270002008 50 6 43% 4.46 4.64 5.4E‐3 0.62 0.44 0.44 11 6 5 0.21 0.22 2.5E‐4 0.03 0.02 0.02

6" Water Pump Diesel 2270006010 60 6 43% 2.31 4.65 5.0E‐3 0.45 0.40 0.40 11 6 5 0.13 0.26 2.8E‐4 0.03 0.02 0.02

HDD Rig Diesel 2270002033 800 2 43% 1.39 5.36 4.4E‐3 0.37 0.23 0.23 13 6 12 0.99 3.80 3.1E‐3 0.26 0.16 0.16

3" Water Pump Diesel 2270006010 40 6 43% 1.32 4.23 4.8E‐3 0.31 0.26 0.26 11 6 5 0.05 0.16 1.8E‐4 0.01 9.7E‐3 9.7E‐3

Load Factor

NONROAD SCC¹MOVES Year/ State/ Vehicle

Type/ Fuel/ Road Type 2

Eastern System Upgrade Project 9.B-1 July 2016








hr/daymi/day


Load Factor



9.06 11.89 0.02 1.18 0.68 0.68

1. User’s Guide for the Final NONROAD2005 Model , EPA420‐R‐05‐013, US EPA, December 2005

2. MOVES2014a User Guide, EPA‐420‐B‐15‐095, US EPA, November 2015

3. EPA NONROAD2008 run

4. EPA MOVES2014 run

Total


Table 9.B.1.2: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Huguenot Loop, Huguenot M&R, and Westtown 2017 Construction Equipment Greenhouse Gas and Hazardous Air Pollutant Emissions






CO2 CH₄⁵ N₂O⁵ CO₂e⁶ Total HAPS

weeks days/ week

hr/daymi/day

CO2 N₂O CH₄ CO₂e Total HAPS

Commuter TransitBuses Diesel 2017364323 1 2 1 861 862 0.06 11 6 50 6 0.0E+0 0.0E+0 6 4.7E‐4

Light Trucks Diesel 2017363223 1 4 1 657 658 0.05 11 6 100 19 0.0E+0 0.0E+0 19 1.4E‐3

Passenger Cars Gasoline 2017362113 1 48 1 298 299 6.4E‐3 11 6 80 83 0.0E+0 0.0E+0 83 1.8E‐3

Passenger Trucks Gasoline 2017363113 1 48 1 477 479 0.03 11 6 80 133 0.0E+0 0.0E+0 134 8.9E‐3

242 0.0E+0 0.0E+0 243 0.01


Heavy Trucks Diesel 2017366123 1 4 1 1,635 1,636 0.05 11 6 100 48 0.0E+0 0.0E+0 48 1.3E‐3

48 0.0E+0 0.0E+0 48 1.3E‐3

Off Road EquipmentLowboy Truck Diesel 2270002051 400 9 59% 536 0.03 0.01 541 1.2E‐02 11 6 5 414 0.01 0.02 418 9.5E‐3

Flatbed Truck Diesel 2270002051 125 16 59% 536 0.03 0.01 541 1.2E‐02 11 6 5 230 5.8E‐3 0.01 232 5.3E‐3

Dozer Diesel 2270002069 250 12 59% 536 0.03 0.01 541 1.2E‐02 11 6 5 345 8.7E‐3 0.02 348 7.9E‐3

Backhoe/Excavator Diesel 2270002066 300 12 21% 625 0.04 0.02 631 1.2E‐02 11 6 5 172 4.3E‐3 9.7E‐3 173 3.4E‐3

Backhoe Diesel 2270002066 80 6 21% 694 0.04 0.02 700 1.2E‐02 11 6 5 25 6.4E‐4 1.4E‐3 26 4.5E‐4

Side Booms Diesel 2270002069 260 8 59% 536 0.03 0.01 541 1.2E‐02 11 6 5 239 6.0E‐3 0.01 242 5.5E‐3

Crane Diesel 2270002045 250 3 43% 531 0.03 0.01 535 1.2E‐02 11 6 5 62 1.6E‐3 3.5E‐3 63 1.4E‐3


Loaders / Graders Diesel 2270002048 250 2 59% 536 0.03 0.01 541 1.2E‐02 11 6 5 58 1.4E‐3 3.2E‐3 58 1.3E‐3

Farm Tractors Diesel 2270002066 175 1 21% 625 0.04 0.02 631 1.2E‐02 11 6 5 8 2.1E‐4 4.7E‐4 8 1.6E‐4

Forklift / Manlift Diesel 2270002057 60 3 59% 595 0.03 0.01 601 1.2E‐02 11 6 5 23 5.8E‐4 1.3E‐3 23 4.8E‐4

Bending Machine Diesel 2270002081 85 1 59% 595 0.03 0.01 601 1.2E‐02 11 6 5 11 2.7E‐4 6.1E‐4 11 2.2E‐4

Road Boring Machine Diesel 2270002033 90 1 43% 589 0.03 0.01 594 1.2E‐02 11 6 5 8 2.1E‐4 4.7E‐4 8 1.7E‐4

Fill / Test Pumps Diesel 2270006010 40 2 43% 589 0.03 0.01 595 1.2E‐02 11 6 5 7 1.8E‐4 4.2E‐4 7 1.5E‐4

185 acfm Compressor Diesel 2270006015 60 2 43% 590 0.03 0.01 595 1.2E‐02 11 6 5 11 2.8E‐4 6.2E‐4 11 2.3E‐4



Welding Machine Diesel 2270006025 40 16 21% 693 0.04 0.02 700 1.2E‐02 11 6 5 34 8.5E‐4 1.9E‐3 34 6.0E‐4

Generator Diesel 2270006005 50 14 43% 589 0.03 0.01 594 1.2E‐02 11 6 5 64 1.6E‐3 3.6E‐3 65 1.3E‐3Misc Saws, Trowel Machine, Compactor Plate, etc.

Diesel 2270002008 50 6 43% 588 0.03 0.01 594 1.2E‐02 11 6 5 28 6.9E‐4 1.6E‐3 28 5.8E‐4

6" Water Pump Diesel 2270006010 60 6 43% 589 0.03 0.01 594 1.2E‐02 11 6 5 33 8.3E‐4 1.9E‐3 33 6.9E‐4

HDD Rig Diesel 2270002033 800 2 43% 530 0.03 0.01 535 5.0E‐3 13 6 12 376 9.4E‐3 0.02 379 3.5E‐3


Load Factor











weeks days/ week

hr/daymi/day


Load Factor



2,996 3,019 7.E‐02





5. Computed from the CO₂ emissions from NONROAD multiplied by ratios of the CH₄ and N₂O to CO₂ from Tables 13.1 and 13.7 (for diesel and gasoline)

Tables 12.1 and 12.9.1 (for CNG) in 2015 Climate Registry Default Emission Factors

6. AP 42 Table 3.3‐2 (Diesel , <600 hp); AP 42 Tables 3.4‐3 & 3.4‐4 (Diesel , ≥600 hp); AP 42Table 3.2‐2 (CNG); computed from the HC emissions from NONROAD multiplied by ratios of the

HAP to VOC ratio for gasoline passenger car from MOVES2014 (gasoline).

7. The global warming potentials of CO ₂, CH₄, and N₂O are assumed to be 1, 25, and 298, respectively.

Total









hr/daymi/day



Light Trucks Diesel 2018363223 1 4 1 0.93 1.53 5.7E‐3 0.21 0.08 0.07 25 6 100 0.06 0.10 3.8E‐4 0.01 5.0E‐3 4.6E‐3

Passenger Cars Gasoline 2018362113 1 48 1 1.40 0.13 1.9E‐3 0.02 4.8E‐3 4.3E‐3 25 6 80 0.89 0.08 1.2E‐3 0.01 3.1E‐3 2.7E‐3

Passenger Trucks Gasoline 2018363113 1 48 1 6.88 0.82 3.1E‐3 0.10 0.01 9.4E‐3 25 6 80 4.37 0.52 2.0E‐3 0.06 6.7E‐3 6.0E‐3

Total 5.34 0.79 3.7E‐3 0.09 0.02 0.02


Heavy Trucks Diesel 2018366123 1 4 1 1.17 5.23 0.01 0.20 0.16 0.15 25 6 100 0.08 0.35 9.4E‐4 0.01 0.01 9.6E‐3

Total 0.08 0.35 9.4E‐4 0.01 0.01 9.6E‐3

Off Road EquipmentLowboy Truck Diesel 2270002051 400 9 59% 0.27 0.82 3.7E‐3 0.14 0.04 0.04 25 6 5 0.47 1.45 6.4E‐3 0.24 0.06 0.06

Flatbed Truck Diesel 2270002051 125 16 59% 0.19 0.47 3.6E‐3 0.13 0.03 0.03 25 6 5 0.19 0.46 3.5E‐3 0.13 0.03 0.03

Dozer Diesel 2270002069 250 12 59% 0.32 1.04 3.8E‐3 0.15 0.06 0.06 25 6 5 0.47 1.52 5.5E‐3 0.21 0.08 0.08

Backhoe/Excavator Diesel 2270002066 300 12 21% 1.61 3.15 5.0E‐3 0.46 0.31 0.31 25 6 5 1.01 1.97 3.1E‐3 0.29 0.19 0.19

Backhoe Diesel 2270002066 80 6 21% 4.56 3.63 5.7E‐3 0.69 0.65 0.65 25 6 5 0.38 0.30 4.7E‐4 0.06 0.05 0.05

Side Booms Diesel 2270002069 260 8 59% 0.32 1.04 3.8E‐3 0.15 0.06 0.06 25 6 5 0.33 1.05 3.8E‐3 0.15 0.06 0.06

Crane Diesel 2270002045 250 3 43% 0.32 1.43 3.9E‐3 0.16 0.06 0.06 25 6 5 0.08 0.38 1.0E‐3 0.04 0.02 0.02

Crane Diesel 2270002045 680 3 43% 0.84 2.31 4.2E‐3 0.17 0.10 0.10 25 6 5 0.61 1.67 3.0E‐3 0.12 0.07 0.07

Loaders / Graders Diesel 2270002048 250 2 59% 0.31 1.01 3.8E‐3 0.15 0.05 0.05 25 6 5 0.08 0.25 9.2E‐4 0.04 0.01 0.01

Farm Tractors Diesel 2270002066 175 1 21% 1.61 3.15 5.0E‐3 0.46 0.31 0.31 25 6 5 0.05 0.10 1.5E‐4 0.01 9.4E‐3 9.4E‐3

Forklift / Manlift Diesel 2270002057 60 3 59% 1.76 3.36 4.7E‐3 0.21 0.20 0.20 25 6 5 0.15 0.30 4.1E‐4 0.02 0.02 0.02

Bending Machine Diesel 2270002081 85 1 59% 2.10 2.25 4.6E‐3 0.23 0.28 0.28 25 6 5 0.09 0.09 1.9E‐4 9.6E‐3 0.01 0.01

Road Boring Machine Diesel 2270002033 90 1 43% 2.03 3.75 4.9E‐3 0.40 0.37 0.37 25 6 5 0.06 0.12 1.6E‐4 0.01 0.01 0.01

Fill / Test Pumps Diesel 2270006010 40 2 43% 1.18 4.09 4.7E‐3 0.28 0.23 0.23 25 6 5 0.03 0.12 1.3E‐4 8.0E‐3 6.6E‐3 6.6E‐3


375 acfm Compressor Diesel 2270006015 100 2 43% 0.52 1.95 4.1E‐3 0.19 0.13 0.13 25 6 5 0.04 0.14 2.9E‐4 0.01 9.2E‐3 9.2E‐3

1200 acfm Compressor Diesel 2270006015 350 2 43% 0.76 2.76 4.3E‐3 0.19 0.12 0.12 25 6 5 0.19 0.69 1.1E‐3 0.05 0.03 0.03

Welding Machine Diesel 2270006025 40 16 21% 3.21 4.56 5.7E‐3 0.71 0.53 0.53 25 6 5 0.36 0.51 6.4E‐4 0.08 0.06 0.06

Generator Diesel 2270006005 50 14 43% 2.15 4.51 5.0E‐3 0.42 0.36 0.36 25 6 5 0.54 1.12 1.2E‐3 0.10 0.09 0.09Misc Saws, Trowel Machine, Compactor Plate, etc.

Diesel 2270002008 50 6 43% 4.46 4.55 5.4E‐3 0.60 0.42 0.42 25 6 5 0.48 0.49 5.8E‐4 0.06 0.04 0.04


HDD Rig Diesel 2270002033 800 2 43% 1.29 5.13 4.4E‐3 0.35 0.21 0.21 13 6 12 0.91 3.64 3.1E‐3 0.25 0.15 0.15




Load Factor









hr/daymi/day




Load Factor

17.80 19.70 0.05 2.20 1.15 1.15





Total









weeks days/ week

hr/daymi/day





Passenger Trucks Gasoline 2018363113 1 48 1 473 475 0.03 25 6 80 300 0.0E+0 0.0E+0 302 0.02

542 0.0E+0 0.0E+0 544 0.02



107 0.0E+0 0.0E+0 107 2.7E‐3

Off Road EquipmentLowboy Truck Diesel 2270002051 400 9 59% 536 0.03 0.01 541 1.2E‐02 25 6 5 942 0.02 0.05 950 0.02

Flatbed Truck Diesel 2270002051 125 16 59% 536 0.03 0.01 541 1.2E‐02 25 6 5 523 0.01 0.03 528 0.01

Dozer Diesel 2270002069 250 12 59% 536 0.03 0.01 541 1.2E‐02 25 6 5 785 0.02 0.04 792 0.02

Backhoe/Excavator Diesel 2270002066 300 12 21% 625 0.04 0.02 631 1.2E‐02 25 6 5 391 9.8E‐3 0.02 394 7.7E‐3

Backhoe Diesel 2270002066 80 6 21% 694 0.04 0.02 700 1.2E‐02 25 6 5 58 1.5E‐3 3.3E‐3 58 1.0E‐3

Side Booms Diesel 2270002069 260 8 59% 536 0.03 0.01 541 1.2E‐02 25 6 5 544 0.01 0.03 549 0.01


Crane Diesel 2270002045 680 3 43% 531 0.03 0.01 535 5.0E‐3 25 6 5 385 9.6E‐3 0.02 388 3.6E‐3

Loaders / Graders Diesel 2270002048 250 2 59% 536 0.03 0.01 541 1.2E‐02 25 6 5 131 3.3E‐3 7.4E‐3 132 3.0E‐3

Farm Tractors Diesel 2270002066 175 1 21% 625 0.04 0.02 631 1.2E‐02 25 6 5 19 4.8E‐4 1.1E‐3 19 3.7E‐4

Forklift / Manlift Diesel 2270002057 60 3 59% 595 0.03 0.01 601 1.2E‐02 25 6 5 52 1.3E‐3 3.0E‐3 53 1.1E‐3

Bending Machine Diesel 2270002081 85 1 59% 595 0.03 0.01 601 1.2E‐02 25 6 5 25 6.2E‐4 1.4E‐3 25 5.1E‐4

Road Boring Machine Diesel 2270002033 90 1 43% 589 0.03 0.01 594 1.2E‐02 25 6 5 19 4.7E‐4 1.1E‐3 19 3.9E‐4

Fill / Test Pumps Diesel 2270006010 40 2 43% 589 0.03 0.01 595 1.2E‐02 25 6 5 17 4.2E‐4 9.5E‐4 17 3.5E‐4




Welding Machine Diesel 2270006025 40 16 21% 694 0.04 0.02 700 1.2E‐02 25 6 5 77 1.9E‐3 4.4E‐3 78 1.4E‐3

Generator Diesel 2270006005 50 14 43% 589 0.03 0.01 594 1.2E‐02 25 6 5 147 3.7E‐3 8.3E‐3 148 3.1E‐3Misc Saws, Trowel Machine, Compactor Plate, etc.

Diesel 2270002008 50 6 43% 588 0.03 0.01 594 1.2E‐02 25 6 5 63 1.6E‐3 3.5E‐3 63 1.3E‐3


HDD Rig Diesel 2270002033 800 2 43% 530 0.03 0.01 535 5.0E‐3 13 6 12 376 9.4E‐3 0.02 379 3.5E‐3




Load Factor









weeks days/ week

hr/daymi/day




Load Factor

6,313 6,360 2.E‐01










Total


Table 9.B.1.5: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Highland CS2017 Construction Equipment Criteria Pollutant Emissions







hr/daymi/day


Commuter TransitBuses Diesel 2017364323 1 1 1 1.73 5.69 7.7E‐3 0.36 0.23 0.21 11 6 50 6.3E‐3 0.02 2.8E‐5 1.3E‐3 8.5E‐4 7.8E‐4



Passenger Trucks Gasoline 2017363113 1 24 1 7.21 0.93 3.2E‐3 0.12 0.01 0.01 11 6 80 1.01 0.13 4.4E‐4 0.02 1.6E‐3 1.4E‐3

Total 1.25 0.22 9.2E‐4 0.03 5.8E‐3 5.2E‐3


Heavy Trucks Diesel 2017366123 1 ‐ 1 1.36 6.12 0.01 0.23 0.20 0.18 11 6 100 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Clearing 1 1

Dump Trucks Diesel 2017366123 1 2 1 1.36 6.12 0.01 0.23 0.20 0.18 11 6 50 9.9E‐3 0.04 1.0E‐4 1.7E‐3 1.4E‐3 1.3E‐3

Pick‐up Trucks Gasoline 2017363213 1 2 1 7.22 0.91 3.1E‐3 0.11 0.01 9.3E‐3 11 6 50 0.05 6.7E‐3 2.3E‐5 7.8E‐4 7.6E‐5 6.8E‐5

Demolition 1

Pickup Trucks Gasoline 2017363213 1 ‐ 1 7.22 0.91 3.1E‐3 0.11 0.01 9.3E‐3 11 6 50 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Weld Trucks Gasoline 2017363213 1 ‐ 1 7.22 0.91 3.1E‐3 0.11 0.01 9.3E‐3 11 6 50 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Dump Trucks Diesel 2017366123 1 ‐ 1 1.36 6.12 0.01 0.23 0.20 0.18 11 6 50 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Total 0.06 0.05 1.3E‐4 2.5E‐3 1.5E‐3 1.4E‐3

Off Road EquipmentClearing

RT Backhoe Diesel 2270002036 85 1 59% 1.39 1.42 4.3E‐3 0.16 0.17 0.17 11 6 5 0.03 0.03 7.9E‐5 2.9E‐3 3.1E‐3 3.1E‐3

Bobcat Diesel 2270002072 70 1 21% 5.24 5.15 5.9E‐3 1.00 0.79 0.79 11 6 5 0.03 0.03 3.2E‐5 5.4E‐3 4.2E‐3 4.2E‐3

Front End Loader Diesel 2270002069 240 1 59% 0.42 1.28 3.9E‐3 0.15 0.08 0.08 11 6 5 0.02 0.07 2.0E‐4 7.9E‐3 4.0E‐3 4.0E‐3

Roller, 150 HP Diesel 2270002015 150 1 59% 0.74 1.74 4.2E‐3 0.18 0.18 0.18 11 6 5 0.02 0.06 1.3E‐4 5.7E‐3 5.7E‐3 5.7E‐3

Water Pump Diesel 2270006010 100 1 43% 1.16 3.86 4.5E‐3 0.33 0.24 0.24 11 6 5 0.02 0.06 7.0E‐5 5.2E‐3 3.8E‐3 3.8E‐3

DemolitionD‐6 Dozer Diesel 2270002069 140 1 59% 0.61 1.41 4.0E‐3 0.16 0.15 0.15 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Front End Loader Diesel 2270002066 240 1 21% 1.77 3.45 5.1E‐3 0.50 0.34 0.34 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

200T Crane Diesel 2270002045 360 1 43% 0.67 2.58 4.3E‐3 0.18 0.11 0.11 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Weld Rigs Diesel 2270006025 20 1 21% 5.15 5.33 6.4E‐3 1.12 0.71 0.71 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Forklift Diesel 2270002057 25 1 59% 0.73 3.54 4.4E‐3 0.18 0.11 0.11 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Grading

D‐6 Dozer Diesel 2270002069 140 1 59% 0.61 1.41 4.0E‐3 0.16 0.15 0.15 11 6 5 0.02 0.04 1.2E‐4 4.9E‐3 4.4E‐3 4.4E‐3


D‐8 Dozer Diesel 2270002069 305 1 59% 0.78 1.93 4.2E‐3 0.16 0.12 0.12 11 6 5 0.05 0.13 2.7E‐4 0.01 7.9E‐3 7.9E‐3

Cat 330 Diesel 2270002066 268 1 21% 1.77 3.45 5.1E‐3 0.50 0.34 0.34 11 6 5 0.04 0.07 1.0E‐4 0.01 6.9E‐3 6.9E‐3



Load Factor









hr/daymi/day




Load Factor


Paving

Grader Diesel 2270002048 180 1 59% 0.41 1.25 3.9E‐3 0.15 0.08 0.08 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Paver Diesel 2270002003 174 1 59% 0.69 1.61 4.1E‐3 0.17 0.17 0.17 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Roller Diesel 2270002015 150 1 59% 0.74 1.74 4.2E‐3 0.18 0.18 0.18 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

RT Backhoe Diesel 2270002036 85 1 59% 1.39 1.42 4.3E‐3 0.16 0.17 0.17 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Foundations 0 6 5

D‐6 Dozer Diesel 2270002069 140 1 59% 0.61 1.41 4.0E‐3 0.16 0.15 0.15 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


Cat 330 Diesel 2270002066 268 1 21% 1.77 3.45 5.1E‐3 0.50 0.34 0.34 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0



Bobcat Diesel 2270002072 70 1 21% 5.24 5.15 5.9E‐3 1.00 0.79 0.79 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

20T Cherry Picker Diesel 2270002045 75 1 43% 1.36 2.19 4.6E‐3 0.21 0.20 0.20 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Electrical 0


Manlift CNG 2268003010 70 1 48% 21.31 3.83 0.01 12.37 0.06 0.06 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Buildings/Set Equipment 0




Manlift Diesel 2268003010 70 1 48% 21.31 3.83 0.01 12.37 0.06 0.06 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0



Welding ‐ Fabrication 0

Weld rigs Diesel 2270006025 80 7 21% 5.59 4.41 5.8E‐3 0.97 0.81 0.81 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0



Welding ‐ Pipe Install 0





572 Sideboom Diesel 2270002069 240 1 59% 0.42 1.28 3.9E‐3 0.15 0.08 0.08 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Testing 0

Fill Pump Diesel 2270006010 150 1 43% 1.16 3.86 4.5E‐3 0.33 0.24 0.24 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0









hr/daymi/day




Load Factor

Test Pump Diesel 2270006010 75 1 43% 2.21 3.98 5.0E‐3 0.44 0.40 0.40 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


0.27 0.61 1.4E‐3 0.07 0.05 0.05





Total


Table 9.B.1.6: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Highland CS2017 Construction Equipment Greenhouse Gas and Hazardous Air Pollutant Emissions







weeks days/ week

hr/daymi/day






Total 131 0.0E+0 0.0E+0 131 7.0E‐3


Heavy Trucks Diesel 2017366123 1 ‐ 1 1,635 1,636 0.05 11 6 100 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Clearing 1 ‐ 1

Dump Trucks Diesel 2017366123 1 2 1 1,635 1,636 0.18 11 6 50 12 0.0E+0 0.0E+0 12 1.3E‐3

Pick‐up Trucks Gasoline 2017363213 1 2 1 471 473 0.03 11 6 50 3 0.0E+0 0.0E+0 3 2.1E‐4

Demolition 1 0

Pickup Trucks Gasoline 2017363213 1 ‐ 1 471 473 0.03 11 6 50 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Weld Trucks Gasoline 2017363213 1 ‐ 1 471 473 0.03 11 6 50 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Dump Trucks Diesel 2017366123 1 ‐ 1 1,635 1,636 0.05 11 6 50 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Total 0 15 0.0E+0 0.0E+0 15 1.5E‐3


RT Backhoe Diesel 2270002036 85 1 59% 596 0.03 0.01 601 1.2E‐02 11 6 5 11 2.7E‐4 6.1E‐4 11 2.2E‐4

Bobcat Diesel 2270002072 70 1 21% 693 0.04 0.02 699 1.2E‐02 11 6 5 4 9.3E‐5 2.1E‐4 4 6.6E‐5

Front End Loader Diesel 2270002069 240 1 59% 536 0.03 0.01 541 1.2E‐02 11 6 5 28 6.9E‐4 1.6E‐3 28 6.3E‐4

Roller, 150 HP Diesel 2270002015 150 1 59% 536 0.03 0.01 541 1.2E‐02 11 6 5 17 4.3E‐4 9.7E‐4 17 4.0E‐4

Water Pump Diesel 2270006010 100 1 43% 530 0.03 0.01 535 1.2E‐02 11 6 5 8 2.1E‐4 4.7E‐4 8 1.9E‐4

DemolitionD‐6 Dozer Diesel 2270002069 140 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Front End Loader Diesel 2270002066 240 1 21% 625 0.04 0.02 631 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

200T Crane Diesel 2270002045 360 1 43% 530 0.03 0.01 535 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Weld Rigs Diesel 2270006025 20 1 21% 692 0.04 0.02 699 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Forklift Diesel 2270002057 25 1 59% 596 0.03 0.01 601 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

GradingD‐6 Dozer Diesel 2270002069 140 1 59% 536 0.03 0.01 541 1.2E‐02 11 6 5 16 4.0E‐4 9.1E‐4 16 3.7E‐4

D‐7 Dozer Diesel 2270002069 240 1 59% 536 0.03 0.01 541 1.2E‐02 11 6 5 28 6.9E‐4 1.6E‐3 28 6.3E‐4


Cat 330 Diesel 2270002066 268 1 21% 625 0.04 0.02 631 1.2E‐02 11 6 5 13 3.2E‐4 7.2E‐4 13 2.5E‐4



Load Factor









weeks days/ week

hr/daymi/day




Load Factor


PavingGrader Diesel 2270002048 180 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Paver Diesel 2270002003 174 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Roller Diesel 2270002015 150 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

RT Backhoe Diesel 2270002036 85 1 59% 596 0.03 0.01 601 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Foundations D‐6 Dozer Diesel 2270002069 140 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0


Cat 330 Diesel 2270002066 268 1 21% 625 0.04 0.02 631 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Cat 318 Diesel 2270002066 125 1 21% 625 0.04 0.02 630 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0


Bobcat Diesel 2270002072 70 1 21% 693 0.04 0.02 699 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

20T Cherry Picker Diesel 2270002045 75 1 43% 590 0.03 0.01 595 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Electrical RT Backhoe Diesel 2270002036 85 1 59% 596 0.03 0.01 601 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Manlift CNG 2268003010 70 1 48% 478 9.0E‐3 9.0E‐4 479 2.3E‐01 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Buildings/Set Equipment 40T Crane Diesel 2270002045 125 1 43% 530 0.03 0.01 535 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0



Manlift Diesel 2268003010 70 1 48% 478 0.03 0.01 483 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0



Welding ‐ FabricationWeld rigs Diesel 2270006025 80 7 21% 693 0.04 0.02 699 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0



Welding ‐ Pipe InstallWeld rigs Diesel 2270006025 80 5 21% 693 0.04 0.02 699 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Cat 330 Diesel 2270002066 268 1 21% 625 0.04 0.02 631 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Cat 318 Diesel 2270002066 125 1 21% 625 0.04 0.02 630 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0


572 Sideboom Diesel 2270002069 240 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

TestingFill Pump Diesel 2270006010 150 1 43% 530 0.03 0.01 535 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0









weeks days/ week

hr/daymi/day




Load Factor

Test Pump Diesel 2270006010 75 1 43% 589 0.03 0.01 594 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0


187 189 4.2E‐3










Total









hr/daymi/day



Light Trucks Diesel 2018363223 1 4 1 0.93 1.53 5.7E‐3 0.21 0.08 0.07 25 6 100 0.06 0.10 3.8E‐4 0.01 5.0E‐3 4.6E‐3



Total 2.70 0.45 2.1E‐3 0.05 0.01 0.01


Heavy Trucks Diesel 2018366123 1 4 1 1.17 5.23 0.01 0.20 0.16 0.15 25 6 100 0.08 0.35 9.4E‐4 0.01 0.01 9.6E‐3

Clearing 1 1


Pick‐up Trucks Gasoline 2018363213 1 ‐ 1 6.88 0.81 3.1E‐3 0.09 9.9E‐3 8.8E‐3 25 6 50 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Demolition 1 1

Pickup Trucks Gasoline 2018363213 1 ‐ 1 6.88 0.81 3.1E‐3 0.09 9.9E‐3 8.8E‐3 25 6 50 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Weld Trucks Gasoline 2018363213 1 ‐ 1 6.88 0.81 3.1E‐3 0.09 9.9E‐3 8.8E‐3 25 6 50 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


Total 0.08 0.35 9.4E‐4 0.01 0.01 9.6E‐3





Roller, 150 HP Diesel 2270002015 150 1 59% 0.64 1.48 4.0E‐3 0.17 0.15 0.15 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Water Pump Diesel 2270006010 100 1 43% 1.06 3.59 4.4E‐3 0.31 0.23 0.23 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Demolition 0 6 5






Grading 0 6 5







Load Factor









hr/daymi/day




Load Factor


Paving

Grader Diesel 2270002048 180 1 59% 0.31 1.01 3.8E‐3 0.15 0.05 0.05 25 6 5 0.03 0.09 3.3E‐4 0.01 4.7E‐3 4.7E‐3

Paver Diesel 2270002003 174 1 59% 0.58 1.35 4.0E‐3 0.16 0.14 0.14 25 6 5 0.05 0.11 3.4E‐4 0.01 0.01 0.01

Roller Diesel 2270002015 150 1 59% 0.64 1.48 4.0E‐3 0.17 0.15 0.15 25 6 5 0.05 0.11 3.0E‐4 0.01 0.01 0.01


Foundations

D‐6 Dozer Diesel 2270002069 140 1 59% 0.49 1.16 3.9E‐3 0.15 0.11 0.11 25 6 5 0.03 0.08 2.7E‐4 0.01 7.7E‐3 7.7E‐3

Front End Loader Diesel 2270002069 240 1 59% 0.32 1.04 3.8E‐3 0.15 0.06 0.06 25 6 5 0.04 0.12 4.4E‐4 0.02 6.6E‐3 6.6E‐3

Cat 330 Diesel 2270002066 268 1 21% 1.61 3.15 5.0E‐3 0.46 0.31 0.31 25 6 5 0.08 0.15 2.3E‐4 0.02 0.01 0.01

Cat 318 Diesel 2270002066 125 1 21% 1.96 3.34 5.1E‐3 0.52 0.40 0.40 25 6 5 0.04 0.07 1.1E‐4 0.01 8.8E‐3 8.8E‐3


Bobcat Diesel 2270002072 70 1 21% 4.90 4.98 5.9E‐3 0.93 0.73 0.73 25 6 5 0.06 0.06 7.1E‐5 0.01 8.9E‐3 8.9E‐3

20T Cherry Picker Diesel 2270002045 75 1 43% 1.18 1.85 4.5E‐3 0.19 0.17 0.17 25 6 5 0.03 0.05 1.2E‐4 5.0E‐3 4.6E‐3 4.6E‐3

Electrical


Manlift CNG 2268003010 70 1 48% 19.15 3.35 0.01 10.81 0.06 0.06 25 6 5 0.53 0.09 2.9E‐4 0.30 1.6E‐3 1.6E‐3

Buildings/Set Equipment

40T Crane Diesel 2270002045 125 1 43% 0.44 1.55 4.0E‐3 0.17 0.11 0.11 25 6 5 0.02 0.07 1.8E‐4 7.5E‐3 4.9E‐3 4.9E‐3


200T Crane Diesel 2270002045 360 1 43% 0.60 2.31 4.2E‐3 0.17 0.10 0.10 25 6 5 0.08 0.30 5.4E‐4 0.02 0.01 0.01

Manlift Diesel 2268003010 70 1 48% 19.15 3.35 0.01 10.81 0.06 0.06 25 6 5 0.53 0.09 2.9E‐4 0.30 1.6E‐3 1.6E‐3


Forklift Diesel 2270002057 25 1 59% 0.55 3.35 4.2E‐3 0.16 0.08 0.08 25 6 5 6.7E‐3 0.04 5.2E‐5 2.0E‐3 9.4E‐4 9.4E‐4

Welding ‐ Fabrication

Weld rigs Diesel 2270006025 80 7 21% 5.25 4.13 5.8E‐3 0.90 0.75 0.75 25 6 5 0.51 0.40 5.6E‐4 0.09 0.07 0.07



Welding ‐ Pipe Install


Cat 330 Diesel 2270002066 268 1 21% 1.61 3.15 5.0E‐3 0.46 0.31 0.31 25 6 5 0.08 0.15 2.3E‐4 0.02 0.01 0.01

Cat 318 Diesel 2270002066 125 1 21% 1.96 3.34 5.1E‐3 0.52 0.40 0.40 25 6 5 0.04 0.07 1.1E‐4 0.01 8.8E‐3 8.8E‐3










hr/daymi/day




Load Factor

572 Sideboom Diesel 2270002069 240 1 59% 0.32 1.04 3.8E‐3 0.15 0.06 0.06 25 6 5 0.04 0.12 4.4E‐4 0.02 6.6E‐3 6.6E‐3

Testing

Fill Pump Diesel 2270006010 150 1 43% 1.06 3.59 4.4E‐3 0.31 0.23 0.23 25 6 5 0.06 0.19 2.4E‐4 0.02 0.01 0.01

Test Pump Diesel 2270006010 75 1 43% 2.08 3.73 4.9E‐3 0.42 0.38 0.38 25 6 5 0.06 0.10 1.3E‐4 0.01 0.01 0.01


3.04 3.24 7.3E‐3 1.03 0.32 0.32





Total









weeks days/ week

hr/daymi/day






Total 293 0.0E+0 0.0E+0 294 0.01



ClearingDump Trucks Diesel 2018366123 1 ‐ 1 1,619 1,620 0.04 25 6 50 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Pick‐up Trucks Gasoline 2018363213 1 ‐ 1 467 469 0.03 25 6 50 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

DemolitionPickup Trucks Gasoline 2018363213 1 ‐ 1 467 469 0.03 25 6 50 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0



Total 0 107 0.0E+0 0.0E+0 107 2.7E‐3





Roller, 150 HP Diesel 2270002015 150 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Water Pump Diesel 2270006010 100 1 43% 530 0.03 0.01 535 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0






GradingD‐6 Dozer Diesel 2270002069 140 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

D‐7 Dozer Diesel 2270002069 240 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0


Cat 330 Diesel 2270002066 268 1 21% 625 0.04 0.02 631 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Load Factor











weeks days/ week

hr/daymi/day


Load Factor




PavingGrader Diesel 2270002048 180 1 59% 536 0.03 0.01 541 1.2E‐02 25 6 5 47 1.2E‐3 2.7E‐3 48 1.1E‐3

Paver Diesel 2270002003 174 1 59% 536 0.03 0.01 541 1.2E‐02 25 6 5 46 1.1E‐3 2.6E‐3 46 1.0E‐3

Roller Diesel 2270002015 150 1 59% 536 0.03 0.01 541 1.2E‐02 25 6 5 39 9.8E‐4 2.2E‐3 40 9.0E‐4


Foundations D‐6 Dozer Diesel 2270002069 140 1 59% 536 0.03 0.01 541 1.2E‐02 25 6 5 37 9.2E‐4 2.1E‐3 37 8.4E‐4


Cat 330 Diesel 2270002066 268 1 21% 625 0.04 0.02 631 1.2E‐02 25 6 5 29 7.3E‐4 1.6E‐3 29 5.7E‐4

Cat 318 Diesel 2270002066 125 1 21% 625 0.04 0.02 630 1.2E‐02 25 6 5 14 3.4E‐4 7.7E‐4 14 2.7E‐4



20T Cherry Picker Diesel 2270002045 75 1 43% 590 0.03 0.01 595 1.2E‐02 25 6 5 16 3.9E‐4 8.9E‐4 16 3.3E‐4

Electrical RT Backhoe Diesel 2270002036 85 1 59% 596 0.03 0.01 601 1.2E‐02 25 6 5 25 6.2E‐4 1.4E‐3 25 5.1E‐4

Manlift CNG 2268003010 70 1 48% 478 9.0E‐3 9.0E‐4 478 2.3E‐01 25 6 5 13 2.5E‐5 2.5E‐4 13 6.4E‐3

Buildings/Set Equipment 40T Crane Diesel 2270002045 125 1 43% 531 0.03 0.01 535 1.2E‐02 25 6 5 24 5.9E‐4 1.3E‐3 24 5.5E‐4


200T Crane Diesel 2270002045 360 1 43% 530 0.03 0.01 535 1.2E‐02 25 6 5 68 1.7E‐3 3.8E‐3 68 1.6E‐3

Manlift Diesel 2268003010 70 1 48% 478 0.03 0.01 482 1.2E‐02 25 6 5 13 3.3E‐4 7.5E‐4 13 3.4E‐4


Forklift Diesel 2270002057 25 1 59% 596 0.03 0.01 601 1.2E‐02 25 6 5 7 1.8E‐4 4.1E‐4 7 1.5E‐4

Welding ‐ FabricationWeld rigs Diesel 2270006025 80 7 21% 693 0.04 0.02 699 1.2E‐02 25 6 5 67 1.7E‐3 3.8E‐3 68 1.2E‐3



Welding ‐ Pipe InstallWeld rigs Diesel 2270006025 80 5 21% 693 0.04 0.02 699 1.2E‐02 25 6 5 48 1.2E‐3 2.7E‐3 49 8.5E‐4

Cat 330 Diesel 2270002066 268 1 21% 625 0.04 0.02 631 1.2E‐02 25 6 5 29 7.3E‐4 1.6E‐3 29 5.7E‐4

Cat 318 Diesel 2270002066 125 1 21% 625 0.04 0.02 630 1.2E‐02 25 6 5 14 3.4E‐4 7.7E‐4 14 2.7E‐4










weeks days/ week

hr/daymi/day


Load Factor



572 Sideboom Diesel 2270002069 240 1 59% 536 0.03 0.01 541 1.2E‐02 25 6 5 63 1.6E‐3 3.5E‐3 63 1.4E‐3

TestingFill Pump Diesel 2270006010 150 1 43% 530 0.03 0.01 535 1.2E‐02 25 6 5 28 7.1E‐4 1.6E‐3 29 6.6E‐4

Test Pump Diesel 2270006010 75 1 43% 589 0.03 0.01 594 1.2E‐02 25 6 5 16 3.9E‐4 8.9E‐4 16 3.3E‐4


913 921 0.03










Total


Table 9.B.1.9: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Hancock CS2017 Construction Equipment Criteria Pollutant Emissions







hr/daymi/day


Commuter TransitBuses Diesel 2017364323 1 1 1 1.73 5.69 7.7E‐3 0.36 0.23 0.21 4 6 50 2.3E‐3 7.5E‐3 1.0E‐5 4.8E‐4 3.1E‐4 2.8E‐4


Passenger Cars Gasoline 2017362113 1 24 1 1.49 0.16 2.0E‐3 0.02 5.3E‐3 4.7E‐3 4 6 80 0.08 8.2E‐3 1.0E‐4 1.2E‐3 2.7E‐4 2.4E‐4

Passenger Trucks Gasoline 2017363113 1 24 1 7.21 0.93 3.2E‐3 0.12 0.01 0.01 4 6 80 0.37 0.05 1.6E‐4 5.9E‐3 5.7E‐4 5.1E‐4

Total 0.46 0.08 3.3E‐4 0.01 2.1E‐3 1.9E‐3


Heavy Trucks Diesel 2017366123 1 ‐ 1 1.36 6.12 0.01 0.23 0.20 0.18 4 6 100 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Clearing 1 1

Dump Trucks Diesel 2017366123 1 2 1 1.36 6.12 0.01 0.23 0.20 0.18 4 6 50 3.6E‐3 0.02 3.8E‐5 6.1E‐4 5.2E‐4 4.8E‐4

Pick‐up Trucks Gasoline 2017363213 1 2 1 7.22 0.91 3.1E‐3 0.11 0.01 9.3E‐3 4 6 50 0.02 2.4E‐3 8.3E‐6 2.8E‐4 2.8E‐5 2.5E‐5

Demolition 1

Pickup Trucks Gasoline 2017363213 1 ‐ 1 7.22 0.91 3.1E‐3 0.11 0.01 9.3E‐3 4 6 50 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Weld Trucks Gasoline 2017363213 1 ‐ 1 7.22 0.91 3.1E‐3 0.11 0.01 9.3E‐3 4 6 50 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


Total 0.02 0.02 4.6E‐5 9.0E‐4 5.5E‐4 5.0E‐4


RT Backhoe Diesel 2270002036 85 1 59% 1.39 1.42 4.3E‐3 0.16 0.17 0.17 4 6 5 9.2E‐3 9.4E‐3 2.9E‐5 1.1E‐3 1.1E‐3 1.1E‐3


Front End Loader Diesel 2270002069 240 1 59% 0.42 1.28 3.9E‐3 0.15 0.08 0.08 4 6 5 7.9E‐3 0.02 7.3E‐5 2.9E‐3 1.5E‐3 1.5E‐3

Roller, 150 HP Diesel 2270002015 150 1 59% 0.74 1.74 4.2E‐3 0.18 0.18 0.18 4 6 5 8.6E‐3 0.02 4.9E‐5 2.1E‐3 2.1E‐3 2.1E‐3

Water Pump Diesel 2270006010 100 1 43% 1.16 3.86 4.5E‐3 0.33 0.24 0.24 4 6 5 6.6E‐3 0.02 2.5E‐5 1.9E‐3 1.4E‐3 1.4E‐3

DemolitionD‐6 Dozer Diesel 2270002069 140 1 59% 0.61 1.41 4.0E‐3 0.16 0.15 0.15 4 6 5 6.7E‐3 0.02 4.4E‐5 1.8E‐3 1.6E‐3 1.6E‐3



Weld Rigs Diesel 2270006025 20 1 21% 5.15 5.33 6.4E‐3 1.12 0.71 0.71 4 6 5 2.9E‐3 3.0E‐3 3.5E‐6 6.2E‐4 4.0E‐4 4.0E‐4

Forklift Diesel 2270002057 25 1 59% 0.73 3.54 4.4E‐3 0.18 0.11 0.11 4 6 5 1.4E‐3 6.9E‐3 8.6E‐6 3.5E‐4 2.1E‐4 2.1E‐4

Grading

D‐6 Dozer Diesel 2270002069 140 1 59% 0.61 1.41 4.0E‐3 0.16 0.15 0.15 4 6 5 6.7E‐3 0.02 4.4E‐5 1.8E‐3 1.6E‐3 1.6E‐3

D‐7 Dozer Diesel 2270002069 240 1 59% 0.42 1.28 3.9E‐3 0.15 0.08 0.08 4 6 5 7.9E‐3 0.02 7.3E‐5 2.9E‐3 1.5E‐3 1.5E‐3


Cat 330 Diesel 2270002066 268 1 21% 1.77 3.45 5.1E‐3 0.50 0.34 0.34 4 6 5 0.01 0.03 3.8E‐5 3.7E‐3 2.5E‐3 2.5E‐3



Load Factor









hr/daymi/day




Load Factor

Front End Loader Diesel 2270002069 240 1 59% 0.42 1.28 3.9E‐3 0.15 0.08 0.08 4 6 5 7.9E‐3 0.02 7.3E‐5 2.9E‐3 1.5E‐3 1.5E‐3

Paving

Grader Diesel 2270002048 180 1 59% 0.41 1.25 3.9E‐3 0.15 0.08 0.08 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Paver Diesel 2270002003 174 1 59% 0.69 1.61 4.1E‐3 0.17 0.17 0.17 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Roller Diesel 2270002015 150 1 59% 0.74 1.74 4.2E‐3 0.18 0.18 0.18 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


Foundations 0 6 5



Cat 330 Diesel 2270002066 268 1 21% 1.77 3.45 5.1E‐3 0.50 0.34 0.34 0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0



Bobcat Diesel 2270002072 70 1 21% 5.24 5.15 5.9E‐3 1.00 0.79 0.79 0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


Electrical 0 6 5


Manlift CNG 2268003010 70 1 48% 21.31 3.83 0.01 12.37 0.06 0.06 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Buildings/Set Equipment 0 6 5


20T Cherry Picker Diesel 2270002045 75 1 43% 1.36 2.19 4.6E‐3 0.21 0.20 0.20 0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


Manlift Diesel 2268003010 70 1 48% 21.31 3.83 0.01 12.37 0.06 0.06 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


Forklift Diesel 2270002057 25 1 59% 0.73 3.54 4.4E‐3 0.18 0.11 0.11 0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Welding ‐ Fabrication 0 6 5




Welding ‐ Pipe Install 0 6 5

Weld rigs Diesel 2270006025 80 5 21% 5.59 4.41 5.8E‐3 0.97 0.81 0.81 0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0




572 Sideboom Diesel 2270002069 240 1 59% 0.42 1.28 3.9E‐3 0.15 0.08 0.08 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Testing 0 6 5

Fill Pump Diesel 2270006010 150 1 43% 1.16 3.86 4.5E‐3 0.33 0.24 0.24 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0









hr/daymi/day




Load Factor

Test Pump Diesel 2270006010 75 1 43% 2.21 3.98 5.0E‐3 0.44 0.40 0.40 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


0.13 0.32 6.9E‐4 0.03 0.02 0.02





Total


Table 9.B.1.10: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Hancock CS2017 Construction Equipment Greenhouse Gas and Hazardous Air Pollutant Emissions







weeks days/ week

hr/daymi/day






Total 47 0.0E+0 0.0E+0 48 2.5E‐3


Heavy Trucks Diesel 2017366123 1 ‐ 1 1,635 1,636 0.05 4 6 100 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Clearing 1 ‐ 1


Pick‐up Trucks Gasoline 2017363213 1 2 1 471 473 0.03 4 6 50 1 0.0E+0 0.0E+0 1 7.8E‐5

Demolition 1 0

Pickup Trucks Gasoline 2017363213 1 ‐ 1 471 473 0.03 4 6 50 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0



Total 0 6 0.0E+0 0.0E+0 6 5.6E‐4





Roller, 150 HP Diesel 2270002015 150 1 59% 536 0.03 0.01 541 1.2E‐02 4 6 5 6 1.6E‐4 3.5E‐4 6 1.4E‐4

Water Pump Diesel 2270006010 100 1 43% 530 0.03 0.01 535 1.2E‐02 4 6 5 3 7.6E‐5 1.7E‐4 3 7.0E‐5

DemolitionD‐6 Dozer Diesel 2270002069 140 1 59% 536 0.03 0.01 541 1.2E‐02 4 6 5 6 1.5E‐4 3.3E‐4 6 1.3E‐4



Weld Rigs Diesel 2270006025 20 1 21% 692 0.04 0.02 699 1.2E‐02 4 6 5 0 9.6E‐6 2.2E‐5 0 6.8E‐6


GradingD‐6 Dozer Diesel 2270002069 140 1 59% 536 0.03 0.01 541 1.2E‐02 4 6 5 6 1.5E‐4 3.3E‐4 6 1.3E‐4



Cat 330 Diesel 2270002066 268 1 21% 625 0.04 0.02 631 1.2E‐02 4 6 5 5 1.2E‐4 2.6E‐4 5 9.2E‐5



Load Factor









weeks days/ week

hr/daymi/day




Load Factor


PavingGrader Diesel 2270002048 180 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Paver Diesel 2270002003 174 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Roller Diesel 2270002015 150 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0


Foundations D‐6 Dozer Diesel 2270002069 140 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0


Cat 330 Diesel 2270002066 268 1 21% 625 0.04 0.02 631 1.2E‐02 0 0 0 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Cat 318 Diesel 2270002066 125 1 21% 625 0.04 0.02 630 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0




Electrical RT Backhoe Diesel 2270002036 85 1 59% 596 0.03 0.01 601 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Manlift CNG 2268003010 70 1 48% 478 9.0E‐3 9.0E‐4 479 2.3E‐01 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Buildings/Set Equipment 40T Crane Diesel 2270002045 125 1 43% 530 0.03 0.01 535 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0



Manlift Diesel 2268003010 70 1 48% 478 0.03 0.01 483 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0



Welding ‐ FabricationWeld rigs Diesel 2270006025 80 7 21% 693 0.04 0.02 699 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0



Welding ‐ Pipe InstallWeld rigs Diesel 2270006025 80 5 21% 693 0.04 0.02 699 1.2E‐02 0 0 0 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Cat 330 Diesel 2270002066 268 1 21% 625 0.04 0.02 631 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Cat 318 Diesel 2270002066 125 1 21% 625 0.04 0.02 630 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0


572 Sideboom Diesel 2270002069 240 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

TestingFill Pump Diesel 2270006010 150 1 43% 530 0.03 0.01 535 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0









weeks days/ week

hr/daymi/day




Load Factor

Test Pump Diesel 2270006010 75 1 43% 589 0.03 0.01 594 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0


90 91 2.0E‐3










Total









hr/daymi/day






Total 1.84 0.30 1.4E‐3 0.04 7.8E‐3 7.1E‐3


Heavy Trucks Diesel 2018366123 1 4 1 1.17 5.23 0.01 0.20 0.16 0.15 17 6 100 0.05 0.24 6.4E‐4 8.9E‐3 7.1E‐3 6.5E‐3

Clearing 1 1


Pick‐up Trucks Gasoline 2018363213 1 ‐ 1 6.88 0.81 3.1E‐3 0.09 9.9E‐3 8.8E‐3 17 6 50 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Demolition 1 1

Pickup Trucks Gasoline 2018363213 1 4 1 6.88 0.81 3.1E‐3 0.09 9.9E‐3 8.8E‐3 17 6 50 0.15 0.02 7.0E‐5 2.0E‐3 2.2E‐4 2.0E‐4

Weld Trucks Gasoline 2018363213 1 2 1 6.88 0.81 3.1E‐3 0.09 9.9E‐3 8.8E‐3 17 6 50 0.08 9.1E‐3 3.5E‐5 1.0E‐3 1.1E‐4 9.9E‐5

Dump Trucks Diesel 2018366123 1 2 1 1.17 5.23 0.01 0.20 0.16 0.15 17 6 50 0.01 0.06 1.6E‐4 2.2E‐3 1.8E‐3 1.6E‐3

Total 0.30 0.32 9.0E‐4 0.01 9.2E‐3 8.5E‐3





Roller, 150 HP Diesel 2270002015 150 1 59% 0.64 1.48 4.0E‐3 0.17 0.15 0.15 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Water Pump Diesel 2270006010 100 1 43% 1.06 3.59 4.4E‐3 0.31 0.23 0.23 0 6 5 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0 0.0E+0

Demolition 0 6 5






Grading 0 6 5







Load Factor









hr/daymi/day




Load Factor


Paving

Grader Diesel 2270002048 180 1 59% 0.31 1.01 3.8E‐3 0.15 0.05 0.05 17 6 5 0.02 0.06 2.2E‐4 8.7E‐3 3.2E‐3 3.2E‐3

Paver Diesel 2270002003 174 1 59% 0.58 1.35 4.0E‐3 0.16 0.14 0.14 17 6 5 0.03 0.08 2.3E‐4 9.4E‐3 7.8E‐3 7.8E‐3

Roller Diesel 2270002015 150 1 59% 0.64 1.48 4.0E‐3 0.17 0.15 0.15 17 6 5 0.03 0.07 2.0E‐4 8.4E‐3 7.5E‐3 7.5E‐3


Foundations



Cat 330 Diesel 2270002066 268 1 21% 1.61 3.15 5.0E‐3 0.46 0.31 0.31 17 6 5 0.05 0.10 1.6E‐4 0.01 9.8E‐3 9.8E‐3

Cat 318 Diesel 2270002066 125 1 21% 1.96 3.34 5.1E‐3 0.52 0.40 0.40 17 6 5 0.03 0.05 7.5E‐5 7.7E‐3 6.0E‐3 6.0E‐3




Electrical


Manlift CNG 2268003010 70 1 48% 19.15 3.35 0.01 10.81 0.06 0.06 17 6 5 0.36 0.06 2.0E‐4 0.20 1.1E‐3 1.1E‐3




200T Crane Diesel 2270002045 360 1 43% 0.60 2.31 4.2E‐3 0.17 0.10 0.10 17 6 5 0.05 0.20 3.6E‐4 0.01 8.5E‐3 8.5E‐3








Welding ‐ Pipe Install


Cat 330 Diesel 2270002066 268 1 21% 1.61 3.15 5.0E‐3 0.46 0.31 0.31 17 6 5 0.05 0.10 1.6E‐4 0.01 9.8E‐3 9.8E‐3

Cat 318 Diesel 2270002066 125 1 21% 1.96 3.34 5.1E‐3 0.52 0.40 0.40 17 6 5 0.03 0.05 7.5E‐5 7.7E‐3 6.0E‐3 6.0E‐3










hr/daymi/day




Load Factor

572 Sideboom Diesel 2270002069 240 1 59% 0.32 1.04 3.8E‐3 0.15 0.06 0.06 17 6 5 0.03 0.08 3.0E‐4 0.01 4.5E‐3 4.5E‐3

Testing

Fill Pump Diesel 2270006010 150 1 43% 1.06 3.59 4.4E‐3 0.31 0.23 0.23 17 6 5 0.04 0.13 1.6E‐4 0.01 8.3E‐3 8.3E‐3

Test Pump Diesel 2270006010 75 1 43% 2.08 3.73 4.9E‐3 0.42 0.38 0.38 17 6 5 0.04 0.07 8.9E‐5 7.6E‐3 6.8E‐3 6.8E‐3


2.06 2.20 4.9E‐3 0.70 0.22 0.22





Total









weeks days/ week

hr/daymi/day






Total 199 0.0E+0 0.0E+0 200 9.1E‐3



ClearingDump Trucks Diesel 2018366123 1 ‐ 1 1,619 1,620 0.04 17 6 50 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Pick‐up Trucks Gasoline 2018363213 1 ‐ 1 467 469 0.03 17 6 50 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

DemolitionPickup Trucks Gasoline 2018363213 1 4 1 467 469 0.03 17 6 50 10 0.0E+0 0.0E+0 11 5.6E‐4

Weld Trucks Gasoline 2018363213 1 2 1 467 469 0.03 17 6 50 5 0.0E+0 0.0E+0 5 2.8E‐4


Total 0 107 0.0E+0 0.0E+0 107 3.1E‐3





Roller, 150 HP Diesel 2270002015 150 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0

Water Pump Diesel 2270006010 100 1 43% 530 0.03 0.01 535 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0






GradingD‐6 Dozer Diesel 2270002069 140 1 59% 536 0.03 0.01 541 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0



Cat 330 Diesel 2270002066 268 1 21% 625 0.04 0.02 631 1.2E‐02 0 6 5 ‐ 0.0E+0 0.0E+0 ‐ 0.0E+0



Load Factor









weeks days/ week

hr/daymi/day




Load Factor


PavingGrader Diesel 2270002048 180 1 59% 536 0.03 0.01 541 1.2E‐02 17 6 5 32 8.0E‐4 1.8E‐3 32 7.3E‐4

Paver Diesel 2270002003 174 1 59% 536 0.03 0.01 541 1.2E‐02 17 6 5 31 7.8E‐4 1.7E‐3 31 7.1E‐4

Roller Diesel 2270002015 150 1 59% 536 0.03 0.01 541 1.2E‐02 17 6 5 27 6.7E‐4 1.5E‐3 27 6.1E‐4


Foundations D‐6 Dozer Diesel 2270002069 140 1 59% 536 0.03 0.01 541 1.2E‐02 17 6 5 25 6.2E‐4 1.4E‐3 25 5.7E‐4


Cat 330 Diesel 2270002066 268 1 21% 625 0.04 0.02 631 1.2E‐02 17 6 5 20 5.0E‐4 1.1E‐3 20 3.9E‐4

Cat 318 Diesel 2270002066 125 1 21% 625 0.04 0.02 630 1.2E‐02 17 6 5 9 2.3E‐4 5.2E‐4 9 1.8E‐4




Electrical RT Backhoe Diesel 2270002036 85 1 59% 596 0.03 0.01 601 1.2E‐02 17 6 5 17 4.2E‐4 9.5E‐4 17 3.5E‐4


Buildings/Set Equipment 40T Crane Diesel 2270002045 125 1 43% 531 0.03 0.01 535 1.2E‐02 17 6 5 16 4.0E‐4 9.0E‐4 16 3.7E‐4



Manlift Diesel 2268003010 70 1 48% 478 0.03 0.01 482 1.2E‐02 17 6 5 9 2.3E‐4 5.1E‐4 9 2.3E‐4






Welding ‐ Pipe InstallWeld rigs Diesel 2270006025 80 5 21% 693 0.04 0.02 699 1.2E‐02 17 6 5 33 8.2E‐4 1.8E‐3 33 5.8E‐4

Cat 330 Diesel 2270002066 268 1 21% 625 0.04 0.02 631 1.2E‐02 17 6 5 20 5.0E‐4 1.1E‐3 20 3.9E‐4

Cat 318 Diesel 2270002066 125 1 21% 625 0.04 0.02 630 1.2E‐02 17 6 5 9 2.3E‐4 5.2E‐4 9 1.8E‐4










weeks days/ week

hr/daymi/day




Load Factor

572 Sideboom Diesel 2270002069 240 1 59% 536 0.03 0.01 541 1.2E‐02 17 6 5 43 1.1E‐3 2.4E‐3 43 9.8E‐4

TestingFill Pump Diesel 2270006010 150 1 43% 530 0.03 0.01 535 1.2E‐02 17 6 5 19 4.8E‐4 1.1E‐3 19 4.5E‐4

Test Pump Diesel 2270006010 75 1 43% 589 0.03 0.01 594 1.2E‐02 17 6 5 11 2.7E‐4 6.0E‐4 11 2.2E‐4


621 626 0.02










Total


Table 9.B.1.13: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Ramapo M&R2018 Construction Equipment Criteria Pollutant Emissions

Nonroad Equipment Type/ On Road Vehicle Type






hr/daymi/day





Passenger Trucks Gasoline 2018363113 1 12 1 6.88 0.82 3.1E‐3 0.10 0.01 9.4E‐3 13 6 80 0.57 0.07 2.6E‐4 8.1E‐3 8.7E‐4 7.7E‐4

Total 0.71 0.13 5.5E‐4 0.01 3.4E‐3 3.1E‐3


Heavy Trucks Diesel 2018366123 1 1 1 1.17 5.23 0.01 0.20 0.16 0.15 13 1 100 1.7E‐3 7.5E‐3 2.0E‐5 2.8E‐4 2.3E‐4 2.1E‐4

Total 1.7E‐3 7.5E‐3 2.0E‐5 2.8E‐4 2.3E‐4 2.1E‐4

Off Road EquipmentElectrical


Manlift CNG 2268003010 70 1 48% 19.15 3.35 0.01 10.81 0.06 0.06 13 6 5 0.28 0.05 1.5E‐4 0.16 8.2E‐4 8.2E‐4





Weld rigs Diesel 2270006025 80 1 21% 5.25 4.13 5.8E‐3 0.90 0.75 0.75 13 6 5 0.04 0.03 4.2E‐5 6.5E‐3 5.4E‐3 5.4E‐3


0.62 0.19 4.9E‐4 0.32 0.01 0.01







Load Factor

Total


Table 9.B.1.14: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Ramapo M&R2018 Construction Equipment Greenhouse Gas and Hazardous Air Pollutant Emissions

Nonroad Equipment Type/ On Road Vehicle Type






weeks days/ week

hr/daymi/day






Total 78 0.0E+0 0.0E+0 78 3.6E‐3



Total 0 2 0.0E+0 0.0E+0 2 5.8E‐5

Off Road EquipmentElectrical



Buildings/Set Equipment Manlift Diesel 2268003010 70 1 48% 478 0.03 0.01 482 1.2E‐02 13 6 5 7 1.7E‐4 3.9E‐4 7 1.8E‐4




39 39 4.0E‐3












Load Factor

Total


Acres AffectedConstruction Area 89.3Access roads 5.3

69.6

Dust Control Efficiency1 50%

Activity Emission Factor(ton/acre‐month)

Reference Duration(months)

Uncontrolled Emissions(tons)

ControlledEmissions(tons)

PM10 PM2.5 PM10 PM2.5 PM10 PM2.5

Construction 1.10E‐01 1.10E‐02 2, 3 2.5 24.55 2.45 12.27 1.23Wind erosion

Construction area 1.58E‐02 2.38E‐03 3, 4, 5, 6 0.0E+0 0.0E+0 0.0E+0 0.0E+0Access roads 1.58E‐02 2.38E‐03 3, 4, 5, 6 2.5 0.21 0.03 0.11 0.02Pipe / contractor yards / temporary work space

1.58E‐02 2.38E‐03 3, 4, 5, 6 2.5 2.76 0.41 1.38 0.21

Total Fugitive Dust Emissions 27.52 2.90 13.76 1.45

1.2.3.4.

5.

6.7.8.

2017 Fugitive Dust

Pipe / contractor yards / temporary work space

Table 9.B.2.1: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Huguenot Loop, Huguenot M&R, Westtown M&R, and Wagoner Interconnect

It is assumed that at any area construction will entail 3 months of continuous activity.It is assumed that, on average, it will require 6 months to fully revegetate disturbed areas.

Water and other approved dust suppressants would be used at construction sites.WRAP Fugitive Dust Handbook, Countess Environmental, September 2006, Table 3‐2, level 1, average conditionsPM2.5/PM10 = 0.10 (WRAP Fugitive Dust Handbook, Section 3.4.1)Wind erosion of exposed areas (seeded land, stripped or graded overburden) = 0.38 ton TSP/acre/yr (WRAP Fugitive Dust Handbook, Table 11‐6)PM10/TSP = 0.5, PM2.5/PM10 = 0.15, (WRAP Fugitive Dust Handbook, Section 7‐2)

Emission factor converted from ton/acre‐year to ton/acre‐month by dividing by 12



69.6






PM10 PM2.5 PM10 PM2.5 PM10 PM2.5

Construction 1.10E‐01 1.10E‐02 2, 3 3⁷ 29.46 2.95 14.73 1.47Wind erosion

Construction area 1.58E‐02 2.38E‐03 3, 4, 5, 6 6⁸ 8.48 1.27 4.24 0.64Access roads 1.58E‐02 2.38E‐03 3, 4, 5, 6 9 0.76 0.11 0.38 0.06Pipe / contractor yards / temporary work space

1.58E‐02 2.38E‐03 3, 4, 5, 6 9 9.92 1.49 4.96 0.74


1.2.3.4.

5.

6.7.8.

2018 Fugitive Dust


Table 9.B.2.2: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Huguenot Loop, Huguenot M&R, Westtown M&R, and Wagoner Interconnect

Water and other approved dust suppressants would be used at construction sites.WRAP Fugitive Dust Handbook, Countess Environmental, September 2006, Table 3‐2, level 1, average conditionsPM2.5/PM10 = 0.10 (WRAP Fugitive Dust Handbook, Section 3.4.1)

Emission factor converted from ton/acre‐year to ton/acre‐month by dividing by 12It is assumed that at any area construction will entail 3 months of continuous activity.It is assumed that, on average, it will require 6 months to fully revegetate disturbed areas.

Wind erosion of exposed areas (seeded land, stripped or graded overburden) = 0.38 ton TSP/acre/yr (WRAP Fugitive Dust Handbook, Table 11‐6)PM10/TSP = 0.5, PM2.5/PM10 = 0.15, (WRAP Fugitive Dust Handbook, Section 7‐2)



0.0






PM10 PM2.5 PM10 PM2.5 PM10 PM2.5


Construction area 1.58E‐02 2.38E‐03 3, 4, 5, 6 0.00 0.00 0.00 0.00Access roads 1.58E‐02 2.38E‐03 3, 4, 5, 6 0.0 0.00 0.00 0.00 0.00Pipe / contractor yards / temporary work space

1.58E‐02 2.38E‐03 3, 4, 5, 6 0.0 0.00 0.00 0.00 0.00


1.2.3.4.

5.

6.7.8.

2017 Fugitive Dust


PM2.5/PM10 = 0.10 (WRAP Fugitive Dust Handbook, Section 3.4.1)

Table 9.B.2.3: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Highland CS

It is assumed that at any area construction will entail 3 months of continuous activity.

PM10/TSP = 0.5, PM2.5/PM10 = 0.15, (WRAP Fugitive Dust Handbook, Section 7‐2)


Water and other approved dust suppressants would be used at construction sites.WRAP Fugitive Dust Handbook, Countess Environmental, September 2006, Table 3‐2, level 1, average conditions

It is assumed that, on average, it will require 6 months to fully revegetate disturbed areas.

Wind erosion of exposed areas (seeded land, stripped or graded overburden) = 0.38 ton TSP/acre/yr (WRAP Fugitive Dust Handbook, Table 11‐6)



0.0






PM10 PM2.5 PM10 PM2.5 PM10 PM2.5


Construction area 1.58E‐02 2.38E‐03 3, 4, 5, 6 2.5⁷ 0.69 0.10 0.34 0.05Access roads 1.58E‐02 2.38E‐03 3, 4, 5, 6 0.0 0.0E+0 0.0E+0 0.0E+0 0.0E+0Pipe / contractor yards / temporary work space

1.58E‐02 2.38E‐03 3, 4, 5, 6 0.0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


1.2.3.4.

5.

6.7.8.

2018 Fugitive Dust


WRAP Fugitive Dust Handbook, Countess Environmental, September 2006, Table 3‐2, level 1, average conditionsPM2.5/PM10 = 0.10 (WRAP Fugitive Dust Handbook, Section 3.4.1)

Table 9.B.2.4: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Highland CS

January 1 ‐ March 15

PM10/TSP = 0.5, PM2.5/PM10 = 0.15, (WRAP Fugitive Dust Handbook, Section 7‐2)


Water and other approved dust suppressants would be used at construction sites.

It is assumed that, on average, it will require 6 months to fully revegetate disturbed areas.

Wind erosion of exposed areas (seeded land, stripped or graded overburden) = 0.38 ton TSP/acre/yr (WRAP Fugitive Dust Handbook, Table 11‐6)



0.0






PM10 PM2.5 PM10 PM2.5 PM10 PM2.5


Construction area 1.58E‐02 2.38E‐03 3, 4, 5, 6 0.0E+0 0.0E+0 0.0E+0 0.0E+0Access roads 1.58E‐02 2.38E‐03 3, 4, 5, 6 0.0 0.0E+0 0.0E+0 0.0E+0 0.0E+0Pipe / contractor yards / temporary work space

1.58E‐02 2.38E‐03 3, 4, 5, 6 0.0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


1.2.3.4.

5.

6.7.8.

2017 Fugitive Dust


It is assumed that at any area construction will entail 3 months of continuous activity.It is assumed that, on average, it will require 6 months to fully revegetate disturbed areas.



Table 9.B.2.5: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Hancock CS




0.0






PM10 PM2.5 PM10 PM2.5 PM10 PM2.5



1.58E‐02 2.38E‐03 3, 4, 5, 6 0.0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


1.2.3.4.

5.

6.7.8.

2018 Fugitive Dust


January 1 ‐ March 15It is assumed that, on average, it will require 6 months to fully revegetate disturbed areas.



Table 9.B.2.6: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Hancock CS




0.0






PM10 PM2.5 PM10 PM2.5 PM10 PM2.5



1.58E‐02 2.38E‐03 3, 4, 5, 6 0.0 0.0E+0 0.0E+0 0.0E+0 0.0E+0


1.2.3.4.

5.

6.7.8.

PM2.5/PM10 = 0.10 (WRAP Fugitive Dust Handbook, Section 3.4.1)

2018 Fugitive Dust


Table 9.B.2.7: Millennium Pipeline Company, L.L.C. ‐ Eastern System Upgrade Project ‐ Ramapo M&R

January 1 ‐ March 15It is assumed that, on average, it will require 6 months to fully revegetate disturbed areas.



Water and other approved dust suppressants would be used at construction sites.WRAP Fugitive Dust Handbook, Countess Environmental, September 2006, Table 3‐2, level 1, average conditions


Resource Report 9 – Air and Noise Quality 9C-i Eastern System Upgrade

APPENDIX 9C

Air Permit Applications

July 15, 2016 Mr. Stephen M. Tomasik DEC - Division of Environmental Permits 625 Broadway, 4th Floor Albany, NY 12233-1750 Subject: Millennium Pipeline Company – Highland Compressor Station Air State Facility Permit Application Dear Mr. Tomasik: On behalf of Millennium Pipeline Company, LLC (Millennium) TRC is submitting the enclosed ASF Permit application. Millennium has contracted TRC to prepare this application for the proposed Highland Compressor Station to be located in Sullivan County, NY along the existing Millennium pipeline. The Project will be constructed on currently undeveloped property and will consist of the following emission units:

One Solar Titan 130E-22402S, 22,400 HP (ISO) natural gas fired turbine‐driven compressor unit;

One Waukesha VGF48GL (1,230 hp) natural gas fired emergency generator;

One 4,000 gallon waste liquids tank;

One 1.2 MMBtu/hr heat input natural gas fired fuel gas heater; and

One 1,500 gallon oil storage tank. The enclosed application document includes all the technical support information, NYSDEC air permit application forms, backup engineering calculations, an air quality impact assessment and associated air modeling files. A PDF of this complete submittal also will be sent via email. Please direct any technical questions on this application and supporting documentation to me at email [email protected] or by telephone at 201-508-6960. Sincerely, TRC Theodore Main Permitting Project Manager Cc: Ron Happach, Millennium Mike Armstrong, Millennium Lacey Ivey, Columbia Pipeline Group John Zimmer, TRC Nicole Libby, TRC Darin Ometz, TRC

mailto:[email protected]

Millennium Pipeline Company, LLCHighland Compressor Station

Eastern System Upgrade ProjectAir State Facility Permit Application

Prepared for:

Millennium Pipeline Company, LLC

Prepared by:

TRC Environmental Corporation1200 Wall Street West, 5th Floor

Lyndhurst, New Jersey 07071

July 2016

ii

TABLE OF CONTENTS

Section Page

1.0 Introduction .......................................................................................................... 1-1

1.1 Project Overview................................................................................................ 1-1 1.2 Application Summary........................................................................................ 1-1

2.0 Project Description................................................................................................ 2-1

2.1 Site Location and Surroundings........................................................................ 2-1 2.2 Facility Conceptual Design................................................................................ 2-1

2.2.1 Compressor Turbine ..................................................................................2-2 2.2.2 Ancillary Equipment ................................................................................. 2-4

2.3 Fuel ................................................................................................................... 2-4 2.4 Fugitive Emissions and Tanks.......................................................................... 2-4 2.5 Proposed Project Emission Potential................................................................2-5

3.0 Applicable Requirements and Required Analyses ............................................... 3-1

3.1 Federal New Source Performance Standards ................................................... 3-1 3.1.1 40 CFR Part 60, Subpart A – General Provisions......................................... 3-1 3.1.2 40 CFR Part 60 Subpart Kb - Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) ........................................................ 3-1 3.1.3 40 CFR Part 60, Subpart JJJJ – Spark Ignition Internal Combustion Engines 3-2 3.1.4 40 CFR Part 60, Subpart KKKK – Stationary Combustion Turbines.......3-2 3.1.5 40 CFR 60, Subparts OOOO and OOOOa – Crude Oil and Natural Gas Production, Transmission and Distribution ............................................................3-3

3.2 Nonattainment New Source Review .................................................................3-3 3.3 Prevention of Significant Deterioration (PSD) .................................................3-4 3.4 Title V Operating Permit and State Operating Permit Programs.....................3-5

3.4.1 Exempt and Trivial Sources .......................................................................3-5 3.5 National Emission Standards for Hazardous Air Pollutants............................3-6

3.5.1 40 CFR Part 63 Subpart HHH (National Emission Standards for Hazardous Air Pollutants from Natural Gas Transmission and Storage Facilities) ..................3-6 3.5.2 40 CFR Part 63 Subpart YYYY (National Emission Standards for Hazardous Air Pollutants for Stationary Combustion Turbines)...............................................3-7 3.5.3 40 CFR Part 63 Subpart ZZZZ (National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines) ..........3-7 3.5.4 40 CFR Part 63 Subpart DDDDD (National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters) ..............................................................3-7

3.6 New York State Department of Environmental Conservation Regulations.....3-7

4.0 Air Quality Modeling Analysis ..............................................................................4-1

4.1 Background Ambient Air Quality......................................................................4-1 4.2 Modeling Methodology .....................................................................................4-3

4.2.1 Model Selection..........................................................................................4-3 4.2.2 Urban/Rural Area Analysis........................................................................4-3

iii

4.2.3 Good Engineering Practice Stack Height ................................................. 4-4 4.2.4 Meteorological Data ...................................................................................4-5

4.3 Receptor Grid ................................................................................................... 4-6 4.3.1 Basic Grid .................................................................................................. 4-6 4.3.2 Property Line Receptors ........................................................................... 4-6

4.4 Selection of Sources for Modeling.....................................................................4-7 4.4.1 Emission Rates and Exhaust Parameters ..................................................4-7

4.5 Maximum Modeled Facility Concentrations ..................................................4-10 4.6 Toxic Ambient Air Contaminant Analysis ......................................................4-10 4.7 Modeling Data Files......................................................................................... 4-11 4.8 References........................................................................................................ 4-11

LIST OF TABLES

Table 2-1: Proposed Facility Emissions.......................................................................................................... 2-6 Table 3-1: PSD/NNSR Applicability Assessment.......................................................................................... 3-4 Table 4-1: Maximum Measured Ambient Air Quality Concentrations........................................................ 4-2 Table 4-2: Stack Parameters and Emission Rates – Proposed Titan 130E Compressor Turbine .............. 4-8 Table 4-4: Stack Parameters and Emission Rates – Proposed Emergency Generator............................... 4-9 Table 4-5: Stack Parameters and Emission Rates – Proposed Fuel Gas Heater ........................................ 4-9 Table 4-5: Facility Maximum Modeled Concentrations Compared to NAAQS/NYAAQS ....................... 4-10 Table 4-6: Facility Maximum Modeled Concentrations Compared to SGCs and AGCs............................4-13

LIST OF FIGURES

Figure 2-1: Site Location Aerial........................................................................................2-7 Figure 2-2: Site Location Map ........................................................................................ 2-8 Figure 2-3: General Arrangement Plan .......................................................................... 2-9

LIST OF APPENDICES

Appendix A: NYSDEC Application FormsAppendix B: Detailed Emission Calculations and Vendor DataAppendix C: Electronic Air Quality Modeling Files (Available Upon Request)

Millennium Pipeline Company, LLC 1-1 Highland Compressor Station

1.0 INTRODUCTION

1.1 Project Overview

Millennium Pipeline Company, L.L.C. (Millennium) is seeking authorization from the Federal Energy Regulatory Commission (FERC or Commission) pursuant to Section 7(c) of the Natural Gas Act to construct, install, operate, and maintain the Eastern System Upgrade (Project). The purpose of the Project is to permit Millennium to transport an incremental volume of approximately 223,000 dekatherms per day of natural gas from Millennium’s Corning Compressor Station to an existing interconnect with Algonquin Gas Transmission, L.L.C. (Algonquin) located in Ramapo, New York. As part of the Eastern System Upgrade Project and in order to boost pressures on Millennium’s transmission pipeline system, Millennium is proposing to construct and operate one Solar Titan 130E turbine powering a C75 compressor (22,400 hp (ISO)) at a new compressor station in the town of Highland, Sullivan County, New York, and known as the Highland Compressor Station. The Highland Compressor Station (CS) will be a new natural gas transmission facility covered by Standard Industrial Classification (SIC) 4922. Ancillary project emission sources include one (1) 1,230 hp Waukesha VGF48GL emergency generator, one (1) 4,000 gallon waste liquids tank, one (1) 1.2 MMBtu/hr gas heater, and one (1) 1,500 gallon oil tank.

1.2 Application Summary

The Highland Compressor Station (Project) is a proposed minor stationary source (as defined under the Prevention of Significant Deterioration of Air Quality [PSD] and Title V rules) located in Sullivan County, New York. As demonstrated in Section 3 of this application, the proposed project is not subject to major source air permittingrequirements.

The Project will be located in the town of Highland, Sullivan County, which is part of the Southern Tier East Intrastate Air Quality Control Region in New York State. SullivanCounty is considered attainment or unclassifiable for all criteria pollutants including ozone and fine particulate matter (PM2.5). However, because New York State is part of the Northeast Ozone Transport region, the Project area is considered moderate non-attainment for ozone.

The proposed project involves the installation of new emission units and will be considered a minor source with respect to New Source Review (NSR) permitting requirements at 6 NYCRR Part 231 and Title V major source permitting requirements at


6 NYCRR Part 201-6. As such, Millennium is submitting an initial minor source State Facility air permit application for the new Highland Compressor Station. The new Titan 130E combustion turbine will be subject to 40 CFR 60 Subpart KKKK, New Source Performance Standards for Stationary Gas Turbines as well as the applicable state regulations as outlined in Section 3 of this application. The new emergency generator will be subject to 40 CFR 60, Subpart JJJJ, New Source Performance Standards for Stationary Spark-Ignition Internal Combustion Engines and 40 CFR 63, Subpart ZZZZ, and National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. The project will not trigger permitting requirements for non-attainment areas per 6 NYCRR Part 231.

Appendix A of this Air State Facility application contains the NYSDEC application formsand a completed Professional Engineer Certification Form. Emission calculation spreadsheets providing supporting calculations for the application forms are included as Appendix B of this application.


2.0 PROJECT DESCRIPTION

2.1 Site Location and Surroundings

The proposed Highland Compressor Station, as shown in Figures 2-1 and 2-2, is located in a rural area in the town of Highland, Sullivan County, New York. The site is currently undeveloped.

The approximate Universal Transverse Mercator (UTM) coordinates of the facility are: 511,142 meters east and 4,603,785 meters north in Zone 18 (North American Datum of 1983(NAD83)).

2.2 Facility Conceptual Design

As a part of the Eastern System Upgrade project, Millennium is proposing to install the following equipment at the proposed Highland Compressor Station:

One Solar Titan 130E-22402S, 22,400 HP (ISO) natural gas fired turbine-driven compressor unit;One Waukesha VGF48GL (1,230 hp) natural gas fired emergency generator;One 4,000 gallon waste liquids tank;One 1.2 MMBtu/hr heat input natural gas fired fuel gas heater; andOne 1,500 gallon oil storage tank.

In addition to the single significant emission source consisting of the Solar Titan 130E combustion turbine, several exempt emission units will be located at the HighlandCompressor Station. These exempt sources include natural gas-fired heaters with heat inputs less than 10 million British thermal units per hour (MMBtu/hr) and one natural gas-fired Waukesha VGF48GL emergency generator with a heat input of 9.7 mmBtu/hr. In addition, the proposed natural gas liquids filter/separators and associated waste liquids storage tank (4,000 gallon) are typical for natural gas compressor stations, whichmay receive small amounts of condensate from upstream natural gas supply and where pipeline cleaning activities may result in residual condensate collection.

Lastly, emissions include trivial station blowdowns consisting of two types of gas blowdown events that could occur at the Station: (1) a type of maintenance gas blowdown that could occur when a compressor is stopped and gas between the suction/discharge valves and compressors is vented to the atmosphere via a blowdown vent, and (2) an emergency shutdown (ESD) that would only occur at required U.S. Department of Transportation (DOT) test intervals or in an emergency situation.


The installation of the above equipment will include a number of piping components at the station which could result in additional fugitive emissions due to equipment leaks.

The new Waukesha (1,230 hp) emergency generator has a four stroke, lean burn, natural gas-fired stationary reciprocating internal combustion engine. The proposed emergency generator will be installed to meet site wide emergency electrical demands as a result of the Eastern System Upgrade project and will be operated only during normal testing, maintenance, and emergency situations. Per 6 NYCRR 201-3.2(c)(6), emergency power generating stationary internal combustion engines, as defined in section 200.1(vq) of this Title are exempt sources. As such, this generator is an exempt source. Further, the engine will meet the definition of “emergency stationary internal combustion engine” per 40 CFR 60.4248 and will comply with the requirements for operating emergency engines in 40 CFR 60.4243(d).

Millennium is proposing to install one natural gas fired fuel gas heater, with a rated heat input capacity of 1.2 MMBtu/hr. Per 6 NYCRR 201-3.2(c)(1)(i), stationary combustion installations with a maximum rated heat input capacity less than 10 MMBtu/hr burning fuels other than coal or wood are exempt from permitting. As such, the heater is anexempt source.

Millennium has provided fugitive emissions estimates for VOC and greenhouse gas (GHG) emissions. Estimates of fugitive emissions are required to be included for Title V applicability assessments, per 6 NYCRR 201-6.2(d)(3)(ii). Typical sources of fugitive emissions from natural gas compressor stations include leaks from piping components (valves, flanges, connectors and open-ended lines) as well as potential gas release events.

2.2.1 Compressor Turbine

The proposed Solar Titan 130E natural gas-fired turbine to be installed at the HighlandCompressor Station will be equipped with Solar’s SoLoNOx dry low NOx combustor technology for NOx control. Emissions for the Solar Turbine assumes that the unit will operate up to 8,760 hours per year and up to 100% rated output. The vendor provided emission rates for normal operating conditions are as follows (all emissions rates are in terms of parts per million dry volume (ppmvd) @ 15% O2):

• 15 ppmvd NOx;• 25 ppmvd CO;• 25 ppmvd unburned hydrocarbons (UHC); and• 5 ppmvd VOC.


Depending upon demand, the turbine may operate at loads ranging from 50% to 100% of full capacity. Because of the different emission rates and exhaust characteristics that occur at different loads and ambient temperatures, a matrix of operating modes is presented in this air permit application. Emission parameters for three turbine loads (50%, 75%, and 100%) and six ambient temperatures (0oF, 20oF, 40oF, 60oF, 80oF and 100oF) are accounted for in this air permit application to cover the range of steady-state turbine operations.

At very low load and cold temperature extremes, the turbine system must be controlled differently in order to assure stable operation. The required adjustments to the turbine controls at these conditions cause emissions of NOx, CO and VOC to increase (emission rates of other pollutants are unchanged). Low-load operation (non-normal SoLoNOx operation) of the turbines is expected to occur only during periods of startup and shutdown and for maintenance or unforeseen emergency events. Solar has provided emissions estimates during start-up and shutdown and low load operation (see Solar Product Information Letter (PIL) 170, included as part of the vendor attachments in Appendix B). The annual hours of operation during low load operation was assumed to be no more than 10 hours per year.

Similarly, Solar has provided emission estimates for low temperature operation (inlet combustion air temperature less than 0° F and greater than -20° F). Table 3.1 provides estimated pre-control emissions from the turbines at low temperature conditions.

• 120 ppmvd NOx;• 150 ppmvd CO;• 50 ppmvd unburned hydrocarbons (UHC); and• 10 ppmvd VOC.

Millennium reviewed historic meteorological data from the previous five years for the region to estimate the worst case number of hours per year under sub-zero (less than 0° F) conditions. The annual hours of operation during sub-zero conditions was assumed to be not more than 120 hours per year.

Turbine emission rates during start-up and shutdown events increase for NOx, CO and VOC as compared to operating above 50% load. The start-up process for the Solar Titan 130E turbine takes approximately 10 minutes from the initiation of start-up to normal operation (equal to or greater than 50% load). Shutdown takes approximately 10 minutes. Millennium has estimated there would be 100 start-up/shutdown events per year. Emissions per start- up and shutdown event for the turbine were estimated based


on Table 3 from the Solar PIL 170 entitled “Emission Estimates at Start-up, Shutdown, and Commissioning for SoLoNOx Combustion Products”. Appendix B contains these per-event emission calculations for start- up and shutdown and the associated Solar PIL 170.

2.2.2 Ancillary Equipment

Millennium is proposing to install a new Waukesha VGF48GL (1,230 hp) four stroke lean burn natural gas fired emergency generator. The emergency generator will operate for no more than 500 hours/year, and therefore meets the definition of an “emergency power generating stationary internal combustion engine” under 6 NYCRR 200.1(cq). As previously indicated, the generator is an exempt source per 6 NYCRR 201-3.2(c)(6), however the potential emissions for this new unit are included for NSR and Title Vapplicability purposes. Maximum hourly and annual emission rates for the emergency generator are provided in Appendix B. Emissions of NOx, CO, and VOC are based on regulatory limits under New Source Performance Standard (NSPS) Subpart JJJJ. Emission rates for SO2, particulates, and HAPs are based on US EPA AP-42 emission factors (Table 3.2-2). GHG emissions are based on 40 CFR Part 98 Tables A-1, C-1, andC-2. The emission rates are based on the emergency generator operating at peak load.

Millennium is proposing to install one new 1.2 MMBtu/hr (heat input) natural gas heater. Appendix B provides information on the emission factors used to calculate emissions from the heater. As previously indicated, the heater is an exempt source per 6 NYCRR201-3.2(c)(1)(i), however the potential emissions for this new unit are included for NSR and Title V applicability purposes.

2.3 Fuel

The Highland Station will utilize pipeline natural gas as the sole fuel for all proposed equipment. The natural gas is assumed to have a higher heating value (HHV) of approximately 1,024.5 Btu/standard cubic foot (SCF) and will contain no more than 2.0grains of sulfur per 100 SCF of gas on an annual average basis.

2.4 Fugitive Emissions and Tanks

Fugitive emissions are defined as those emissions which do not pass through a stack, vent, or other functionally equivalent opening, and include natural gas leaks from valves, flanges, pumps, compressors, seals, connections, etc. Vented emissions are defined as those emissions which pass through a stack, vent, or equivalent opening. A compressor may be vented for startup, shutdown, maintenance, or for protection of gas seals from


contamination. An individual compressor or the entire station may be blown down (i.e., vented) for testing, or in the event of an emergency.

Fugitive emissions at natural gas compressor stations include leaks from piping components (valves, flanges, connectors and open-ended lines) as well as potential gas release events. The vast majority of gas release events are associated with startup, shutdown, or maintenance activities. Millennium has provided fugitive emissions estimates for VOC and greenhouse gas (GHG) emissions in Appendix B. The calculations in Appendix B are based on a methodology described in Interstate Natural Gas Association of America guidelines and a recent analysis of a Millennium Pipeline natural gas sample, which is also included in Appendix B. The calculations for operational ventednatural gas conservatively assume that the Highland Station will conduct two full-station blowdowns per year. Estimates of fugitive emissions are required to be included in Title V permit applicability assessments, per 6 NYCRR 201-6.2(d)(3)(ii).

Proposed tanks at the Highland Station may have associated emissions, such as the flashing losses that occur when the pressure of a liquid is decreased or the temperature is increased. At Highland, flashing losses will occur at pipeline liquids storage tanks and include VOCs and GHGs. Total flashing losses are calculated based on a flash gas rate and a representative flash gas density. The flash gas rate is calculated based on a liquids input rate and a flash factor. Emissions of individual VOCs and GHGs are calculated from total flashing losses using a representative pipeline liquids compositions. The details of the calculations are provided in Appendix B.

Lastly, Millennium is proposing to install a new 1,500 gallon lube oil tank for the Solar Titan 130E turbine. The 1,500 gallon oil storage tank is considered an exempt activity per 6 NYCRR 201-3.2(c)(25) as a storage tank with a capacity under 10,000 gallons. Estimated emissions were calculated using the Tanks 4.09d estimation tool for storage tank working and standing losses.

2.5 Proposed Project Emission Potential

Table 2-1 presents project emission potentials from the new units to be installed as a part of the proposed Highland Compressor Station. For new units, project emission potential is equal to potentials to emit. Detailed emission calculations can be found in Appendix B of this permit application.


Table 2-1: Proposed Facility Emissions (tons/year)

Pollutant

SolarTitan 130E

Turbine

ExemptWaukeshaVGF48GL

Emergency Generator(1)

Exempt Fuel Gas Heater(1)

Exempt Lube Oil and

Condensate Tanks(2)

Trivial Station

Blowdowns(3)

Trivial Station

Fugitives(3)

ProposedProject

Total(tons/year)

NOx 48.59 1.36 0.53 - - - 50.47

VOC 5.53 0.68 0.03 2.27 0.05 0.49 9.05

CO 78.08 2.71 0.44 - - - 81.23

SO2 4.57 0.0015 0.030 - - - 4.60

PM10/PM2.5 12.27 0.04 0.04 - - - 12.33

CO2e 95,690 285 631 - 758 7,891 105,255

HAPs 2.48 0.18 0.01 0.21 - - 2.87Maximum Individual

HAP1.71 0.13 0.0003 - - - 1.84

(1) Exempt per 201-3.2(c)(6) for emergency power generating stationary internal combustion engines which meet therequirements of 200.1(cq) of operation when the usual source of electric power is unavailable and no more than 500 hoursper year inclusive of emergency operation, testing, and maintenance.

(2) Exempt per 201-3.2(c)(25) for storage tanks under 10,000 gallons, not otherwise subject to Parts 229 or 233(3) Trivial per 201-3.3(94) for emissions of “….oxygen, carbon dioxide, nitrogen, simple asphyxiants including methane and

propane, trace constituents included in raw materials or byproducts, where the constituents are less than 1 percent by weightfor any regulated air pollutant, or 0.1 percent by weight for any carcinogen listed by the United States Department of Healthand Human Services’ Seventh Annual Report on Carcinogens (1994). The definition of “regulated air pollutant” under200.1(bu) does not include methane or ethane.

(4) Greenhouse gases calculated as CO2e.

(5) The individual HAP with the highest total annual emission rate is formaldehyde.

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3.0 APPLICABLE REQUIREMENTS AND REQUIRED ANALYSES

This section contains an analysis of the applicability of federal and state air quality regulations to the proposed project. The specific regulations included in this applicability review are the Federal New Source Performance Standards (NSPS), Prevention of Significant Deterioration (PSD) and Non-Attainment New Source Review (NNSR) requirements, Maximum Achievable Control Technology (MACT) requirements for HAPs, and NYSDEC Regulations and Policy.

3.1 Federal New Source Performance Standards

The 40 CFR 60 NSPS are technology-based standards that apply to new and modified stationary sources. The 40 CFR 60 NSPS requirements have been established for approximately 70 source categories. The proposed project is subject to the following foursubparts: General Provisions (40 CFR Part 60, Subpart A), Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (40 CFR Part 60, Subpart JJJJ),Standards of Performance for Stationary Combustion Turbines (40 CFR Part 60, Subpart KKKK), and the Standards of Performance for Oil and Natural Gas Sector: Emission Standards for New, Reconstructed, and Modified Sources (40 CFR Part 60, Subpart OOOOa).

3.1.1 40 CFR Part 60, Subpart A – General Provisions

The new Titan 130E turbine is subject to the general provisions for NSPS units in 40 CFR Part 60 Subpart A. These include the requirements for notification, record keeping, and performance testing contained in 40 CFR Parts 60.7 and 60.8.

3.1.2 40 CFR Part 60 Subpart Kb - Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels)

Subpart Kb potentially applies to storage vessels with a capacity greater than 75 cubic meters (m3) (19,813 gallons) that will store volatile organic liquids. Tanks with a capacity greater than 75 m3 are not proposed to be constructed, reconstructed, or modified at Highland. Therefore, this subpart will not apply.


3.1.3 40 CFR Part 60, Subpart JJJJ – Spark Ignition Internal Combustion Engines

On January 18, 2008, the USEPA promulgated NSPS Subpart JJJJ for new stationary spark-ignited (SI) internal combustion engines (ICE). Under NSPS Subpart JJJJ, all new, modified, and reconstructed stationary SI engines, both emergency and non-emergency, are covered regardless of size and fuel type. Owners/operators have several options to demonstrate compliance with Subpart JJJJ. The rule allows compliance to be demonstrated by purchase of a certified engine or a non-certified engine and an initial performance test. The performance test for a non-certified engine must show compliance with applicable emission limits of:

• NOx – 2.0 g/bhp-hr or 160 ppmvd @ 15% O2;• CO – 4.0 g/bhp-hr or 540 ppmvd @ 15% O2 ; and• VOC (not including formaldehyde) – 1.0 g/bhp-hr or 86 ppmvd @ 15% O2.

If the spark-ignition engine is a non-certified engine, the owner/operator has the option of complying with the emissions standards in either set of units.

3.1.4 40 CFR Part 60, Subpart KKKK – Stationary Combustion Turbines

On July 6, 2006, the USEPA promulgated Subpart KKKK to establish emission standards and compliance schedules for the control of emissions from new stationary combustion turbines that commence construction, modification, or reconstruction after February 18, 2005. Note that stationary combustion turbines regulated under Subpart KKKK are exempt from Subpart GG requirements, which are applicable to units constructed, modified, or reconstructed prior to February 18, 2005.

Pursuant to 40 CFR 60.4305(a), the new Solar gas turbine is subject to requirements of 40 CFR 60 Subpart KKKK, because the heat input at peak load will be greater than or equal to 10 MMBtu/hr (HHV) and Millennium will have commenced the construction or modification of the turbine after February 18, 2005. Pursuant to 40 CFR 60.4320(a) and Table 1 to Subpart KKKK of Part 60 – Nitrogen Oxide Emission Limits for New Stationary Combustion Turbines, the new gas turbine, which will have HHV heat inputs of between 50 and 850 MMBtu/hr, will comply with a NOx emission standard of 25 ppm at 15 percent O2 or 1.2 lb/MWh useful output as indicated by the vendor guarantee shown in Appendix B. Subpart KKKK also includes a NOx limit of 150 ppmvd at 15% O2 or 8.7 lb/MWh for turbine operation at temperatures less than 0°F and turbine operation at loads less than 75 % of peak load which the new turbine will meet as indicated by the vendor guarantee


shown in Appendix B. The new turbine will not burn any fuel that has the potential to emit in excess of 0.060 lb/MMBtu SO2 heat input, pursuant to 40 CFR 60.4330(a)(1) and (2), respectively.

3.1.5 40 CFR 60, Subparts OOOO and OOOOa – Crude Oil and Natural Gas Production, Transmission and Distribution

Subpart OOOO currently applies to affected facilities that commenced construction, reconstruction, or modification after August 23, 2011. Subpart OOOO establishes emissions standards and compliance schedules for the control of VOCs and SO2 emissions for affected facilities producing, transmitting, or distributing natural gas. Compressors located between the wellhead and the point of custody transfer to the natural gas transmission and storage segment are subject to this Subpart. Custody transfer is defined as the transfer of natural gas after processing and/or treatment in the producing operations. Highland Station is located after the point of custody transfer, and therefore centrifugal compressors driven by the proposed turbines are not currently subject to this regulation. Storage vessels located in the natural gas transmission and storage segment that have the potential for VOC emissions equal to or greater than 6 tpy are also subject to this Subpart. All storage vessels at Highland will emit less than this threshold, and thus will not be subject to this regulation. On August 18, 2015, EPA proposed amendments to 40 CFR 60, Subpart OOOO and proposed an entirely new Subpart OOOOa.

Based on the effective date of August 2, 2016 for the new Subpart, this project will be required to comply with the requirements of NSPS Subpart OOOOa. While storage tanks remain covered, Subpart OOOOa also includes provisions intended to reduce emissionsfrom compressors and equipment leaks at compressor stations. For equipment leaks,Subpart OOOOa proposes requiring periodic surveys using optical gas imaging (OGI) technology and subsequent repair of any identified leaks. The project will comply with all applicable leak detection provisions of proposed Subpart OOOOa.

3.2 Nonattainment New Source Review

The location of the Highland Compressor Station is in an area currently designated as attainment or unclassifiable for SO2, NO2, CO, PM10, PM2.5 and ozone (O3). However, the project is located in the ozone transport region (OTR). Facilities with the potential to emit more than 100 tons per year of NOx or 50 tons per year of VOC in an OTR are subject to NNSR for these pollutants. The proposed Project will not trigger nonattainment NSR because potential emissions are less than the applicable emissions thresholds as shown


in Table 3-1. As the facility will be a minor source for all nonattainment pollutants, offsets and the application of the Lowest Achievable Emission Rate (LAER) are not necessary.

Table 3-1: PSD/NNSR Applicability AssessmentPollutant PSD/NNSR Major Source

Threshold (tons/year)Total Facility Emissions

(tons/year)Carbon Monoxide (CO) 250 81.23

Sulfur Dioxide (SO2) 250 4.60TSP 250 12.33

PM10 250 12.33PM2.5 250 12.33

Nitrogen Oxides (NOx) 100 50.47VOC 50 9.05

Greenhouse Gases (CO2e) 100,000 105,255Total HAP 25 2.87

Individual HAP -Formaldehyde

10 1.84

3.3 Prevention of Significant Deterioration (PSD)

Preconstruction air permitting programs that regulate the construction of new stationary sources of air pollution and the modification of existing stationary sources are commonly referred to as NSR. NSR can be divided into major NSR and minor NSR. Major NSR is comprised of the Prevention of Significant Deterioration (PSD). Major NSR requirements are established on a federal level but may be implemented by state or local permitting authorities under either a delegation agreement with USEPA or as a SIP program approved by USEPA. NYSDEC administers its major NSR permitting program through 6 NYCRR Part 231, which establishes preconstruction, construction, and operation requirements for new and modified sources. The Highland Compressor Station is not classified as one of the 28 named source categories listed in Section 169 of the Clean Air Act. Therefore, to be considered a “major stationary source”, the facility would need to have potential emissions of 250 tons per year or more of any regulated pollutant (except CO2). The final PSD and Title V GHG Tailoring Rule was published in the Federal Register on June 3, 2010 (75 FR 31514) but was ultimately overturned on June 23, 2014 by the US Supreme Court. Under the formerly effective rule, GHGs could, as of July 1, 2011, become “subject to regulation” under the PSD program for construction projects that would result in potential GHG emissions of 100,000 tons per year (tpy) carbon dioxide equivalents (CO2e) or more. However, the June 23, 2014 Supreme Court Decision clarifies that construction projects cannot trigger major NSR for GHGs unless major NSR is otherwisetriggered for criteria pollutants.

As shown in Table 3-1, the proposed Highland Compressor Station is a minor stationary source with respect to PSD.


3.4 Title V Operating Permit and State Operating Permit Programs

The Title V permit program in 40 CFR Part 70 requires major sources of air pollutants to obtain federal operating permits. The major source thresholds under the Title V program, as defined in 40 CFR 70.2 and which are different from the federal NSR major source thresholds, are 100 tpy of any air pollutant, 10 tpy of any single hazardous air pollutant (HAP), or 25 tpy of total HAPs. More stringent Title V major source thresholds apply for VOC and NOx in ozone nonattainment areas, namely 50 tpy of VOC or NOx in areas defined as serious, 25 tpy in areas defined as severe, and 10 tpy in areas classified as extreme.

The State of New York’s Title V Operating Permit Program is administered through aUSEPA-approved program at 6 NYCRR 201-6. NYSDEC also administers a state operating permit program through 6 NYCRR 201-5 for certain non-Title V facilities that do not qualify for a minor facility registration under 6 NYCRR Subpart 201-4, including synthetic minor facilities and facilities with actual emissions greater than fifty percent of Title V thresholds. Emission sources or activities listed under NYCRR 201-3 are exempt from the registration and permitting provisions of 6 NYCRR Subparts 201-4, 201-5, and 201-6.

As shown in Table 3-1, potential emissions of all regulated pollutants are below the Title V major source thresholds. As such, the facility is not subject to Title V permitting requirements for these pollutants and is required to obtain a State Facility operating permit per 6 NYCRR 201-5.

3.4.1 Exempt and Trivial Sources

Exempt activities cannot be excluded when determining applicability of Title V, nonattainment NSR, or PSD. Table 3-1 includes emissions from exempt equipment at the Station (the emergency generators, fuel gas heater, oil storage tank, and waste liquids storage tank). A list of exempt activities is included with the NYSDEC permit application forms in Appendix A.

The emergency generator is considered an exempt activity per 6 NYCRR 201-3.2(c)(6) as an emergency power generating internal combustion engine. The generator conforms to the definition of such an exempt unit under 6 NYCRR 200.1(cq) because it will operate as an electric power source only when the usual supply of electric power is unavailable and


will operate for no more than 500 hours per year, inclusive of emergency situations, maintenance, and testing.

Pursuant to 6 NYCRR 201-3.2(c)(1)(i), natural gas-fired heaters with a maximum rated heat input capacity less than 10 million British thermal units per hour (MMBtu/hr) are considered exempt sources. The 4,000 gallon waste liquids storage tank and 1,500 gallon lube oil tank are considered an exempt activity per 6 NYCRR 201- 3.2(c)(25) as a storage tank with a capacity under 10,000 gallons.

Blowdowns are considered a trivial activity per 6 NYCRR 201-3.3(94) which covers “Emissions of the following pollutants: water vapor, oxygen, carbon dioxide, nitrogen, inert gases such as argon, helium, neon, krypton and xenon, hydrogen, simple asphyxiants including methane and propane, trace constituents included in raw materials or byproducts, where the constituents are less than 1 percent by weight for any regulated air pollutant, or 0.1 percent by weight for any carcinogen listed by the United States Department of Health and Human Services' Seventh Annual Report on Carcinogens (1994).” The natural gas composition at the Highland Station meets the definition in 6 NYCRR 201-3.3 as shown in Appendix B.

3.5 National Emission Standards for Hazardous Air Pollutants

The USEPA has established National Emission Standards for Hazardous Air Pollutants (NESHAP) for specific pollutants and industries in 40 CFR Part 61. The Project does not include any of the specific sources for which NESHAP have been established in Part 61. Therefore, Part 61 NESHAP requirements will not apply to the Project. The USEPA has also established NESHAP requirements in 40 CFR Part 63 for various source categories. The Part 63 NESHAP apply to certain emission units at facilities that are major sources of HAP. The applicability to the Project of several NESHAP rules is discussed below.

3.5.1 40 CFR Part 63 Subpart HHH (National Emission Standards for Hazardous Air Pollutants from Natural Gas Transmission and Storage Facilities)

Subpart HHH applies to natural gas transmission and storage facilities that are major sources of HAPs and that transport or store natural gas prior to entering the pipeline to a local distribution company or to a final end user (if there is no local distribution company). The Highland Station is an area source (i.e., not major source) of HAPs. Therefore, this subpart will not apply because it only applies to major sources.


3.5.2 40 CFR Part 63 Subpart YYYY (National Emission Standards for Hazardous Air Pollutants for Stationary Combustion Turbines)

Subpart YYYY applies to stationary combustion turbines at major sources of HAPs. Emissions and operating limitations under Subpart YYYY apply to new and reconstructedstationary combustion turbine. The Highland Station is an area source (i.e., not major source) of HAPs. Therefore, this subpart will not apply because it only applies to major sources.

3.5.3 40 CFR Part 63 Subpart ZZZZ (National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines)

Subpart ZZZZ, applies to existing, new, and reconstructed stationary reciprocatinginternal combustion engines (ICE) depending on size, use, and whether the engine is located at a major or area source of HAP. The Project includes the installation of one new emergency stationary RICE with a site rating greater than 500 hp at the Highland Station. New stationary ICE located at area sources of HAP, such as the emergency engineproposed for the Project, must meet the requirements of Subpart ZZZZ by meeting the NSPS. As discussed above, the new emergency engine is subject to the NSPS at 40 CFR Part 60, Subpart JJJJ, therefore the requirements of Subpart ZZZZ will be met.

3.5.4 40 CFR Part 63 Subpart DDDDD (National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters)

Subpart DDDDD applies to certain new and existing boilers and process heaters at major HAP sources. The Highland Station is an area source (i.e., not major source) of HAPs. Therefore, this subpart will not apply because it only applies to major sources.

3.6 New York State Department of Environmental Conservation Regulations

Applicable NYSDEC air regulations and the associated proposed means of project compliance are identified below:

Part 200 defines general terms and conditions, requires sources to restrict emissions, and allows NYSDEC to enforce NSPS, PSD, and National Emission Standards for Hazardous Air Pollutants (NESHAP). Part 200 is a general applicable requirement; no action is required by the facility.


Part 200.1(cq) defines emergency power generating stationary internal combustion engines as stationary internal combustion engines that operate as mechanical or electrical power sources only when the usual supply of power is unavailable, and operate for no more than 500 hours per year (i.e., applicable to the proposed emergency generator, which has been assumed to operate no more than 500 hours per year, including periodic testing and maintenance activities to ensure reliability). Part 202-1 requires sources to conduct emissions testing upon the request of NYSDEC. Permit conditions covering construction of the proposed project will likely require stack testing as a condition of receiving its permit to construct.Part 202-2 requires sources to submit annual emission statements for emissions tracking and fee assessment. Pollutants are required to be reported in an emission statement if certain annual thresholds are exceeded. Project emissions will be reported as required.Part 211-3 defines general opacity limits for sources of air pollution in New York State. General applicable requirement facility-wide visible emissions are limited to 20 percent opacity (6-minute average) except for one continuous six-minute period per hour of not more than 57 percent opacity. Note that the opacity requirements under Part 227-1 (see below) are more restrictive and effectively supersede the requirements of Part 211-3.Visible emissions (opacity) for stationary fuel-burning equipment are regulated under 6 NYCRR Subpart 227-1.3. Facility stationary combustion installations must be operated so that the following opacity limits are not violated; 227-1.3(a) 20 percent opacity (six minute average), except for one six-minute period per hour of not more than 27 percent opacity.


4.0 AIR QUALITY MODELING ANALYSIS

At the federal level, because the emission increases from the Highland Station modifications are less than applicable major source thresholds, Millennium will not trigger federal NSR requirements for any regulated air pollutant under either PSD or NNSR permitting programs. At the state level, the Project triggers air permitting through the NYSDEC as a minor source of air emissions subject to State Air Facility permitting. If the agency considers that any project triggering minor NSR permitting could threaten attainment with the National Ambient Air Quality Standards (NAAQSs) or human health from toxic air pollutant (TAP) concentrations, NYSDEC can require air dispersion modeling for the Project. A site wide modeling analysis for criteria pollutants has beenperformed in accordance with their impact analysis modeling guidance, Policy DAR-10. In addition, a modeling analysis that addresses TAPs is performed per Policy DAR-1. This section details the NAAQS and TAPs modeling assessment for the proposed HighlandStation.

4.1 Background Ambient Air Quality

Background ambient air quality data was obtained from various existing monitoring locations. Based on a review of the locations of Pennsylvania and New York ambient air quality monitoring sites, the closest representative monitoring sites were used to represent the current background air quality in the site area.

Background data for CO, NO2, and PM2.5 was obtained from a monitoring station located in Lackawanna County, Pennsylvania (USEPA AIRData # 42-069-2006). This monitor is located in the city of Scranton that has a higher population density and higher density of industrial facilities than the Highland area in Sullivan County. Further, this monitor is located in an area with a greater amount of mobile and point sources of air emissions as compared to the project area. Thus, this monitor is considered to conservatively represent the ambient air quality within the project area.

Background data for SO2 and PM10 was obtained from a monitoring station located in Luzerne County, Pennsylvania (USEPA AIRData # 42-079-1101). This monitor is located in city of Wilkes Barre that has a higher population density and higher density of industrial facilities than the area around the Highland Station. Further, this monitor is located in an area with a greater amount of mobile and point sources of air emissions as compared to the project area. Thus, this monitor is also considered to conservatively represent the ambient air quality within the project study area.


The monitoring data for the most recent three years (2012 – 2014) are presented and compared to the NAAQS in Table 4-1. The maximum measured concentrations for each of these pollutants during the last three years are all below applicable standards and are proposed to be used as representative background values for comparison of facility concentrations to the NAAQS.

Table 4-1: Maximum Measured Ambient Air Quality Concentrations

PollutantAveraging

Period

Maximum Ambient Concentrations ( g/m3) NAAQS

( g/m3)2012 2013 2014

SO2

1-Houra

24-HourAnnual

21.013.62.1

18.313.61.4

23.613.92.1

19636580

NO21-Hourb

Annual

67.7

16.1

75.2

15.4

84.6

20.0

188

100

CO1-Hour8-Hour

1,380920

2,0701,495

1,7251,150

40,00010,000

PM10 24-Hour 34 45 32 150

PM2.5c 24-HourAnnual

208.3

249.2

2311.1

3512

a1-hour 3-year average 99th percentile value for SO2 is 21.0 g/m3.b1-hour 3-year average 98th percentile value for NO2 is 75.8 g/m3.c24-hour 3-year average 98th percentile value for PM-2.5 is 22.3 g/m3; Annual 3-year average value for PM2.5 is 9.5 g/m3.High second-high short term (1-, 3-, 8-, and 24-hour) and maximum annual average concentrations presented for all pollutants other than PM2.5 and 1-hour SO2 and NO2. Bold values represent the proposed background values for use in any necessary NAAQS/NYAAQS analyses. Monitored background concentrations obtained from the USEPA AirData website(https://www3.epa.gov/airdata/).

Millennium Pipeline Company LLC 4-3 Highland Compressor Station

4.2 Modeling Methodology

An air quality modeling analysis was performed consistent with the procedures found in the following documents: Guideline on Air Quality Models (Revised) (USEPA, 2005), New Source Review Workshop Manual (USEPA, 1990), Screening Procedures for Estimating the Air Quality Impact of Stationary Sources (USEPA, 1992), and DAR-10: NYSDEC Guidelines on Dispersion Modeling Procedures for Air Quality Impact Analysis(NYSDEC, 2006).

4.2.1 Model Selection

The USEPA has compiled a set of preferred and alternative computer models for the calculation of pollutant impacts. The selection of a model depends on the characteristics of the source, as well as the nature of the surrounding study area. Of the four classes of models available, the Gaussian type model is the most widely used technique for estimating the impacts of nonreactive pollutants.

The AERMOD model was designed for assessing pollutant concentrations from a wide variety of sources (point, area, and volume). AERMOD is currently recommended by the USEPA for modeling studies in rural or urban areas, flat or complex terrain, and transport distances less than 50 kilometers, with one hour to annual averaging times.

The latest version of USEPA’s AERMOD model (Version 15181) was used in the analysis. AERMOD was applied with the regulatory default options and 5-years (2011-2015) of hourly meteorological data consisting of surface observations from Binghamton Edwin A Link Field in Binghamton, NY and concurrent upper air data from Albany, NY.

4.2.2 Urban/Rural Area Analysis

A land cover classification analysis was performed to determine whether the URBAN option in the AERMOD model should be used in quantifying ground-level concentrations. The methodology utilized to determine whether the project is located in an urban or ruralarea is described below.

The following classifications relate the colors on a United States Geological Survey (USGS) topographic quadrangle map to the land use type that they represent:

Blue – water (rural);Green – wooded areas (rural);


White – parks, unwooded, non-densely packed structures (rural);Purple – industrial; identified by large buildings, tanks, sewage disposal or filtration plants, rail yards, roadways, and, intersections (urban);Pink – densely packed structures (urban); and,Red – roadways and intersections (urban)

The USGS map covering the area within a 3-kilometer radius of the facility was reviewed and indicated that the vast majority of the surrounding area is denoted as blue, green, or white, which represent water, wooded areas, parks, and non-densely packed structures. Additionally, the “AERMOD Implementation Guide” published on August 3, 2015 cautions users against applying the Land Use Procedure on a source-by-source basis and instead to consider the potential for urban heat island influences across the full modeling domain. This approach is consistent with the fact that the urban heat island is not a localized effect, but is more regional in character.

Because the urban heat island is more of a regional effect, the Urban Source option in AERMOD was not utilized since the area within 3 kilometers of the facility as well as the full modeling domain (20 kilometers by 20 kilometers) is predominantly rural.

4.2.3 Good Engineering Practice Stack Height

Section 123 of the Clean Air Act (CAA) required the USEPA to promulgate regulations to assure that the degree of emission limitation for the control of any air pollutant under an applicable State Implementation Plan (SIP) was not affected by (1) stack heights that exceed Good Engineering Practice (GEP) or (2) any other dispersion technique. The USEPA provides specific guidance for determining GEP stack height and for determining whether building downwash will occur in the Guidance for Determination of Good Engineering Practice Stack Height (Technical Support Document for the Stack Height Regulations), (USEPA, 1985). GEP is defined as “…the height necessary to ensure that emissions from the stack do not result in excessive concentrations of any air pollutant in the immediate vicinity of the source as a result of atmospheric downwash, eddies, and wakes that may be created by the source itself, or nearby structures, or nearby terrain “obstacles”.”

The GEP definition is based on the observed phenomenon of atmospheric flow in the immediate vicinity of a structure. It identifies the minimum stack height at which significant adverse aerodynamics (downwash) are avoided. The USEPA GEP stack height regulations (40 CFR 51.100) specify that the GEP stack height (HGEP) be calculated in the following manner:


HGEP = HB + 1.5L

Where: HB = the height of adjacent or nearby structures, andL = the lesser dimension (height or projected width

of the adjacent or nearby structures).

A detailed plot plan of the proposed facility is shown in Figure 2-3. A GEP stack height analysis has been conducted using the USEPA approved Building Profile Input Program with PRIME (BPIPPRM, version 04274). The maximum calculated GEP stack height for the new emission sources is 77.5 feet; the controlling structure is the proposedcompressor building (31.0 feet). Direction-specific downwash parameters were determined using BPIPPRM, version 04274. Electronic input and output files for the BPIPPRM model have been provided on the DVD-ROM contained in Appendix C.

4.2.4 Meteorological Data

If at least one year of hourly on-site meteorological data is not available, the application of the AERMOD dispersion model requires five years of hourly meteorological data that are representative of the project site. In addition to being representative, the data must meet quality and completeness requirements per USEPA guidelines. The closest source of representative hourly surface meteorological data is Binghamton Edwin A Link Field located in Binghamton, NY located approximately 71 miles to the northwest of the Highland Compressor Station.

The meteorological data at the Binghamton Edwin A Link Field is recorded by an Automated Surface Observing System (ASOS) that records 1-minute measurements of wind direction and wind speed along with hourly surface observations necessary. The USEPA AERMINUTE program was used by the NYSDEC to process 1-minute ASOS wind data (2011 – 2015) from the Binghamton surface station in order to generate hourly averaged wind speed and wind direction data to supplement the standard hourly ASOS observations. The hourly averaged wind speed and direction data generated by AERMINUTE was merged with the aforementioned hourly surface data.

The AERMOD assessment utilized five (5) years (2011–2015) of concurrent meteorological data collected from a meteorological tower at the Binghamton Edwin A Link Field and from radiosondes launched from Albany, New York. Both the surface and upper air sounding data were processed by the NYSDEC using AERMOD’s meteorological processor, AERMET (version 15181). The output from AERMET was used as the meteorological database for the modeling analysis and consists of a surface data file and


a vertical profile data file. These data, which were prepared and processed to AERMOD format by the NYSDEC, was provided for use in the modeling analyses for the proposed facility.

4.3 Receptor Grid

4.3.1 Basic Grid

The AERMOD model requires receptor data consisting of location coordinates and ground-level elevations. The receptor generating program, AERMAP (Version 11103), was used to develop a complete receptor grid to a distance of 10 kilometers from the proposed facility. AERMAP uses digital elevation model (DEM) or the National Elevation Dataset (NED) data obtained from the USGS. The preferred elevation dataset based on NED data was used in AERMAP to process the receptor grid. This is currently the preferred data to be used with AERMAP as indicated in the USEPA AERMOD Implementation Guide published August 3, 2015. AERMAP was run to determine the representative elevation for each receptor using 1/3 arc second NED files that were obtained for an area covering at least 10 kilometers in all directions from the proposed facility. The NED data was obtained through the USGS Seamless Data Server (http://seamless.usgs.gov/index.php).

The following rectangular (i.e. Cartesian) receptors were used to assess the air quality impact of the proposed facility:

Consistent with DAR-10 guidance, fine grid receptors (70 meter spacing) for a 20 km (east-west) x 20 km (north-south) grid centered on the proposed facility site.

4.3.2 Property Line Receptors

The facility has a fenced property line that precludes public access to the site. Ambient air is therefore defined as the area at and beyond the fence. The modeling receptor grid includes receptors spaced at 25-meter intervals along the entire fence line. Any Cartesian receptors located within the fence line were removed.


4.4 Selection of Sources for Modeling

The emission source responsible for most of the potential emissions from the HighlandCompressor Station is the single combustion turbine. This unit was included in and is the main focus of the modeling analyses. The modeling includes consideration of operation over a range of turbine loads, ambient temperatures, and operating scenarios.

Ancillary sources (emergency diesel generators and fuel gas heater) were included in the modeling for appropriate pollutants and averaging periods. The emergency equipment may operate for up to 30 minutes in any day for readiness testing and maintenance purposes. Operation of the emergency equipment for longer periods of time in an emergency mode will not be expected to occur when the turbines are operating.

Although only limited operation is expected from the emergency equipment, initial modeling to assess short-term facility impacts assumed concurrent operation of the emergency equipment for readiness testing (i.e., up to 30 minutes per day) with the combustion turbine.

4.4.1 Emission Rates and Exhaust Parameters

The dispersion modeling analysis was conducted with emission rates and flue gas exhaust characteristics (flow rate and temperature) that are expected to represent the range of possible values for the proposed natural gas fired turbine. Because emission rates and flue gas characteristics for a given turbine load vary as a function of ambient temperature and fuel use, data were derived for a number of ambient temperature cases for natural gas fuel at 100%, 75% and 50% operating loads. The temperatures were:

• <0°F, 0°F, 20°F, 40°F, 60°F, 80°F and 100°F.

A detailed summary of the stack exhaust and emissions data for all loads and ambient temperatures cases are provided in Appendix B. To be conservative and limit the number of cases to be modeled, the short-term modeling analysis was conducted using the lowest stack exhaust temperature and exit velocity coupled with the maximum emission rate over all ambient temperature cases for each operating load (with the exception of 1-hour NO2 modeling which excluded the <0ºF data as discussed below). Annual modeling was based on the 100% load 40°F case (vendor performance data for the turbine was available for 40°F and 60°F). The annual average temperature for the project area is approximately 50°F. Use of the 40ºF emissions data is conservative as emissions are slightly higher than


the 60°F case.). Table 4-2 summarizes the stack parameters and emission rates used in the modeling for the compressor turbine.

Note that the modeling for 1-hour NO2 excluded the emergency generator for which normal operations (maintenance purposes only) will be limited to no more than 30 minutes per day with an annual limit of 100 hours per year for testing and maintenance purposes. The 1-hour NO2 modeling also did not consider combustion turbine operations under sub-zero ambient temperature conditions as these conditions are extremely limited annually. The exclusion of the emergency generator and sub-zero operations for the combustion turbines for the 1-hour NO2 modeling is based on USEPA guidance provided in the March 1, 2011 memorandum, “Additional Clarification Regarding Application of Appendix W Modeling Guidance for the 1-hour NO2 National Ambient Air Quality Standard” for intermittent sources such as emergency generators. In the memo, US EPA states the following:

“Given the implications of the probabilistic form of the 1-hour NO2 NAAQS discussed above, we are concerned that assuming continuous operation of intermittent emissions would effectively impose an additional level of stringency beyond that level intended by the standard itself. As a result, we feel it would be inappropriate to implement the 1-hour NO2 standard in such a manner and recommend that compliance demonstrations for the 1-hour NO2 NAAQS be based on emission scenarios that can logically be assumed to be relatively continuous or which occur frequently enough to contribute significantly to the annual distribution of daily maximum 1-hour concentrations.”

The emergency generator and sub-zero operation of the combustion turbine are considered as intermittent emissions, and thus, were excluded from the 1-hour NO2 modeling assessment.

Table 4-2: Stack Parameters and Emission Rates – Proposed Titan 130E Compressor Turbine

Parameter ValuesLoad 50% 75 100% Annual(2)

Stack Height (m) 18.29 18.29 18.29 18.29

Stack Diameter (m)(1) 3.27 3.27 3.27 3.27Exhaust Velocity (m/s) 9.60 11.38 12.69 14.33Exhaust Temperature (K) 720.4 730.9 758.7 765.9

Pollutant Emissions(g/s)

NOx 0.869 1.079 1.271 1.395CO 5.292 6.562 7.734 -SO2 0.095 0.115 0.132 0.132PM10/PM2.5 0.255 0.308 0.353 0.353


(1) The turbine stack is square (114 inches x 114 inches). The value listed and used in the modeling is theeffective diameter for an equivalent area circular stack.(2) Based on conservative annual average exhaust parameters for 40ºF and annual potential toemit discussed in Section 2.

Tables 4-3 and 4-4 present the stack parameters and emission rates for the emergency diesel generator and fuel gas heater. The emergency diesel generator was included in the modeling analysis for appropriate pollutants and averaging periods when used for readiness testing (i.e., up to 30 minutes per day).

Table 4-4: Stack Parameters and Emission Rates – Proposed Emergency Generator

Parameter ValuesStack Height (m) 5.94Stack Diameter (m) 0.30Exhaust Velocity (m/s) 39.84Exhaust Temperature (K) 721.5Averaging Period 1-hr 3-hr 8-hr 24-hr Annual

PollutantEmissions (g/sec)

NOx 0.3422 - - - 0.039CO 0.683 - 0.085 - -SO2 0.0004 0.00013 - 0.000015 0.00004PM10/PM2.5 0.0061 - - 0.00025 0.00069

Notes:Hourly emission rate divided by 2 to simulate limit of 30 minutes testing per day. For the 3-, 8- and24-hour period the hourly emission rate is further divided by the number of hours in the period.

Table 4-5: Stack Parameters and Emission Rates – Proposed Fuel Gas Heater

Parameter ValuesStack Height (m) 4.877Stack Diameter (m) 0.406Exhaust Velocity (m/s) 1.86Exhaust Temperature (K) 510.9

PollutantEmissions (g/sec)

NOx 0.015CO 0.012SO2 0.0008PM10/PM2.5 0.0012


4.5 Maximum Modeled Facility Concentrations

Table 4-5 presents the maximum modeled air quality concentrations of the proposed facility calculated by AERMOD. As shown in this table, the maximum modeled concentrations when combined with a representative background concentration, are less than the applicable NAAQS/NYAAQS for all pollutants.

Table 4-5: Facility Maximum Modeled Concentrations Compared to NAAQS/NYAAQS

PollutantAveraging

Period

NAAQS/NYAAQS ( g/m3)

Maximum Modeled

Concentration ( g/m3)

Background Concentration

( g/m3)

Total Concentration

( g/m3)

CO1-Hour 40,000 312 2,070 2,3828-Hour 10,000 89 1,495 1,584

SO2

1-Hour 196 1.8 21.0 22.83-Hour 1,300 1.7 23.6a 25.3

24-Hour -/260 0.8 13.9 14.7Annual -/60 0.09 2.1 2.2

PM-10 24-Hour 150 2.1 45 47.1

PM-2.524-Hour 35 0.7 22.3 23.0Annual 12 0.13 9.5 9.6

NO21-Hour 188 20.9b 75.8 96.7

Annual 100 1.6c 20.0 21.6aConservatively based upon maximum 1-hour SO2 monitored concentration.bAssumed 80% of NOx is NO2 per USEPA guidance.cAssumed 75% of NOx is NO2 per USEPA guidance.

4.6 Toxic Ambient Air Contaminant Analysis

Air quality modeling was conducted for potential toxic (non-criteria) air pollutant emissions from the proposed non-exempt facility sources. The modeling methodology used in the toxic air pollutant analysis was the same as used in the Part 201 air quality analyses for criteria air pollutants. Maximum modeled short-term and annual ground level concentrations of each toxic air pollutant were compared to the DEC’s short-term guideline concentration (SGC) and annual guideline concentration (AGC), respectively. The DEC SGCs and AGCs used in the analysis are listed in the DAR-1 (formerly Air Guide-1) tables that were published by the DEC in February 2014.


Unit concentrations for the 1-hour and annual averaging periods were calculated for the combustion turbine. The maximum toxic air pollutant-specific emission rate was multiplied by the modeled unit concentration to determine the maximum pollutant-specific concentration. Presented in Table 4-6 are the NYSDEC SGCs and AGCs and the facility maximum modeled concentrations for each toxic air pollutant. As shown in the table, all of the maximum modeled toxic air pollutants are well below their corresponding NYSDEC SGC and AGC.

4.7 Modeling Data Files

All modeling data files to determine the maximum ambient ground-level concentrations from the proposed facility are included on DVD-ROM in Appendix C.

4.8 References

NYSDEC, 2006. NYSDEC Guidelines on Dispersion Modeling Procedures for Air Quality Impact Analysis – DAR 10. Impact Assessment and Meteorology Section, Bureau of Stationary Sources. May 9, 2006.

USEPA, 2015. AERMOD Implementation Guide. AERMOD Implementation Workgroup, Office of Air Quality Planning and Standards, Air Quality Assessment Division, Research Triangle Park, North Carolina. August 3, 2015.

USEPA, 2014. Clarification on the Use of AERMOD Dispersion Modeling for Demonstrating Compliance with the NO2 National Ambient Air Quality Standard. USEPA. September 30, 2014.

USEPA, 2011. Additional Clarification Regarding Application of Appendix W Modeling Guidance for the 1-Hour NO2 NAAQS. USEPA. March 1, 2011.

USEPA, 2005. Guideline on Air Quality Models (Revised). Appendix W to Title 40 U.S. Code of Federal Regulations (CFR) Parts 51 and 52, Office of Air Quality Planning and Standards, U.S. Environmental Protection Agency. Research Triangle Park, North Carolina. November 6, 2005.

USEPA, 1992. "Screening Procedures for Estimating the Air Quality Impact of Stationary Sources, Revised". EPA Document 454/R-92-019, Office of Air Quality Planning and Standards, Research Triangle Park, North Carolina.

USEPA, 1990. "New Source Review Workshop Manual, Draft". Office of Air Quality Planning and Standards, U.S. Environmental Protection Agency. Research Triangle Park, North Carolina.


USEPA, 1985. Guidelines for Determination of Good Engineering Practice Stack Height (Technical Support Document for the Stack Height Regulations-Revised). EPA-450/4-80-023R. U.S. Environmental Protection Agency.

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APPENDIX A NYSDEC APPLICATION FORMS

-

Subdivision Paragraph Subparagraph ClauseFacility State Only Requirements Continuation Sheet(s)

SubclauseTitle Type Part Subpart Section

For all emission units subject to any applicable requirements that will become effective during the term of the permit, this facility will meet such requirements on a timely basis.

Compliance certification reports will be submitted at least once per year. Each report will certify compliance status with respect to each applicable requirement, and the method used to determine the status.

Title Type Part Subparagraph ClauseSubpart SubclauseSection Subdivision Paragraph

Affected States (Title V Facilities Only) Vermont Massachusetts Rhode Island Pennsylvania Tribal Land: __________________

New Hampshire Connecticut New Jersey Ohio Tribal Land:

NAICS Code(s)SIC Code(s)

Facility Description Continuation Sheet(s)

Facility Applicable Federal Requirements Continuation Sheet(s)

Compliance Statements (Title V Facilities Only)I certify that as of the date of this application the facility is in compliance with all applicable requirements. Yes NoIf one or more emission units at the facility are not in compliance with all applicable requirements at the time of signing this application (the 'NO" box must be checked), the noncomplying units must be identified in the "Compliance Plan" block on page 8 of this form along with the compliance plan information required. For all emission units at the facility that are operating in compliance with all applicable requirements, complete the following:

This facility will continue to be operated and maintained in such a manner as to assure compliance for the duration of the permit, except those emission units referenced in the compliance plan portion of this application.

New York State Department of Environmental ConservationAir Permit Application

DEC ID

Project Description Continuation Sheet(s)

Section III - Facility InformationFacility Classification

Hospital Residential Educational/Institutional Commercial Industrial Utility

As part of the Eastern System Upgrade Project and in order to boost pressures on Millennium’s transmission pipelinesystem, Millennium is proposing to construct and operate one Solar Titan 130E compressor turbine at the HighlandCompressor Station. Ancillary project emission sources include one (1) 1,230 hp emergency generator, one (1) 1.2MMBtu/hr gas heater, one 4,000 gallon NGL tank, and a 1,500 gallon oil tank.

4922

Millennium Pipeline Company, L.L.C. (Millennium) is proposing to construct and operate the Highland CompressorStation located in Sullivan County, New York. The Highland Compressor Station (CS) is a natural gas transmissionfacility covered by Standard Industrial Classification (SIC) 4922.

6 NYCRR 202 1

6 NYCRR 211 1

6 NYCRR 212

6 NYCRR 227 1

6 NYCRR 201 3

6 NYCRR 201 5

Version 1.2 - 3/4/2015

-

007439 - 92 - 1 Lead (elemental)

0NY750 - 00 - 0 Carbon Dioxide Equivalents

0NY998 - 00 - 0 Total Volatile Organic Compounds

0NY100 - 00 - 0 Total Hazardous Air Pollutants

000630 - 08 - 0 Carbon Monoxide

007446 - 09 - 5 Sulfur Dioxide

0NY210 - 00 - 0 Oxides of Nitrogen

0NY075 - 00 - 5 PM-10

Range Code

(lbs/yr)

0NY750 - 02 - 5 PM-2.5

CAS Number Contaminant Name

Facility Emissions Summary Continuation Sheet(s)Potential to Emit

Actual (lbs/yr)

Averaging Method Monitoring Frequency Reporting RequirementsCode Description Code Description Code Description

LimitUpper Lower

Limit UnitsCode Description

Work PracticeType Code Description

Process Material Reference Test Method

ParameterCode Description Manufacturer's Name/Model Number

Applicable Federal Requirement State Only Requirement

CappingCAS Number Contaminant Name

Monitoring Information Ambient Air Monitoring Work Practice Involving Specific Operations Record Keeping/Maintenance Procedures

Description

SubclauseRule Citation

Title Type Part Subpart Section Subdivision Paragraph Subparagraph Clause

DEC ID

Facility Compliance Certification Continuation Sheet(s)


C >= 1

C >= 1

B >= 2

F >= 5

F >= 5

-

B >= 2

B >= 2

J >= 10

71-43-2 Benzene Y > 0 b

50-00-0 Formaldehyde Y > 0 b

-

Version 1.2 - 3/4/2015

-

-

Design Capacity

Design Capacity Units Waste Feed Waste TypeCode Description Code Description Code Description

Emission Source Date of Construction

Date of Operation

Date of Removal

Control Type Manufacturer's Name/Model NumberID Type Code Description

Design Capacity

Design Capacity UnitsCode Description

Waste FeedCode Description

Date of Construction

Date of Operation

Waste TypeCode Description

DescriptionManufacturer's

Name/Model NumberEmission Source

ID TypeDate of

RemovalControl Type

Code

Emission Source/Control Information Continuation Sheet(s)

Exit Velocity (FPS)

Exit Flow (ACFM)

NYTM (E) (KM) NYTM (N) (KM) Building Distance to Property Line (ft)

Date of Removal

Ground Elevation (ft)

Height (ft) Height Above Structure (ft)

Inside Diameter (in) Exit Temp. (oF)

Cross SectionLength (in) Width (in)


Emission Point

Date of RemovalExit Velocity (FPS)

Exit Flow (ACFM)





Emission PointEmission Point Information Continuation Sheet(s)

Building ID Length (ft) Width (ft) OrientationBuilding Name

Emission Unit


Building Information Continuation Sheet(s)

Air Permit ApplicationDEC ID

Section IV - Emission Unit InformationEmission Unit Description Continuation Sheet(s)

U 0 0 0 0 1

Solar Titan 130E Combustion Turbine

1 Compressor Building - Titan 130E 100 60 125

2 Station Control/Auxiliary Building 60 40 125

0 0 0 0 1

1,333 60 29 927 114 114

45.9 248,350 511.142 4603.786 1 150

T U R B 1 C Solar Titan 130E

167.8 25

S L N X 1 K 103 Solar SoLoNOx

Version 1.2 - 3/4/2015

-

-

-

Confidential Operating at Maximum Capacity

Emission Source/Control Identifier(s)

Emission Point Identifier(s)


Throughput Quantity UnitsQuantity/Hr Quantity/Yr

Emission Unit Process

Description

Code

Operating ScheduleBuilding Floor/Location

Hours/Day Days/Year

Floor/Location


Operating ScheduleHours/Day

Source Classification Code (SCC)Total Throughput

Quantity/Hr Quantity/YrThroughput Quantity Units

Building


Description

Code Description


Description


Days/Year


DEC ID

Process Information Continuation Sheet(s)

U 0 0 0 0 1 0 0 1


2-02-002-01

24 365 1 Ground

00001

TURB1

SLNX1

Version 1.2 - 3/4/2015

-

Applicable Federal Requirement State Only Requirement CappingEmission Source


Rule CitationTitle Type Part Subpart Section Subdivision

Monitoring Information

Emission Unit Emission Point

Process

Emission Unit Compliance Certification Continuation Sheet(s)

SubclauseParagraph Subparagraph Clause

Subparag. Cl. Subcl. Continuation Sheet(s)

Title Type PartEmission Unit

Emission Point

ProcessEmission Source

Emission Unit State Only RequirementsSubpart Section Subdiv. Parag.

ProcessEmission Source Title Subpart Subparag.Section Subdiv. Parag. Cl. Subcl.

Emission Unit Applicable Federal Requirements

DEC ID


PartType Continuation Sheet(s)

Emission UnitEmission

Point

Description

Ambient Air Monitoring Record Keeping/Maintenance ProceduresDescription

Work Practice Process MaterialReference Test Method

Type

ParameterManufacturer's Name/Model Number

Code Description

Continuous Emission Monitoring Monitoring of a Process or Control Device Parameters as a Surrogate Intermittent Emission Testing Work Practice Involving Specific Operations

Code Description

Limit Limit UnitsUpper Lower Code Description

Averaging Method Monitoring Frequency Reporting RequirementsCode Description Code Description

Code

U00001 40 CFR 60 KKKK 4305 a

U00001 40 CFR 60 KKKK 4320 a

U00001 40 CFR 60 KKKK 4330

U00001 40 CFR 60 KKKK 4333 a

U00001

U00001

U00001

U00001

40 CFR 60 KKKK 4320 a

U00001 001 0NY210-00-0 Oxides of Nitrogen

The owner or operator of a stationary combustion turbine must meet the appropriate emission limit for the operationcondition listed in Table 1 of this Subpart. The emission limit is 25 ppm at 15 percent Oxygen for operation at ambient

temperatures greater than 0 degrees F.

25 275

20 14 16

Version 1.2 - 3/4/2015

- -

Applicable Federal Requirement State Only Requirement Capping

Subparagraph Clause

Emission Unit CAS No. Contaminant Name

Continuation Sheet ____ of ____

Description

Code Description Code Description Code DescriptionAveraging Method Monitoring Frequency Reporting Requirements

LimitUpper


ParameterCode Description

Manufacturer Name/Model No.

Work PracticeType

Process MaterialCode Description

Reference Test Method

Lower

Emission Point Process

Subclause

Section IV - Emission Unit InformationEmission Unit Compliance Certification (continuation)

Rule CitationTitle Type Part Subpart Section Subdivision Paragraph

Monitoring Information Continuous Emission Monitoring Intermittent Emission Testing Ambient Air Monitoring

Monitoring of Process or Control Device Parameters as a Surrogate Work Practice Involving Specific Operations Record Keeping/Maintenance Procedures

Emission Source

New York State Department of Environmental ConservationAir Permit Application Form

DEC ID

40 CFR KKKK a

U00001 001 007446-09-5

The facility may elect not to monitor the total sulfur content of the fuel combusted in the turbine, if the fuel isdemonstrated not to exceed potential sulfur emissions of 0.060 lb/SO2/mmBtu of heat input. The facility must use thefuel quality characteristics in a current, valid purchase contract, tariff sheet, or transportation contract for the fuel,specifying that"

1. The total sulfur content for natural gas use is 20 grains of sulfur or less per 100 standard cubic feet, or2. Has potential sulfur emissions less than 0.060 lb SO2/mmBtu heat input.

The FERC gas tariff will be used to demonstrate compliance with this requirement

13 14

- -

Subpart Section Subdiv. Parag.


Type Part Clause


DEC ID

Section IV - Emission Unit InformationEmission

UnitEmission

PointProcess

Emission Source

Emission Unit Applicable Federal Requirements (continuation)Title Subparag. Subcl.

U00001 40 KKKK 4305 a

U00001 40 KKKK 4320 a

U00001 40 KKKK 4330

U00001 40 KKKK 4333 a

U00001 6 NYCRR 202 1 1

U00001 6 NYCRR 202 1 2

U00001 6 NYCRR 211 1

U00001 6 NYCRR 227 1 2

U00001 6 NYCRR 227 1 3 b

-

-

-

-


Clause SubclausePart Subpart Section Subdivision Paragraph Subparagraph

DEC ID

Determination of Non-Applicability (Title V Only) Continuation Sheet(s)Rule Citation

Title Type

Emission Unit Emission Point Process Emission Source Applicable Federal Requirement State Only Requirement

Type Part Subpart Section Subdivision Paragraph

Description

Rule CitationTitle



Description

Process Emissions Summary Continuation Sheet(s)

Subparagraph Clause Subclause

ERP How DeterminedCAS Number Contaminant Name % Thruput % Capture % Control ERP (lbs/hr)

Process

Potential to Emit(lbs/hr) (lbs/yr) (standard units)

Standard Units

Potential to Emit How Determined

Actual Emissions(lbs/hr) (lbs/yr)

Emission Unit

(standard units) (lbs/hr) (lbs/yr)

CAS Number Contaminant Name % Thruput % Capture % Control ERP (lbs/hr) ERP How Determined


Potential to Emit Standard Units



(lbs/hr) (lbs/yr)




Actual Emissions(lbs/hr) (lbs/yr) (standard units)

60

U00001/U00002

CFR

Sulfur Dioxide

Version 1.2 - 3/4/2015

-

-


ERP (lbs/yr)Potential to Emit

(lbs/hr) (lbs/yr)Actual Emissions

(lbs/hr) (lbs/yr)


DEC ID

Emission Unit Emission Unit Emissions Summary Continuation Sheet(s)


(lbs/yr) (lbs/hr) (lbs/yr)

ERP (lbs/yr)Potential to Emit Actual Emissions

(lbs/hr) (lbs/yr) (lbs/hr) (lbs/yr)



(lbs/hr)


Certified progress reports are to be submitted every 6 months beginning / /



Parag. Subparag. Clause Subcl.

Compliance Plan Continuation Sheet(s)For any emission units which are not in compliance at the time of permit application, the applicant shall complete the following:

Consent Order

Emission Unit Process Emission Source

Applicable Federal RequirementTitle Type Part Subpart Section Subdiv.

Date ScheduledR/IRemedial Measure(s) / Intermediate Milestone(s)

Version 1.2 - 3/4/2015

-

- - /

- - /

Continuation Sheet(s)Emission Source

Date MethodBaseline Period ____ /____ /________ to ____ / ____ / ________


DEC ID

Request for Emission Reduction Credits

Emission Reduction Description

Contaminant Emission Reduction DataReduction

Facility to Use Future Reduction

CAS Number Contaminant NameERC (lbs/yr)

Netting Offset

Use of Emission Reduction Credits Continuation Sheet(s)

CAS Number Contaminant Name PEP (lbs/yr)

Application ID

Name

Location Address

City/ Town / Village State Zip

Name

Permit ID

Location Address

Emission SourceProposed Project Description

Contaminant Emissions Increase Data

ERC (lbs/yr)Netting OffsetContaminant Name

Statement of Compliance All facilities under the ownership of this "owner/firm" are operating in compliance with all applicable requirements and state

regulations including any compliance certification requirements under Section 114(a)(3) of the Clean Air Act Amendments of 1990, or are meeting the schedule of a consent order.

Source of Emission Reduction Credit - Facility


Emission Source CAS Number

Version 1.2 - 3/4/2015

-

Required Supporting Documentation: List of Exempt Activities (form attached) Plot Plan Process Flow Diagram Methods Used to Determine Compliance (form attached) Calculations

Optional Supporting Documentation: Air Quality Model ( ____ / ____ / _____ ) Confidentiality Justification Ambient Air Monitoring Plan ( ____ / ____ / _____ ) Stack Test Protocols/Reports ( ____ / ____ / _____ ) Continuous Emissions Monitoring Plans/QA/QC ( ____ / ____ / _____ ) MACT Demonstration ( ____ / ____ / _____ ) Operational Flexibility: Description of Alternative Operating Scenarios and Protocols Title IV: Application/Registration (where appropriate) ERC Quantification (form attached) Baseline Period Demonstration Use of ERC(s) (form attached) Analysis of Contemporaneous Emissions Increase/Decrease LAER Demonstration ( ____ / ____ / _____ ) BACT Demonstration ( ____ / ____ / _____ ) Other Document(s):

( / / )

( / / )

( / / )

( / / )


DEC ID

Supporting Documentation

( / / )

( / / )

( / / )

( / / )

( / / )

( / / )

( / / )

( / / )

( / / )

( / / )

Version 1.2 - 3/4/2015

- -


DEC ID

Methods Used to Determine ComplianceEmission Unit

IDCompliance

Date

Sheet _____ of _____Version 1 / /201

Applicable Requirement

Method Used to Determine Compliance

U00001 40 CFR60.4320(a)

An initial compliance test will be performed after installationand annual stack testing will be performed after installationas required by the regulation for compliance with the NSPS

U00001 40 CFR60.4365

The FERC gas tariff will be used to demonstratecompliance with this requirement

U00001 6 NYCRR200.6

An initial compliance test will be performed after installationand annual stack testing will be performed following the NSPSrequirements to demonstrate compliance with the NOx limit.

- -

3/30/2015 Page 1 of 6

(4) Reserved.

(5) Gas turbines with a heat input at peak load less then 10 mmBtu/hour

(3)(ii)

Stationary or portable internal combustion engines that are liquid or gaseous fuel powered and located outside of the New York City metropolitan area or the Orange County towns of Blooming Grove, Chester, Highlands, Monroe, Tuxedo, Warwick, or Woodbury, and have a maximum mechanical power rating of less than 400 brake horsepower.

(3)(iii)Stationary or portable internal combustion engines that are gasoline powered and have a maximum mechanical power rating of less than 50 brake horsepower.

(3)(i)

Stationary or portable internal combustion engines that are liquid or gaseous fuel powered and located within the New York City metropolitan area or the Orange County towns of Blooming Grove, Chester, Highlands, Monroe, Tuxedo, Warwick, or Woodbury, and have a maximum mechanical power rating of less than 200 brake horsepower.

Combustion

Rule Citation

201-3.2(c)Description

Number of

Activities

Building Location

(1)

Stationary or portable combustion installations where the furnace has a maximum heat input capacity less than 10 mmBtu/hr burning fuels other than coal or wood; or a maximum heat input capacity of less than 1 mmBtu/hr burning coal or wood. This activity does not include combustion installations burning any material classified as solid waste, as defined in 6 NYCRR Part 360, or waste oil, as defined in 6 NYCRR Subpart 225-2.


DEC ID

List of Exempt ActivitiesInstructions

Applicants for Title V facility permits must provide a listing of each exempt activity, as described in 6 NYCRR Part 201-3.2(c), that is currently operated at the facility. This form provides a means to fulfill this requirement.

In order to complete this form, enter the number and building location of each exempt activity. Building IDs used on this form should match those used in the Title V permit application. If a listed activity is not operated at the facility, leave the corresponding information blank.

(2)

Space heaters burning waste oil at automotive service facilities, as defined in 6 NYCRR Subpart 225-2, generated on-site or at a facility under common control, alone or in conjunction with used oil generated by a do-it-yourself oil changer as defined in 6 NYCRR Subpart 374-2.

1 NA

- -

3/30/2015 Page 2 of 6

Commercial - Graphic Arts

(12)Screen printing inks/coatings or adhesives which are applied by a hand-held squeegee. A hand-held squeegee is one that is not propelled though the use of mechanical conveyance and is not an integral part of the screen printing process.

(13)

Graphic arts processes at facilities located outside the New York City metropolitan area or the Orange County towns of Blooming Grove, Chester, Highlands, Monroe, Tuxedo, Warwick, or Woodbury whose facility-wide total emissions of volatile organic compounds from inks, coatings, adhesives, fountain solutions and cleaning solutions are less than three tons during any 12-month period.

Commercial - Food Service Industries

(10)Flour silos at bakeries, provided all such silos are exhausted through an appropriate emission control device.

(11)Emissions from flavorings added to a food product where such flavors are manually added to the product.

Agricultural

(8)

Feed and grain milling, cleaning, conveying, drying and storage operations including grain storage silos, where such silos exhaust to an appropriate emissions control device, excluding grain terminal elevators with permanent storage capacities over 2.5 million U.S. bushels, and grain storage elevators with capacities above one million bushels.

(9)Equipment used exclusively to slaughter animals, but not including other equipment at slaughterhouses, such as rendering cookers, boilers, heating plants, incinerators, and electrical power generating equipment.

(6)

Emergency power generating stationary internal combustion engines, as defined in 6 NYCRR Part 200.1(cq), and engine test cells at engine manufacturing facilities that are utilized for research and development, reliability performance testing, or quality assurance performance testing. Stationary internal combustion engines used for peak shaving and/or demand response programs are not exempt.

Combustion Related

(7)Non-contact water cooling towers and water treatment systems for process cooling water and other water containers designed to cool, store or otherwise handle water that has not been in direct contact with gaseous or liquid process streams.


DEC ID

Rule Citation


Number of

Activities

Building Location

g

1 NA

- -

(21)Distillate fuel oil, residual fuel oil, and liquid asphalt storage tanks with storage capacities below 300,000 barrels.

3/30/2015 Page 3 of 6

Municipal/Public Health Related

(20)

Landfill gas ventilating systems at landfills with design capacities less than 2.5 million megagrams (3.3 million tons) and 2.5 million cubic meters (2.75 million cubic yards), where the systems are vented directly to the atmosphere, and the ventilating system has been required by, and is operating under, the conditions of a valid 6 NYCRR Part 360 permit, or order on consent.

Storage Vessels

(18)Abrasive cleaning operations which exhaust to an appropriate emission control device.

(19) Ultraviolet curing operations.

Commercial - Other

(16)Gasoline dispensing sites registered with the department pursuant to 6 NYCRR Part 612.

(17)

Surface coating and related activities at facilities which use less than 25 gallons per month of total coating materials, or with actual volatile organic compound emissions of 1,000 pounds or less from coating materials in any 12-month period. Coating materials include all paints and paint components, other materials mixed with paints prior to application, and cleaning solvents, combined. This exemption is subject to the following:

(i) The facility is located outside of the New York City metropolitan area or the Orange County towns of Blooming Grove, Chester, Highlands, Monroe, Tuxedo, Warwick, or Woodbury; and

(ii) All abrasive cleaning and surface coating operations are performed in an enclosed building where such operations are exhausted into appropriate emission control devices.

(14)Graphic label and/or box labeling operations where the inks are applied by stamping or rolling.

(15)Graphic arts processes which are specifically exempted from regulation under 6 NYCRR Part 234, with respect to emissions of volatile organic compounds which are not given an A rating as described in 6 NYCRR Part 212.


DEC ID

Rule Citation


Number of

Activities

Building Location

age 3 o 6

- -

3/30/2015 Page 4 of 6

Industrial

(28)

Processing equipment at existing sand and gravel and stone crushing plants which were installed or constructed before August 31, 1983, where water is used for operations such as wet conveying, separating, and washing. This exemption does not include processing equipment at existing sand and gravel and stone crushing plants where water is used for dust suppression.

(29)(i)Sand and gravel processing or crushed stone processing lines at a non-metallic mineral processing facility that are a permanent or fixed installation with a maximum rated processing capacity of 25 tons of minerals per hour or less.

(26) Horizontal petroleum or volatile organic liquid storage tanks.

(27)Storage silos storing solid materials, provided all such silos are exhausted through an appropriate emission control device. This exemption does not include raw material, clinker, or finished product storage silos at Portland cement plants.

(24)

External floating roof tanks which are used for the storage of a petroleum or volatile organic liquid with a true vapor pressure less than 4.0 psi (27.6 kPa), are of welded construction and are equipped with one of the following:

(i) a metallic-type shoe seal;

(ii) a liquid-mounted foam seal;

(iii) a liquid-mounted liquid-filled type seal; or

(iv) equivalent control equipment or device.

(25)Storage tanks, including petroleum liquid storage tanks as defined in 6 NYCRR Part 229, with capacities less than 10,000 gallons, except those subject to 6 NYCRR Part 229 or Part 233.

Building Location

(22)Pressurized fixed roof tanks which are capable of maintaining a working pressure at all times to prevent emissions of volatile organic compounds to the outdoor atmosphere.

(23)External floating roof tanks which are of welded construction and are equipped with a metallic-type shoe primary seal and a secondary seal from the top of the shoe seal to the tank wall.


DEC ID

Rule Citation


Number of

Activities

g

2 NA

- -

39(ii)Cold cleaning degreasers that use a solvent with a VOC content or five percent or less by weight, unless subject to the requirements of 40 CFR 63 Subpart T.

3/30/2015 Page 5 of 6

(38)Cement storage operations not located at Portland cement plants where materials are transported by screw or bucket conveyors.

(39)(i)Cold cleaning degreasers with an open surface area of 11 square feet or less and an internal volume of 93 gallons or less or, having an organic solvent loss of 3 gallons per day or less.

(36)Presses used exclusively for molding or extruding plastics except where halogenated carbon compounds or hydrocarbon solvents are used as foaming agents.

(37)Concrete batch plants where the cement weigh hopper and all bulk storage silos are

exhausted through fabric filters, and the batch drop point is controlled by a shroud or other emission control device.

(34) Powder coating operations.

(35)All tumblers used for the cleaning and/or deburring of metal products without abrasive blasting.

(32) Pharmaceutical tablet branding operations.

(33)Thermal packaging operations, including, but not limited to, therimage labeling, blister packing, shrink wrapping, shrink banding, and carton gluing.

(30) Reserved.

(31)Surface coating operations which are specifically exempted from regulation under 6 NYCRR Part 228, with respect to emissions of volatile organic compounds which are not given an A rating pursuant to 6 NYCRR Part 212.

(29)(ii)Sand and gravel processing or crushed stone processing lines at a non-metallic mineral processing facility that are a portable emission source with a maximum rated processing capacity of 150 tons of minerals per hour or less.

(29)(iii)Sand and gravel processing or crushed stone processing lines at a non-metallic mineral processing facility that are used exclusively to screen minerals at a facility where no crushing or grinding takes place.


DEC ID

Rule Citation


Number of

Activities

Building Location

age 5 o 6

- -

(48) Manure spreading, handling and storage at farms and agricultural facilities.

3/30/2015 Page 6 of 6

(46) Hydrogen fuel cells.

(47)Dry cleaning equipment that uses only water-based cleaning processes or those using liquid carbon dioxide.

(44)Research and development activities, including both stand-alone and activities within a major facility, until such time as the administrator completes a rule making to determine how the permitting program should be structured for these activities.

(45) The application of odor counteractants and/or neutralizers.

(42)Exhaust systems for paint mixing, transfer, filling or sampling and/or paint storage rooms or cabinets, provided the paints stored within these locations are stored in closed containers when not in use.

(43)Exhaust systems for solvent transfer, filling or sampling, and/or solvent storage rooms provided the solvent stored within these locations are stored in containers when not in use.

Miscellaneous

(40)Ventilating and exhaust systems for laboratory operations. Laboratory operations do not include processes having a primary purpose to produce commercial quantities of materials.

(41)Exhaust or ventilating systems for the melting of gold, silver, platinum and other precious metals.

Building Location

(39)(iii)Conveyorized degreasers with an air/vapor interface smaller than 22 square feet (2 square meters), unless subject to the requirements of 40 CFR 63 Subpart T.

(39)(iv)Open-top vapor degreasers with an open-top area smaller than 11 square feet (1 square meter), unless subject to the requirements of 40 CFR 63 Subpart T.


DEC ID

Rule Citation


Number of

Activities

APPENDIX BEMISSION CALCULATIONS

AND VENDOR DATA

Mil

len

niu

m P

ipel

ine

Com

pan

y, L

LC

Hig

hla

nd

Com

pre

ssor

Sta

tion

Tab

le B

-1. T

otal

Fac

ilit

y P

oten

tial

Em

issi

ons

Su

mm

ary

NO

xC

OV

OC

SO

2P

M/P

M-1

0/

PM

-2.5

CO

2T

otal

HA

PS

CH

4N

2OC

O2e

Sola

r Ti

tan

130E

48.5

978

.08

5.53

4.57

12.2

795

,591

.02.

481.

800.

1895

,690

Wau

kesh

a V

GF4

8GL

Em

erge

ncy

Eng

ine

1.36

2.71

0.68

0.00

140.

0228

4.4

0.18

0.01

0.00

128

5Fu

el G

as H

eate

r0.

530.

440.

030.

0301

0.04

630.

60.

010.

010.

001

631

Lube

Oil

Tank

-0.

0017

--

--

--

Was

te L

iqui

ds T

ank

-2.

27-

-0.

21-

--

Blo

wdo

wns

-0.

05-

0.03

-30

.32

-75

8-

-0.

49-

-0.

27-

315.

64-

7,89

1T

otal

s (t

on/y

ear)

50.4

78

1.23

9.0

54

.60

12.3

39

6,5

06

.38

2.8

734

7.78

0.1

810

5,25

5

Pro

pos

ed S

ourc

es

Stat

ion

Fugi

tive

s

Mil

len

niu

m P

ipel

ine

Com

pan

y, L

LC

Hig

hla

nd

Com

pre

ssor

Sta

tion

Tab

le B

-2. S

olar

Tit

an 1

30E

Sp

ecif

icat

ion

s

Fuel

Load

50<

5050

5050

5050

5075

7575

7575

7575

100

100

100

100

100

100

100

Hp

Out

put (

Net

)11

,177

11,1

7711

,177

10,7

6810

,344

9,92

09,

220

8,34

816

,766

16,7

6616

,153

15,5

1614

,880

13,8

3012

,523

22,3

5422

,354

21,5

3720

,688

19,8

4118

,440

16,6

97

Am

bien

tTe

mpe

ratu

re (F

)be

low

00

020

4060

8010

0be

low

00

2040

6080

100

belo

w 0

020

4060

8010

0

% R

H60

6060

6060

6060

6060

6060

6060

6060

6060

6060

6060

60E

leva

tion

ft1,

320

1,32

01,

320

1,32

01,

320

1,32

01,

320

1,32

01,

320

1,32

01,

320

1,32

01,

320

1,32

01,

320

1,32

01,

320

1,32

01,

320

1,32

01,

320

1,32

0

Fuel

LH

V (B

tu/s

cf)

920.

9092

0.9

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

Hea

t Inp

u LH

V(M

MB

tu/h

r) b

yvo

lum

e12

1.15

121.

1512

1.15

117.

3411

3.57

110.

5710

6.05

101.

0914

6.65

146.

6514

0.73

135.

0613

0.03

123.

9611

7.35

167.

8316

7.83

161.

2915

4.82

148.

6014

0.18

131.

30

Hea

t Inp

ut H

HV

(MM

Btu

/hr)

(=LH

V*1

.112

5)13

4.78

134.

7813

4.78

130.

5412

6.35

123.

0111

7.98

112.

4616

3.15

163.

1515

6.56

150.

2514

4.66

137.

9113

0.55

186.

7118

6.71

179.

4417

2.24

165.

3215

5.95

146.

07

Exh

aust

lb/h

r38

6,51

738

6,51

738

6,51

736

5,30

434

4,36

732

2,32

330

0,08

727

8,59

144

3,08

444

3,08

442

2,17

440

0,83

138

0,13

335

6,19

532

8,79

745

8,60

945

8,60

944

5,90

443

2,58

141

8,87

939

6,18

436

8,08

2E

xhau

st A

CFM

213,

692

213,

692

213,

692

206,

397

198,

741

188,

347

179,

190

170,

540

248,

555

248,

555

240,

148

231,

669

223,

753

214,

221

202,

122

267,

038

267,

038

260,

872

254,

636

248,

350

238,

271

225,

480

Stac

k H

eigh

t (ft

)60

6060

6060

6060

6060

6060

6060

6060

6060

6060

6060

60

Stac

k H

eigh

t (m

)18

.29

18.2

918

.29

18.2

918

.29

18.2

918

.29

18.2

918

.29

18.2

918

.29

18.2

918

.29

18.2

918

.29

18.2

918

.29

18.2

918

.29

18.2

918

.29

18.2

9

Squa

re S

tack

Sid

e(i

nche

s)11

411

411

411

411

411

411

411

411

411

411

411

411

411

411

411

411

411

411

411

411

411

4

Squa

re S

tack

Sid

e(f

t)2.

902.

902.

902.

902.

902.

902.

902.

902.

902.

902.

902.

902.

902.

902.

902.

902.

902.

902.

902.

902.

902.

90

Squa

re S

tack

Equ

ivD

iam

eter

(ft)

10.7

210

.72

10.7

210

.72

10.7

210

.72

10.7

210

.72

10.7

210

.72

10.7

210

.72

10.7

210

.72

10.7

210

.72

10.7

210

.72

10.7

210

.72

10.7

210

.72

Squa

re S

tack

Exh

aust

(m/s

)12

.03

12.0

312

.03

11.6

211

.19

10.6

010

.09

9.60

13.9

913

.99

13.5

213

.04

12.5

912

.06

11.3

815

.03

15.0

314

.68

14.3

313

.98

13.4

112

.69

Exh

aust

M.W

.28

.55

28.5

528

.55

28.5

428

.51

28.4

728

.37

28.2

928

.55

28.5

528

.54

28.5

128

.47

28.3

728

.29

28.5

528

.55

28.5

428

.51

28.4

728

.37

28.2

9

Exh

aust

Tem

pera

ture

(F)

837

837

837

865

892

907

932

963

856

856

874

894

917

942

969

906

906

912

919

927

942

964

Exh

aust

Tem

pera

ture

(K)

720.

472

0.4

720.

473

5.9

750.

975

9.3

773.

279

0.4

730.

973

0.9

740.

975

2.0

764.

877

8.7

793.

775

8.7

758.

776

2.0

765.

977

0.4

778.

779

0.9

NO

Xpp

m@

15%

O2

120

7015

1515

1515

1512

015

1515

1515

1512

015

1515

1515

15

NO

Xlb

/hr

55.2

0032

.200

6.90

06.

680

6.46

06.

270

5.97

05.

620

68.4

808.

560

8.20

07.

860

7.54

07.

140

6.68

080

.720

10.0

909.

680

9.28

08.

870

8.31

07.

690

NO

Xg/

s6.

955

4.05

70.

869

0.84

20.

814

0.79

00.

752

0.70

88.

628

1.07

91.

033

0.99

00.

950

0.90

00.

842

10.1

711.

271

1.22

01.

169

1.11

81.

047

0.96

9

CO

ppm

@ 1

5% O

215

08,

000

2525

2525

2525

150

2525

2525

2525

150

2525

2525

2525

CO

lb/h

r42

.000

2240

.07.

000

6.78

06.

550

6.36

06.

060

5.71

052

.080

8.68

08.

330

7.98

07.

650

7.25

06.

780

61.3

8010

.230

9.83

09.

410

9.00

08.

430

7.80

0C

O g

/s5.

292

282.

240

0.88

20.

854

0.82

50.

801

0.76

40.

719

6.56

21.

094

1.05

01.

005

0.96

40.

914

0.85

47.

734

1.28

91.

239

1.18

61.

134

1.06

20.

983

UH

C p

pm@

15% O

250

800

2525

2525

2525

5025

2525

2525

2550

2525

2525

2525

UH

C lb

/hr

8.02

012

8.32

04.

010

3.88

03.

750

3.64

03.

470

3.27

09.

940

4.97

04.

770

4.57

04.

380

4.15

03.

880

11.7

205.

860

5.63

05.

390

5.16

04.

830

4.47

0

VO

C p

pm@

15%

O2

(20%

of U

HC

)10

160

55

55

55

105

55

55

510

55

55

55

VO

C lb

/hr

1.60

425

.664

0.80

20.

776

0.75

00.

728

0.69

40.

654

1.98

80.

994

0.95

40.

914

0.87

60.

830

0.77

62.

344

1.17

21.

126

1.07

81.

032

0.96

60.

894

sulfu

r gr

/100

scf

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

SO2

lb/h

r0.

753

0.75

30.

753

0.73

00.

706

0.68

80.

660

0.62

90.

912

0.91

20.

875

0.84

00.

809

0.77

10.

730

1.04

41.

044

1.00

30.

963

0.92

40.

872

0.81

7SO

2 g/

s0.

095

0.09

50.

095

0.09

20.

089

0.08

70.

083

0.07

90.

115

0.11

50.

110

0.10

60.

102

0.09

70.

092

0.13

20.

132

0.12

60.

121

0.11

60.

110

0.10

3Pa

rtic

ulat

eslb

/MM

Btu

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

PM10

/2.5

lb/h

r2.

022.

022.

021.

961.

901.

851.

771.

692.

452.

452.

352.

252.

172.

071.

962.

802.

802.

692.

582.

482.

342.

19PM

10/2

.5g/

s0.

255

0.25

50.

255

0.24

70.

239

0.23

20.

223

0.21

30.

308

0.30

80.

296

0.28

40.

273

0.26

10.

247

0.35

30.

353

0.33

90.

326

0.31

20.

295

0.27

6C

O2

lb/m

mB

tu11

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

7C

O2

lb/h

r15

,754

15,7

5415

,754

15,2

5914

,769

14,3

7813

,791

13,1

4619

,070

19,0

7018

,300

17,5

6316

,909

16,1

2015

,260

21,8

2421

,824

20,9

7420

,133

19,3

2418

,229

17,0

74C

H4

lb/m

mB

tu0.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

22C

H4

lb/h

r0.

2971

0.29

710.

2971

0.28

780.

2785

0.27

120.

2601

0.24

790.

3597

0.35

970.

3452

0.33

130.

3189

0.30

400.

2878

0.41

160.

4116

0.39

560.

3797

0.36

450.

3438

0.32

20N

2O lb

/mm

Btu

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

N2O

lb/h

r0.

0297

0.02

970.

0297

0.02

880.

0279

0.02

710.

0260

0.02

480.

0360

0.03

600.

0345

0.03

310.

0319

0.03

040.

0288

0.04

120.

0412

0.03

960.

0380

0.03

640.

0344

0.03

22C

O2e

lb/m

mB

tu11

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

0C

O2e

lb/h

r15

,771

15,7

7115

,771

15,2

7514

,784

14,3

9313

,805

13,1

5919

,090

19,0

9018

,319

17,5

8116

,926

16,1

3615

,276

21,8

4721

,847

20,9

9620

,153

19,3

4418

,248

17,0

92

Not

es1.

Dat

a pr

ovid

ed b

y So

lar

for

100%

, 75%

, and

50%

load

cas

es: n

et o

utpu

t pow

er, f

uel f

low

(MM

Btu

/hr,

LH

V),

exh

aust

flow

(lb/

hr),

exh

aust

tem

pera

ture

, NO

X/C

O/U

HC

con

cent

rati

ons

and

lb/h

r.2.

Bel

ow z

ero

and

low

load

ope

rati

on u

ses

0ºF

for

oper

atin

g pa

ram

eter

s an

d us

es c

once

ntra

tion

s fr

om S

olar

PIL

167

.3.

Gre

enho

use

gase

s ar

e ca

lcul

ated

usi

ng e

mis

sion

fact

ors

from

Par

t 98,

Tab

les

C1

and

C2

and

glob

al w

arm

ing

pote

ntia

ls fr

om T

able

A1

(CO

2=

1, C

H4

= 2

5, N

2O =

298

).

Nat

ural

Gas

Mil

len

niu

m P

ipel

ine

Com

pan

y, L

LC

Hig

hla

nd

Com

pre

ssor

Sta

tion

Tab

le B

-3. S

olar

Tit

an 1

30E

Pot

enti

al t

o E

mit

Op

erat

ion

sP

oten

tial

to

Em

it

Incl

ud

ing

Sta

rtu

p/S

hu

tdow

nd

uri

ng

Nor

mal

T

emp

erat

ure

Op

erat

ion

Max

imu

m Y

earl

y P

oten

tial

to

Em

it

Max

imu

mA

nn

ual

Com

bin

ed E

ven

t F

req

uen

cy

8,76

0 hr

s/yr

8,76

0 hr

s/yr

Pol

luta

nt

Hou

rly

(lb/

hr)

Max

imum

Ann

ual

(tpy

)

Eve

nt(l

b/ev

ent)

Max

imum

Ann

ual

(tpy

)

Eve

nt(l

b/ev

ent)

Max

imum

Ann

ual

(tpy

)

Max

imum

Ann

ual

(tpy

)H

ourl

y(l

b/hr

)M

axim

umA

nnua

l(t

py)

Hou

rly

(lb/

hr)

Max

imum

Ann

ual

(tpy

)

Max

imum

Ann

ual

(tpy

)

NO

X10

.09

44.1

91.

900.

102.

400.

1244

.24

80.7

24.

8432

.20

0.16

48.5

9

CO

10.2

344

.81

176.

908.

8520

7.60

10.3

863

.86

61.3

83.

682,

240.

0011

.20

78.0

8SO

21.

044.

570

00

04.

571.

040.

060.

750.

004

4.57

PM10

/2.5

2.80

12.2

70

00

012

.27

2.80

0.17

2.02

0.01

12.2

7C

O2e

21,8

4795

,690

00

00

95,6

9021

,847

1,31

115

,771

7995

,690

CO

221

,824

95,5

910

00

095

,591

21,8

241,

309

15,7

5479

95,5

91N

2O0.

040.

180

00

00.

180.

040.

002

0.03

0.00

010.

18TO

C (T

otal

)5.

8625

.67

10.1

00.

5111

.90

0.60

26.6

711

.72

0.70

128.

320.

6427

.63

CH

40.

411.

800

00

01.

800.

410.

020.

300.

001

1.80

VO

C (T

otal

)1.

175.

132.

020.

102.

380.

125.

332.

340.

1425

.66

0.13

5.53

Low

Loa

d O

per

atio

n (

<50

%)

10 h

rs/y

r8,

760

hrs/

yr10

0 E

vent

s/Yr

(1

0 M

inut

e E

vent

Dur

atio

n)10

0 E

vent

s/Ye

ar(1

0 M

inut

e E

vent

Dur

atio

n)12

0 hr

s/yr

Nor

mal

Am

bie

nt

Tem

per

atu

res

(>

0 d

egre

es F

)

Sta

rtu

pS

hu

tdow

nL

ow A

mbi

ent

Tem

per

atu

res

(<

0 d

egre

es F

)

Mil

len

niu

m P

ipel

ine

Com

pan

y, L

LC

Hig

hla

nd

Com

pre

ssor

Sta

tion

Tab

le B

-4.

Au

xili

ary

Gen

erat

or P

oten

tial

Em

issi

ons

Su

mm

ary

(Wau

kesh

a V

GF

48

GL

)

En

gin

e p

aram

eter

sPo

wer

out

put b

ase

load

1,23

0hp

Hea

t Inp

ut C

apac

ity

(HH

V)

9.72

6M

MB

tu/h

rM

axim

um A

nnua

l Ope

rati

on50

0hr

/yr

Pol

luta

nt

g/b

hp

-hr1

lb/M

MB

tu2

lb/h

rT

otal

An

nu

al

(ton

/yr)

3

NO

x2.

005.

421.

36C

O

4.00

10.8

52.

71V

OC

1.00

2.71

0.68

PM10

/2.5

0.00

999

0.10

0.02

4SO

25.

88E

-04

0.00

60.

0014

CO

2e11

7.10

1138

.912

284.

73C

O2

116.

9800

1137

.738

284.

43C

H4

0.00

220.

021

0.01

N2O

0.00

020.

002

0.00

1N

otes

:

2 Em

issi

ons

for

PM10

/PM

2.5

and

SO2

calc

ulat

ed u

sing

AP-

42 e

mis

sion

fact

ors

(Tab

le 3

.2-2

). E

mis

sion

for

GH

Gs

base

d up

on 4

0 C

FR P

art 9

8, S

ubpa

rt C

Pot

enti

al E

mis

sion

s

1 NO

x, C

O, V

OC

bas

ed o

n N

SPS

Subp

art J

JJJ,

Tab

le 1

3 Aux

iliar

y G

ener

ator

is L

imit

ed to

500

hou

rs /

yea

r.


Table B-5. Gas-Fired Heater Potential Emissions Summary

Engine parametersHeat Input Capacity (HHV) 1.23 MMBtu/hrFuel Firing Rate 1,201 SCF/hrMaximum Annual Operation 8,760 hr/yr

Pollutant lb/mmscf lb/hrTotal Annual

(ton/yr)

NOx 100 0.12 0.53CO 84 0.10 0.44VOC 5.5 0.007 0.03PM/PM-10/PM-2.5 7.6 0.01 0.04SO2

(2) 5.71 0.0069 0.03CO2e 119,970 144.12 631.26CO2 119,846 143.98 630.61CH4 2.26 0.0027 0.01N2O 0.23 0.00027 0.0012

(1) NOx, CO, VOC and PM emissions are based upon AP-42 Emission Factors (2) Emissions of SO2 from based on mass balance of sulfur in fuel:

Sulfur Content 2.0 grains/100 SCFHigher Heating Value 1,025 Btu/SCF

Molecular Weight of S = 32 lb/lbmolMolecular Weight of SO2 = 64 lb/lbmol

(3) GHG Emissions are based upon 40 CFR Part 98, Subpart C

Potential Emissions


Table B-6. Fugitive Blowdowns Potential Emissions Summary

Natural Gas SpecificationsConstituent Mol Percent Molecular Weight Lb/Lb-Mol NG Mass Percent VOC

CO2 0.031 44.01 0.014 0.08% NoNitrogen 0.244 28.01 0.068 0.42% NoMethane 97.794 16.04 15.689 95.90% NoEthane 1.876 30.07 0.564 3.45% No

Propane 0.053 44.10 0.023 0.14% YesN-Butane 0.002 58.12 0.001 0.01% Yes

Molecular Weight 16.35Btu/Scf 1024.5Specific Gravity 0.566lb/Scf 0.0433Scf/lb 23.10

BuildingShutdown

Emergency StationShutdown

Gas Blowdown (scf/event) 61,000 608,474Blowdowns per Year 4 2

VOC Emissions (lb/event) 4.0 39.5CO2 Emissions (lb/event) 2.2 22.0CH4 Emissions (lb/event) 2,532.1 25,257.5CO2e Emissions (lb/event) 63,304.4 631,460.0

VOC Emissions (tpy) 0.0079 0.0395CO2 Emissions (tpy) 0.0044 0.0220CH4 Emissions (tpy) 5.1 25.3CO2e Emissions (tpy) 126.6 631.5

Blowdown Events

Parameter

Natural Gas Properties


Table B-7. Waste Liquids Tank Potential Emissions Summary

Capacity (gal) 4,000 4,000Liquids Input Rate (gal/yr) 4,000 667 (gal/hr)

Flash Gas Density (lb/scf) 0.1107 0.1107

Flash Factor (scf/bbl) 640.3 629.71Flash Gas Rate (scf/yr) 60,980.95 10,000.39 (scf/hr)Flash Losses (lb/yr) 6,750.59 Maximum 1,107.04 MaximumIndividual Constituents Weight

Percentage (%)Annual

Emissions(tpy)

WeightPercentage (%)

HourlyEmissions

(lb/hr)VOC (Total) 67.38 2.274 67.38 745.93HAP (Total) 6.17 0.208 6.17 68.30Benzene 0.7598 0.026 0.7598 8.41Ethylbenzene 0.047 0.002 0.047 0.52Hexane (n ) 1.6563 0.056 1.6563 18.34Toluene 2.4744 0.084 2.4744 27.39Trimethylpentane (2,2,4 )

0.2072 0.007 0.2072 2.29Xylenes 1.0253 0.035 1.0253 11.35Notes:Liquid input rates:a. maximum hourly based on the minimum of vessel capacity or maximum annual throughput divided by 6;b. maximum annual based on operating experience and safety factor; andc. average hourly is the maximum annual divided by 8,760 hrs/yr.

Flash gas density is 110% of the value extracted from laboratory analysis results.Laboratory Density:Flash factor extracted from laboratory analysis results:0.1006 lb/scf Safety Factor: 110%Speciated emissions vapor weight percentages caculated from laboratory analysis results.


Table B-8. Potential Fugitive Emissions Summary

CH4 Emission Factor¹,²

CO2 Emission Factor¹,²

Compressor Station Fugitives 135,260.0 7,813.1Centrifugal Compressor Fugitives 467,660.0 27,013.7

2Based on 93.4 vol% CH4 and 2 vol% CO2 in natural gas, per INGAA Guideline




Segment CO Emissions3

(tpy) CH4

Emissions3

(tpy)

CO eEmissions3,4

(tpy)

VOCEmissions3

(tpy)

Compressor Station Fugitives 0.06 70.8 1,770.4 0.1Titan 130E Fugitives 0.2 244.8 6,121.0 0.4Total 0.3 315.6 7,891.3 0.5

3Based upon natural gas specfications and INGAA factors above.4Calculated using global warming potentials from Part 98, Table A 1 (CO2 = 1, CH4 = 25)

1Greenhouse Gas Emission Estimation Guidelines for Natural Gas Transmission and Storage, Volume 1 - GHG Emission Estimation Methodologies and Procedures, Interstate Natural Gas Association of America, September 28, 2005. See Table 4.4.

Component Units

lb/station-yrlb/compressor-yr

Mil

len

niu

m P

ipel

ine

Com

pan

y, L

LC

Hig

hla

nd

Com

pre

ssor

Sta

tion

Tab

le B

-9.

Pro

pos

ed P

roje

ct P

oten

tial

HA

P E

mis

sion

s S

um

mar

y

Em

issi

on F

acto

rM

ax H

ourl

yA

nn

ual

Pot

enti

alE

mis

sion

Fac

tor

Max

An

nu

alP

oten

tial

EF

Max

An

nu

alP

oten

tial

Fac

ilit

yB

asis

(1)

Bas

is(2

)H

ourl

yB

asis

(3)

Hou

rly

PT

E

Haz

ard

ous

Air

Pol

luta

nts

(H

AP

s)lb

/MM

Btu

lb/h

rto

ns/

year

lb/M

MB

tulb

/hr

ton

s/ye

arlb

/MM

Btu

lb/h

rto

ns/

year

ton

s/yr

Ace

tald

ehyd

e1.

18E

-04

2.20

E-0

29.

66E

-02

8.36

E-0

38.

13E

-02

2.03

E-0

21.

17E

-01

Acr

olei

n1.

89E

-05

3.53

E-0

31.

55E

-02

5.14

E-0

35.

00E

-02

1.25

E-0

22.

80E

-02

Ben

zene

3.54

E-0

56.

61E

-03

2.90

E-0

22.

06E

-06

2.53

E-0

61.

11E

-05

4.40

E-0

44.

28E

-03

1.07

E-0

33.

01E

-02

1,3-

But

adie

ne1.

27E

-06

2.37

E-0

41.

04E

-03

2.67

E-0

42.

60E

-03

6.49

E-0

41.

69E

-03

Car

bon

Tetr

achl

orid

e0.

00E

+00

0.00

E+

003.

67E

-05

3.57

E-0

48.

92E

-05

8.92

E-0

5C

hlor

oben

zene

0.00

E+

000.

00E

+00

3.04

E-0

52.

96E

-04

7.39

E-0

57.

39E

-05

Chl

orof

orm

0.00

E+

000.

00E

+00

2.85

E-0

52.

77E

-04

6.93

E-0

56.

93E

-05

Dic

hlor

oben

zene

0.00

E+

000.

00E

+00

1.18

E-0

61.

45E

-06

6.34

E-0

66.

34E

-06

1,3-

Dic

hlor

opro

pene

0.00

E+

000.

00E

+00

2.64

E-0

52.

57E

-04

6.42

E-0

56.

42E

-05

Eth

ylbe

nzen

e9.

45E

-05

1.76

E-0

27.

73E

-02

3.97

E-0

53.

86E

-04

9.65

E-0

57.

74E

-02

Eth

ylen

e D

ibro

mid

e0.

00E

+00

0.00

E+

004.

43E

-05

4.31

E-0

41.

08E

-04

1.08

E-0

4Fo

rmal

dehy

de

2.10

E-0

33.

91E

-01

1.71

E+

007.

35E

-05

9.05

E-0

53.

96E

-04

5.28

E-0

25.

14E

-01

1.28

E-0

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E

PREDICTED EMISSION PERFORMANCE

Customer

Millenium Pipeline Job ID

Highland

Inquiry Number

HO15-0146

Run By Date Run

Nima Bahrami 14-Apr-16

Engine Model

TITAN 130-22402S

CS/MD 59F MATCH

Fuel Type Water Injection

CHOICE GAS NO

Engine Emissions Data

REV. 0.0

NOx EMISSIONS CO EMISSIONS UHC EMISSIONS

1 11177 HP 50.0% Load Elev. 1320 ft Rel. Humidity 60.0% Temperature 0 Deg. F

15.00 25.00 25.00 PPMvd at 15% O2

30.24 30.68 17.57 ton/yr

0.060 0.061 0.035 lbm/MMBtu (Fuel LHV)

0.83 0.84 0.48 lbm/(MW-hr)

(gas turbine shaft pwr) 6.90 7.00 4.01 lbm/hr

2 10768 HP 50.0% Load Elev. 1320 ft Rel. Humidity 60.0% Temperature 20.0 Deg. F

15.00 25.00 25.00 PPMvd at 15% O2

29.27 29.70 17.01 ton/yr


0.83 0.84 0.48 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

28.28 28.70 16.44 ton/yr


0.84 0.85 0.49 lbm/(MW-hr)


Notes

1. For short-term emission limits such as lbs/hr., Solar recommends using "worst case" anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant is not necessarily the same for another.

2. Solar’s typical SoLoNOx warranty, for ppm values, is available for greater than 0 deg F or -20 deg C, and between 50% and 100% load for gas, fuel, and between 65% and 100% load for liquid fuel (except f or the Centaur 40). An emission warranty for non-SoLoNOx equipment is available for greater than 0 deg F or -20 deg C and betwee

3. Fuel must meet Solar standard fuel specification ES 9-98. Emissions are based on the attached fuel composition, or, San Diego natural gas or equivalent.

4. If needed, Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges, as well as non-warranted emissions of SO2, PM10/2.5, VOC, and formaldehyde.

5. Solar can provide factory testing in San Diego to ensure the actual unit(s) meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request.

6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up, shut-down, malfunction, or transient event.


Customer


Highland

Inquiry Number

HO15-0146

Run By Date Run


Engine Model

TITAN 130-22402S

CS/MD 59F MATCH


CHOICE GAS NO


REV. 0.0



15.00 25.00 25.00 PPMvd at 15% O2

27.45 27.85 15.95 ton/yr


0.85 0.86 0.49 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

26.16 26.54 15.20 ton/yr


0.87 0.88 0.50 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

24.64 25.00 14.32 ton/yr


0.90 0.92 0.53 lbm/(MW-hr)


Notes







PREDICTED ENGINE PERFORMANCE

Customer


Highland

Run By Date Run


Engine Performance Code Engine Performance Data

REV. 4.17.1.19.11 REV. 0.0

Model

TITAN 130-22402S Package Type

CS/MD Match

59F MATCH Fuel System

GAS Fuel Type

CHOICE GAS

DATA FOR MINIMUM PERFORMANCE

Elevation feet 1320

Inlet Loss in H2O 4.0

Exhaust Loss in H2O 4.0

Accessory on GP Shaft HP 29.2

1 2 3 4 5 6

Engine Inlet Temperature deg F 0 20.0 40.0 60.0 80.0 100.0

Relative Humidity % 60.0 60.0 60.0 60.0 60.0 60.0

Driven Equipment Speed RPM 7139 7024 6916 7187 7065 6932

Specified Load HP 50.0% 50.0% 50.0% 50.0% 50.0% 50.0%

Net Output Power HP 11177 10768 10344 9920 9220 8348

Fuel Flow mmBtu/hr 121.15 117.34 113.57 110.57 106.05 101.09

Heat Rate Btu/HP-hr 10839 10897 10979 11146 11503 12109

Therm Eff % 23.475 23.350 23.175 22.827 22.120 21.013

Engine Exhaust Flow lbm/hr 386517 365304 344367 322323 300087 278591

PT Exit Temperature deg F 889 907 925 929 949 981

Exhaust Temperature deg F 837 865 892 907 932 963

Fuel Gas Composition (Volume Percent)

Methane (CH4) 97.79

Ethane (C2H6) 1.88

Propane (C3H8) 0.05

N-Butane (C4H10) 0.0020

Carbon Dioxide (CO2) 0.03

Nitrogen (N2) 0.24

Sulfur Dioxide (SO2) 0.0001

Fuel Gas Properties LHV (Btu/Scf) 920.9 Specific Gravity 0.5648 Wobbe Index at 60F 1225.4

This performance was calculated with a basic inlet and exhaust system. Special equipment such as low noise silencers, special filters, heat recovery systems or cooling devices will affect engine performance. Performance shown is "Expected" performance at the pressure drops stated, not guaranteed.


Customer


Highland

Inquiry Number

HO15-0146

Run By Date Run


Engine Model

TITAN 130-22402S

CS/MD 59F MATCH


CHOICE GAS NO


REV. 0.0



15.00 25.00 25.00 PPMvd at 15% O2

37.48 38.03 21.78 ton/yr


0.68 0.69 0.40 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

35.94 36.47 20.89 ton/yr


0.68 0.69 0.40 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

34.43 34.94 20.01 ton/yr


0.68 0.69 0.39 lbm/(MW-hr)


Notes








Customer


Highland

Inquiry Number

HO15-0146

Run By Date Run


Engine Model

TITAN 130-22402S

CS/MD 59F MATCH


CHOICE GAS NO


REV. 0.0



15.00 25.00 25.00 PPMvd at 15% O2

33.03 33.52 19.20 ton/yr


0.68 0.69 0.40 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

31.28 31.74 18.18 ton/yr


0.69 0.70 0.40 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

29.26 29.69 17.01 ton/yr


0.72 0.73 0.42 lbm/(MW-hr)


Notes








Customer


Highland

Run By Date Run



REV. 4.17.1.19.11 REV. 0.0

Model


CS/MD Match


GAS Fuel Type

CHOICE GAS


Elevation feet 1320




1 2 3 4 5 6








Therm Eff % 29.089 29.204 29.231 29.117 28.387 27.153





Methane (CH4) 97.79

Ethane (C2H6) 1.88

Propane (C3H8) 0.05

N-Butane (C4H10) 0.0020


Nitrogen (N2) 0.24





Customer


Highland

Inquiry Number

HO15-0146

Run By Date Run


Engine Model

TITAN 130-22402S

CS/MD 59F MATCH


CHOICE GAS NO


REV. 0.0



15.00 25.00 25.00 PPMvd at 15% O2

44.18 44.83 25.67 ton/yr


0.61 0.61 0.35 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

42.42 43.04 24.65 ton/yr


0.60 0.61 0.35 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

40.64 41.23 23.62 ton/yr


0.60 0.61 0.35 lbm/(MW-hr)


Notes








Customer


Highland

Inquiry Number

HO15-0146

Run By Date Run


Engine Model

TITAN 130-22402S

CS/MD 59F MATCH


CHOICE GAS NO


REV. 0.0



15.00 25.00 25.00 PPMvd at 15% O2

38.86 39.43 22.58 ton/yr


0.60 0.61 0.35 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

36.41 36.94 21.16 ton/yr


0.60 0.61 0.35 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

33.69 34.18 19.58 ton/yr


0.62 0.63 0.36 lbm/(MW-hr)


Notes








Customer


Highland

Run By Date Run



REV. 4.17.1.19.11 REV. 0.0

Model


CS/MD Match


GAS Fuel Type

CHOICE GAS


Elevation feet 1320




1 2 3 4 5 6




Specified Load HP FULL FULL FULL FULL FULL FULL




Therm Eff % 33.890 33.974 34.001 33.973 33.470 32.358





Methane (CH4) 97.79

Ethane (C2H6) 1.88

Propane (C3H8) 0.05

N-Butane (C4H10) 0.0020


Nitrogen (N2) 0.24




Solar Turbines Incorporated Product Information Letter 167

SoLoNOx Products:Emissions in Non-SoLoNOx Modes

Leslie WitherspoonSolar Turbines Incorporated

PURPOSESolar’s gas turbine dry low NOx emissions combustion systems, known as SoLoNOx™,have been developed to provide the lowest emissions possible during normal operating conditions. In order to optimize the performance of the turbine, the combustion and fuel systems are designed to reduce NOx, CO and unburned hydrocarbons (UHC) without penalizing stability or transient capabilities. At very low load and cold temperature extremes, the SoLoNOx system must be controlled differently in order to assure stable operation. The required adjustments to the turbine controls at these conditions cause emissions to increase.

The purpose of this Product Information Letter is to provide emissions estimates, and in some cases warrantable emissions for NOx, CO and UHC, at off-design conditions.

Historically, regulatory agencies have not required a specific emissions level to be met at low load or cold ambient operating conditions, but have asked what emissions levels are expected. The expected values are necessary to appropriately estimate emissions for annual emissions inventory purposes and for New Source Review applicability determinations, air dispersion modeling, and permitting.

COLD AMBIENT EMISSIONS ESTIMATESSolar’s standard temperature range warranty for gas turbines with SoLoNOx combustion is

0°F (–20°C). The Titan™ 250 is an exception, with a lower standard warranty at–20°F (–29°C). At ambient temperatures below 0°F, many of Solar’s turbine engine

models are controlled to increase pilot fuel which improves flame stability but leads to higher emissions. Without the increase in pilot fuel at temperatures below 0°F the engines may exhibit combustor rumble, as operation may be near the lean stability limit.

If a cold ambient emissions warranty is requested, a new production turbine configured with the latest combustion hardware is required. For most models this refers to the inclusion of “Cold Ambient Fuel Control Logic”. A cold ambient emissions warranty is only available on gas turbines being fired on natural gas and not offered for ambient temperatures below –20°F (–29°C). In general, standard natural gas as defined in ES9-98 is required to offer a cold ambient warranty, but non-standard fuels on a project basis can be reviewed by Solar to determine applicability. In addition, cold ambient emissions warranties cannot be offered for the Centaur® 40 turbine. Note that a cold ambient warranty cannot be offered for liquid fuel operation at this time.

Table 1 provides expected and warrantable (upon Solar’s documented approval) emissionslevels for Solar’s SoLoNOx combustion turbines. All emissions levels are in ppm at 15% O2. Refer to Product Information Letter 205 for Mercury™ 50 turbine emissions estimates.

For information on the availability and approvals for cold ambient temperature emissions warranties, please contact Solar’s sales representatives.

Product Information LetterPIL 167

PIL 167 Revision 5 31 March 2015

© 2015 Solar Turbines Incorporated

Caterpillar Confidential Green: Information contained herein is to be treated as Confidential and Proprietary to Caterpillar.

1


Table 1. Warrantable Emissions Between 0°F and –20°F (–20° to –29°C) for New Production (NOx ppm values corrected to 15% O2.)

Turbine Model

Fuel System FuelApplicable

LoadNOx, ppm

CO, ppm

UHC, ppm

Centaur 50Gas Only Gas 50 to 100% load 42 100 50

Dual Fuel Gas 50 to 100% load 72 100 50

Taurus™ 60 Gas Only or Dual Fuel Gas 50 to 100% load 42 100 50

Taurus 65 Gas Only Gas 50 to 100% load 42 100 50

Taurus 70 Gas Only or Dual Fuel Gas 50 to 100% load 42 100 50

Mars® 90 Gas Only Gas 50 to 100% load 42 100 50

Mars 100 Gas Only or Dual Fuel Gas 50 to 100% load 42 100 50

Titan 130 Gas Only or Dual Fuel Gas 50 to 100% load 42 100 50

Titan 250Gas Only Gas 40 to 100% load 25 50 25

Gas Only Gas 40 to 100% load 15 25 25

Table 2 summarizes “expected” emissions levels for ambient temperatures below 0°F (–20°C) for Solar’s SoLoNOx turbines that do not have current production hardware or for new production hardware that is not equipped with the Cold Ambient Fuel Control Logic.The emissions levels are extrapolated from San Diego factory tests and may vary at extreme temperatures and as a result of variations in other parameters, such as fuel composition, fuel quality, etc.

For more conservative NOx emissions estimate on new equipment, customers can refer to the New Source Performance Standard (NSPS) 40CFR60, subpart KKKK, where the allowable NOx emissions level for ambient temperatures < 0°F (–20°C) is 150 ppm NOx at 15% O2. For pre-February 18, 2005, SoLoNOx combustion turbines subject to 40CFR60 subpart GG, a conservative estimate is the appropriate subpart GG emissions level. Subpart GG levels range from 150 to 214 ppm NOx at 15% O2 on natural gas (and 150-210 on liquid fuel) depending on the turbine model.

Table 2. Expected Emissions below 0°F (–20°C) for SoLoNOx Combustion Turbines (NOx ppm values corrected to 15% O2.)

Turbine Model


LoadNOx, ppm

CO, ppm

UHC, ppm

Centaur 40 Gas Only or Dual Fuel Gas 80 to 100% load 120 150 50






Mars 90 Gas Only Gas 80 to 100% load 120 150 50



Centaur 40 Dual Fuel Liquid 80 to 100% load 150 150 75


Taurus 60 Dual Fuel Liquid 65 to 100% load 150 150 75


Mars 100 Dual Fuel Liquid 65 to 100% load 150 150 75

Titan 130 Dual Fuel Liquid 65 to 100% load 150 150 75




2


Table 3 summarizes “expected” emissions levels for ambient temperatures below –20°F (–29°C) for the Titan 250.

Table 3. Expected Emissions below –20°F (–29°C) for the Titan 250 SoLoNOx Combustion Turbine (NOx ppm values corrected to 15% O2.)

Turbine Model


LoadNOx, ppm

CO, ppm

UHC, ppm

Titan 250 Gas Only Gas 40 to 100% load 70 150 50

COLD AMBIENT PERMITTING STRATEGYThere are several permitting options to consider when permitting in cold ambient climates. Customers can use a tiered permitting approach or choose to permit a single emission rate over all temperatures. Some customers have used a tiered permitting strategy. For purposes of compliance and annual emissions inventories, a digital thermometer is installed to record ambient temperature. The amount of time is recorded

that the ambient temperature falls below 0 F. The amount of time below 0°F is then used with the emissions estimates shown in Tables 1 and 2 to estimate “actual” emissions during sub-zero operation.

A conservative alternative to using the NOx values in Tables 1, 2 and 3 is to reference 40CFR60 subpart KKKK, which allows 150 ppm NOx at 15% O2 for sub-zero operation.

For customers who wish to permit at a single emission rate over all ambient temperatures, inlet air heating can be used to raise the engine inlet air temperature (T1)above 0°F. With inlet air heating to keep T1 above 0°F, standard emission warranty levels may be offered.

Inlet air heating technology options include an electric resistance heater, an inlet air to exhaust heat exchanger and a glycol heat exchanger.

If an emissions warranty is desired, and ambient temperatures are commonly below –20°F (–29°C), inlet air heating can be used to raise the turbine inlet temperature (T1) to at least –20°F. In such cases, the values shown in Table 1 can be warranted for new production natural gas fired turbine.

EMISSIONS ESTIMATES IN NON-SOLONOX MODE (LOW LOAD)At operating loads < 50% (<40% load for the Titan 250) on natural gas fuel and < 65%(< 80% load for Centaur 40) on liquid fuels, SoLoNOx engines are controlled to increase stability and transient response capability. The control steps that are required affect emissions in two ways: 1) pilot fuel flow is increased, increasing NOx emissions, and 2) airflow through the combustor is increased, increasing CO emissions. Note that the load levels are approximate. Engine controls are triggered either by power output for single-shaft engines or gas producer speed for two-shaft engines.

A conservative method for estimating emissions of NOx at low loads is to use the applicable NSPS: 40CFR60 subpart GG or KKKK. For projects that commence construction after February 18, 2005, subpart KKKK is the applicable NSPS and contains a NOx level of 150 ppm @ 15% O2 for operating loads less than 75%.

Table 4 provides estimates of NOx, CO, and UHC emissions when operating in non-SoLoNOx mode for natural gas or liquid fuel. The estimated emissions can be assumed to vary linearly as load is decreased from just below 50% load for natural gas (or 65% load for liquid fuel) to idle.




3


The estimates in Table 4 apply for any product for gas only or dual fuel systems using pipeline quality natural gas. Refer to Product Information Letter 205 for Mercury 50 emissions estimates.

Table 4. Estimated Emissions in non-SoLoNOx Mode(NOx ppm values corrected to 15% O2.)

Ambient Fuel System Engine Load NOx, ppm CO, ppm UHC, ppm

Centaur 40/50, Taurus 60/65/70, Mars 90/100, Titan 130

–20°F (–29°C) Natural GasLess than 50% 70 8,000 800

Idle 50 10,000 1,000

< –20°F (–29°C) Natural GasLess than 50% 120 8,000 800

Idle 120 10,000 1,000

Titan 250

–20°F (–29°C) Natural GasLess than 40% 50 25 20

Idle 50 2,000 200

< –20°F (–29°C) Natural GasLess than 40% 70 150 50

Idle 70 2,000 200

Centaur 50, Taurus 60/70, Mars 100, Titan 130

–20°F (–29°C) LiquidLess than 65% 150 1,000 100

Idle 150 10,000 3,000

< –20°F (–29°C) LiquidLess than 65% 150 1,000 150

Idle 150 10,000 3,000

Centaur 40


Idle 150 10,000 3,000


Idle 150 10,000 3,000

Solar Turbines Incorporated9330 Sky Park CourtSan Diego, CA 92123-5398

Caterpillar is a registered trademark of Caterpillar Inc. Solar, Centaur, Taurus, Mars, Titan and SoLoNOx are trademarks of Solar Turbines Incorporated. All other trademarks are the intellectual property of their respective companies. Specifications are subject to change without notice.

© 2015 Solar Turbines Incorporated. All rights reserved. Specifications are subject to change without notice.




4

PIL 168, Revision 5 8 July 2015Caterpillar: Confidential Green© 2015 Solar Turbines Incorporated Caterpillar Confidential Green: Information contained herein is to be treated as Confidential and Proprietary to Caterpillar.

1

Volatile Organic Compound, Sulfur Dioxide,and Formaldehyde Emission Estimates


PURPOSEThis Product Information Letter summarizes methods that are available to estimate emissions of volatile organic compounds (VOC), sulfur dioxide (SO2), and formaldehyde from gas turbines. Emissions esti-mates of these pollutants are often necessary during the air permitting process.

INTRODUCTIONIn absence of site-specific or representative source test data, Solar refers customers to a United States Environmental Protection Agency (EPA) document titled “AP-42” or other appropriate EPA reference documents. AP-42 is a collection of emission factors for different emission sources. The emission factors found in AP-42 provide a generally accepted way of estimating emissions when more representative data are not available. The most recent version of AP-42 (dated April 2000) can be found at:

http://www.epa.gov/ttn/chief/ap42/ch03/index.html

Solar does not typically warranty the emission rates for VOC, SO2 or formaldehyde.

Volatile Organic CompoundsMany permitting agencies require gas turbine users to estimate emissions of VOC, a subpart of the un-burned hydrocarbon (UHC) emissions, during the air permitting process. Volatile organic compounds, non-methane hydrocarbons (NMHC), and reactive organic gases (ROG) are some of the many ways of referring to the non-methane (and non-ethane) portion of an “unburned hydrocarbon” emission estimate.

For natural gas fuel, Solar’s customers use 10-20% of the UHC emission rate to represent VOC emis-sions. The estimate of 10-20% is based on a ratio of total non-methane hydrocarbons to total organic compounds. The use of 10-20% provides a conservative estimate of VOC emissions. The balance of the UHC is assumed to be primarily methane.

For liquid fuel, it is appropriate to estimate that 100% of the UHC emission estimate is VOC.

Sulfur DioxideSulfur dioxide emissions are produced by conversion of sulfur in the fuel to SO2. Since Solar does not control the amount of sulfur in the fuel, we are unable to predict SO2 emissions without a site fuel compo-sition analysis. Customers generally estimate SO2 emissions with a mass balance calculation by assum-ing that any sulfur in the fuel will convert to SO2. For reference, the typical mass balance equation is shown below.

SulfurMWSOMW

hrfuelMMBtu

MMBtuBtu10

Btufuellb

100Sulfurwt%

hrSOlb 2

62

Variables: wt % of sulfur in fuelBtu/lb fuel (LHV)MMBtu/hr fuel flow (LHV)

PIL 168Product Information Letter



2

As an alternative to the mass balance calculation, EPA’s AP-42 document can be used. AP-42 (Table 3.1-2a, April 2000) suggests emission factors of 0.0034 lb/MMBtu for gas fuel (HHV) and 0.033 lb/MMBtu for liquid fuel (HHV).

FormaldehydeIn gas turbines, formaldehyde emissions are a result of incomplete combustion. Formaldehyde in the ex-haust stream is unstable and very difficult to measure. In addition to turbine characteristics including combustor design, size, maintenance history, and load profile, the formaldehyde emission level is also affected by:

Ambient temperature

Humidity

Atmospheric pressure

Fuel quality

Formaldehyde concentration in the ambient air

Test method measurement variability

Operational factors

The emission factor data in Table 1 is an excerpt from an EPA memo: “Revised HAP Emission Factors for Stationary Combustion Turbines, 8/22/03.” The memo presents hazardous air pollutant (HAP) emission factor data in several categories including: mean, median, maximum, and minimum. The emission fac-tors in the memo are a compilation of the HAP data EPA collected during the Maximum Achievable Con-trol Technology (MACT) standard development process. The emission factor documentation shows there is a high degree of variability in formaldehyde emissions from gas turbines, depending on the manufac-turer, rating size of equipment, combustor design, and testing events. To estimate formaldehyde emis-sions from gas turbines, users should use the emission factor(s) that best represent the gas turbines ac-tual / planned operating profile. Refer to EPA’s memo for alternative emission factors.

Table 1. EPA’s Total HAP and Formaldehyde Emission Factors for <50 MW Lean-Premix Gas Turbines burning Natural Gas

(Source: Revised HAP Emission Factors for Stationary Combustion Turbines, OAR-2002-0060, IV-B-09, 8/22/03)

PollutantEngine Load

95% Upper Confidence of Mean, lb/MMBtu HHV

95% Upper Confidence of Data, lb/MMBtu HHV

Memo Reference

Total HAP > 90% 0.00144 0.00258 Table 19

Total HAP All 0.00160 0.00305 Table 16

Formaldehyde > 90% 0.00127 0.00241 Table 19

Formaldehyde All 0.00143 0.00288 Table 16


Cat and Caterpillar are registered trademarks of Caterpillar Inc. Solar, Saturn, Centaur, Taurus, Mercury, Mars, Titan, SoLoNOx, Turbotronic, InSight System, and InSight Connect, are trademarks of Solar Turbines Incorporated. All other trademarks are the intel-lectual property of their respective companies.© 2015 Solar Turbines Incorporated. All rights reserved. Specifications are subject to change without notice.


PIL 170 Revision 6 1 19 August 2015



Emission Estimates at Start-up, Shutdown, andCommissioning for SoLoNOx Combustion

ProductsLeslie Witherspoon

Solar Turbines Incorporated

PURPOSEThe purpose of this Product Information Letter (PIL) is to provide emission estimates for start-up and shutdown events for Solar® gas turbines with SoLoNOx™ dry low emissions combustion systems. The commissioning process is also discussed.

INTRODUCTIONThe information presented in this document is representative for both generator set (GS) and compressor set/mechanical drive (CS/MD) combustion turbine applications. Operation of duct burners and/or any add-on control equipment is not accounted for in the emissions estimates. Emissions related to the start-up, shutdown, and commissioning of combustion turbines will not be guaranteed or warranted.

Combustion turbine start-up occurs in one of three modes: cold, warm, or hot. On large, utility size, combustion turbines, the start-up time varies by the “mode”. The start-upduration for a hot, warm, or cold Solar turbine is less than 10 minutes in simple-cycle and most combined heat and power applications.

Heat recovery steam generator (HRSG) steam pressure is usually 250 psig or less. At 250 psig or less, thermal stress within the HRSG is minimized and, therefore, firing ramp-up is not limited. However, some combined heat and power plant applications will desire or dictate longer start-up times, therefore emissions assuming a 60-minute start are also estimated.

A typical shutdown for a Solar turbine is <10 minutes. Emissions estimates for an elongated shutdown, 30-minutes, are also included.

Start-up and shutdown emissions estimates for the Mercury™ 50 engine are found in PIL 205.

For start-up and shutdown emissions estimates for conventional combustion turbines, landfill gas, digester gas, or other alternative fuel applications, contact Solar’s Environmental Programs Department.

START-UP SEQUENCEThe start-up sequence, or getting to SoLoNOx combustion mode, takes three steps:

1. Purge-crank

2. Ignition and acceleration to idle

3. Loading / thermal stabilization

During the “purge-crank” step, rotation of the turbine shaft is accomplished with a starter motor to remove any residual fuel gas in the engine flow path and exhaust. During






“ignition and acceleration to idle,” fuel is introduced into the combustor and ignited in a diffusion flame mode and the engine rotor is accelerated to idle speed.

The third step consists of applying up to 50% load1 while allowing the combustion flame to transition and stabilize. Once 50% load is achieved, the turbine transitions to SoLoNOxcombustion mode and the engine control system begins to hold the combustion primary zone temperature and limit pilot fuel to achieve the targeted nitrogen oxides (NOx), carbon monoxide (CO), and unburned hydrocarbons (UHC) emission levels.

Steps 2 and 3 are short-term transient conditions making up less than 10 minutes.

SHUTDOWN PROCESSNormal, planned cool down/shutdown duration varies by engine model. The Centaur® 40, Centaur 50, Taurus™ 60, and Taurus 65 engines take about 5 minutes. The Taurus 70, Mars® 90 and Mars 100, Titan™ 130 and Titan 250 engines take about 10 minutes. Typically, once the shutdown process starts, the emissions will remain in SoLoNOx mode for approximately 90 seconds and move into a transitional mode for the balance of the estimated shutdown time (assuming the unit was operating at full-load).

START-UP AND SHUTDOWN EMISSIONS ESTIMATESTables 1 through 5 summarize the estimated pounds of emissions per start-up and shutdown event for each product. Emissions estimates are presented for both GS and CS/MD applications on both natural gas and liquid fuel (diesel #2). The emissions estimates are calculated using empirical exhaust characteristics.

COMMISSIONING EMISSIONSCommissioning generally takes place over a two-week period. Static testing, where no combustion occurs, usually requires one week and no emissions are expected. Dynamic testing, where combustion will occur, will see the engine start and shutdown a number of times and a variety of loads will be placed on the system. It is impossible to predict how long the turbine will run and in what combustion / emissions mode it will be running. The dynamic testing period is generally followed by one to two days of “tune-up” during which the turbine is running at various loads, most likely within low emissions mode (warranted emissions range).


Caterpillar is a registered trademark of Caterpillar Inc.Solar, Titan, Mars, Taurus, Mercury, Centaur, Saturn, SoLoNOx, and Turbotronic are trademarks of Solar Turbines Incorporated. All other trademarks are the intellectual property of their respective companies. Specifications are subject to change without notice.

1 40% load for the Titan 250 engine on natural gas. 65% load for all engines on liquid fuel (except 80% load for the Centaur 40).

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Emis

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Gen

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Nat

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Gas

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Data

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un

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Assum

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Estim

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Sta

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Emis

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s (lb

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for S

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Gen

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n.

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Tabl

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Estim

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Sta

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Emis

sion

s (lb

s/ev

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for S

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CS/

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App

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10 M

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Shut

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Data

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Ce

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40 4

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Ce

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CO

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Ox

CO

UH

CC

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NO

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OU

HC

CO

2

(lb

s)(l

bs)

(lb

s)(l

bs)

(lb

s)(l

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(lb

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(lb

s)(l

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(lb

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To

tal

Em

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s p

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Sta

rt (

lbs)

0.7

64.4

3.7

392

0.8

69.1

4.0

469

0.7

64.3

3.7

410

To

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Em

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s p

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Sh

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lbs)

0.3

30.2

1.7

181

0.4

35.4

2.0

217

0.4

33.0

1.9

204

Ta

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s 70 1

0802S

Ma

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Ma

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CC

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(lb

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(lb

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(lb

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(lb

s)(l

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(lb

s)(l

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(lb

s)(l

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(lb

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(lb

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(lb

s)(l

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(lb

s)(l

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To

tal

Em

issi

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s p

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Sta

rt (

lbs)

0.9

83.6

4.8

582

1.2

109.3

6.2

805

1.4

123.5

7.1

829

1.9

176.9

10.1

1,1

61

2.6

26.2

1.7

1,7

94

To

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Em

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s p

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Sh

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lbs)

1.3

108.2

6.2

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1.5

132.6

7.6

817

1.7

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8.5

920

2.4

207.6

11.9

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2.9

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1.4

1,9

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Estim

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Emis

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Tabl

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Estim

atio

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Sta

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Emis

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s (lb

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for S

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Gen

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Assum

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59

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Assum

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CYL #1000

GAS ANALYSIS REPORT NO.: DATE:

FOR: SAMPLE IDENTIFICATION:

COMPANY:

FIELD:

LEASE:

STA #:

REMARKS:

CARBON DIOXIDE

NITROGEN

METHANE

ETHANE

PROPANE

ISO-BUTANE

N-BUTANE

ISO-PENTANE

N-PENTANE

TOTAL

MOL WEIGHT:

BTU/LB: ISO-PENTANE + GPM:

PROPANE + GPM:

ETHANE + GPM:

BTU/CUFT. (REAL) 60 DEG.F. - PSIA: 14.650 14.696 15.025

DRY:

SAT:

( N2)

(CO2)

( C1)

( C2)

( C3)

(IC4)

(NC4)

(IC5)

(NC5)

46-082715-42 (381316)

COLUMBIA PIPELINE GROUP

LORI MARTIN SHAFFER

1700 MACCORKLE AVE SE

CHARLESTON WV 25314


N/P

MINISINK C.S.

CS-7C4175

0.031

0.244

97.794

1.876

0.053

0.000

0.002

0.000

0.000

100.000

16.35

23715.3

0.518

0.016

0.000

1021.3 1024.5 1026.9 1047.4

1003.4 1006.6 1009.0 1029.6

0.502

0.015

0.000

0.001

0.000

0.000

ATTN:

08/27/15

HEXANES PLUS (C6+) 0.000 0.000

14.730

SAMPLE TYPE: BY REQUEST FROM:08/20/15 TO:08/20/15

SAMPLE DATA: DATE:

PSIG:

BY:

TEMP: DEG.F. LBS H20DP:

08/20/15

700

JOE LASTATZA

N/P N/P

HYDROCARBON ANALYSIS - METHOD GPA 2261-13

COMPONENT NAME MOL PERCENT GPM @ 14.730 PSIA

COMPRESSIBILITY FACTOR:

SPECIFIC GRAVITY @ 60 DEG. F. (AIR = 1):

0.9979

0.566

LAB ANALYST:MP

2129 WEST WILLOW SCOTT LA 70583 337-232-3568

This document shall not be reproduced, except in full, without the written approval of Element Materials Technology.

REVIEWED BY:

DATE:

SAMPLE IDENTIFICATION

COMPANY:FIELD:LEASE:STA #:

SAMPLE DATE:

08/27/15

COLUMBIA PIPELINE GROUPN/PMINISINK C.S.CS-7C4175

08/20/15(381316)

CAPILLARY ANALYSIS - METHOD GPA 2286-95

COMPONENTMOL

PERCENTWT.

PERCENT

COMPONENTS AS % OF TOTAL SAMPLE

0.0000 0.0000METHANE

0.0000 0.0000ETHANE

0.0000 0.0000PROPANE

0.0000 0.0000ISO-BUTANE

0.0000 0.0000N-BUTANE

0.0000 0.00002,2-DIMETHYLPROPANE (NEOPENTANE)

0.0000 0.0000ISOPENTANE

0.0000 0.0000N-PENTANE

0.0000 0.00002,2-DIMETHYLBUTANE (NEOHEXANE)

0.0000 0.00002,3-DIMETHYLBUTANECYCLOPENTANE

0.0000 0.00002-METHYLPENTANE


0.0000 0.0000N-HEXANE

0.0000 0.00002,2-DIMETHYLPENTANE

0.0000 0.0000METHYLCYCLOPENTANE


0.0000 0.00002,2,3-TRIMETHYLBUTANE

0.0000 0.0000BENZENE


0.0000 0.0000CYCLOHEXANE

0.0000 0.00002-METHYLHEXANE


0.0000 0.00001,1-DIMETHYLCYCLOPENTANE3-METHYLHEXANE

0.0000 0.00001,t3-DIMETHYLCYCLOPENTANE

0.0000 0.00001,c3-DIMETHYLCYCLOPENTANE3-ETHYLPENTANE

PAGE 1



COMPONENTMOL

PERCENTWT.

PERCENT


0.0000 0.00001,t2-DIMETHYLCYCLOPENTANE2,2,4-TRIMETHYLPENTANE

0.0000 0.0000N-HEPTANE

0.0000 0.0000METHYLCYCLOHEXANE1,1,3-TRIMETHYLCYCLOPENTANE2,2-DIMETHYLHEXANE

0.0000 0.00001,C2-DIMETHYLCYCLOPENTANE

0.0000 0.00002,5-DIMETHYLHEXANE

0.0000 0.00002,4-DIMETHYLHEXANE2,2,3-TRIMETHYLPENTANEETHYLCYCLOPENTANE

0.0000 0.00001,t2,c4-TRIMETHYLCYCLOPENTANE3,3-DIMETHYLHEXANE

0.0000 0.00001,t2,c3-TRIMETHYLCYCLOPENTANE

0.0000 0.00002,3,4-TRIMETHYLPENTANE

0.0000 0.0000TOLUENE


0.0000 0.00001,1,2-TRIMETHYLCYCLOPENTANE

0.0000 0.00002-METHYLHEPTANE



0.0000 0.00003-METHYLHEPTANE3-ETHYLHEXANE

0.0000 0.00001,c3-DIMETHYLCYCLOHEXANE1,c2,t3-TRIMETHYLCYCLOPENTANE1,c2,t4-TRIMETHYLCYCLOPENTANE

0.0000 0.00001,t4-DIMETHYLCYCLOHEXANE

0.0000 0.00002,2,5-TRIMETHYLHEXANE

0.0000 0.00001,1-DIMETHYLCYCLOHEXANE1,methyl-t3-ETHYLCYCLOPENTANE

0.0000 0.00001-methyl-c3-ETHYLCYCLOPENTANE

0.0000 0.00001-methyl-t2-ETHYLCYCLOPENTANE2,2,4-TRIMETHYLHEXANE

0.0000 0.00001-methyl-1-ETHYLCYCLOPENTANECYCLOHEPTANEN-OCTANE

0.0000 0.00001,T2-DIMETHYLCYCLOCHEXANE

PAGE 2



COMPONENTMOL

PERCENTWT.

PERCENT


0.0000 0.0000UNKNOWN

0.0000 0.00001,t3-DIMETHYLCYCLOHEXANE1,c4-DIMETHYLCYCLOHEXANE1,c2,c3-TRIMETHYLCYCLOPENTANE


0.0000 0.0000ISOPROPYLCYCLOPENTANE

0.0000 0.0000UNKNOWN

0.0000 0.00002,2-DIMETHYLHEPTANE

0.0000 0.00002,4-DIMETHYLHEPTANE1-methyl-c2-ETHYLCYCLOPENTANE


0.0000 0.00001,c2-DIMETHYLCYCLOHEXANE2,6-DIMETHYLHEPTANE

0.0000 0.0000N-PROPYLCYCLOPENTANE1,c3,c5-TRIMETHYLCYCLOHEXANE

0.0000 0.00002,5-DIMETHYLHEPTANE3,5-DIMETHYLHEPTANEETHYLCYCLOHEXANE

0.0000 0.00001,1,3-TRIMETHYLCYCLOHEXANE2,3,3-TRIMETHYLHEXANE3,3-DIMETHYLHEPTANE

0.0000 0.00001,1,4-TRIMETHYLCYCLOHEXANE

0.0000 0.0000UNKNOWN


0.0000 0.0000ETHYLBENZENE

0.0000 0.00001,t2,t4-TRIMETHYLCYCLOHEXANE1,c3,t5-TRIMETHYLCYCLOHEXANE2,3-DIMETHYLHEPTANE

0.0000 0.0000M-XYLENEP-XYLENE3,4-DIMETHYLHEPTANE

0.0000 0.00002-METHYLOCTANE4-METHYLOCTANE

0.0000 0.0000UNKNOWN

0.0000 0.00003-METHYLOCTANE

0.0000 0.0000UNKNOWN

0.0000 0.00001,t2,c3-TRIMETHYLCYCLOHEXANE1,t2,c4-TRIMETHYLCYCLOHEXANE

PAGE 3



COMPONENTMOL

PERCENTWT.

PERCENT


0.0000 0.0000O-XYLENE


0.0000 0.0000UNKNOWN

0.0000 0.0000ISOBUTYLCYCLOPENTANE

0.0000 0.0000N-NONANE

0.0000 0.0000UNKNOWN

0.0000 0.00001,c2,c3-TRIMETHYLCYCLOHEXANE1,c2,t3-TRIMETHYLCYCLOHEXANE

0.0000 0.0000UNKNOWN

0.0000 0.0000ISOPROPYLBENZENE

0.0000 0.00002,2-DIMETHYLOCTANE

0.0000 0.0000ISOPROPYLCYCLOHEXANECYCLOOCTANE

0.0000 0.0000UNKNOWN

0.0000 0.0000N-BUTYLCYCLOPENTANEN-PROPYLCYCLOHEXANE


0.0000 0.0000UNKNOWN

0.0000 0.0000N-PROPYLBENZENE

0.0000 0.0000UNKNOWN

0.0000 0.0000m-ETHYLTOLUENE

0.0000 0.0000p-ETHYLTOLUENE2,3-DIMETHYLOCTANE

0.0000 0.00004-METHYLNONANE5-METHYLNONANE1,3,5-TRIMETHYLBENZENE

0.0000 0.00002-METHYLNONANE

0.0000 0.00003-ETHYLOCTANE

0.0000 0.0000O-ETHYLTOLUENE3-METHYLNONANE

0.0000 0.0000UNKNOWN

0.0000 0.00001,2,4-TRIMETHYLBENZENEt-BUTYLBENZENEMETHYLCYCLOOCTANE

0.0000 0.0000tert-BUTYLCYCLOHEXANE

PAGE 4



COMPONENTMOL

PERCENTWT.

PERCENT


0.0000 0.0000ISO-BUTYLCYCLOHEXANE

0.0000 0.0000N-DECANE

0.0000 0.0000ISOBUTYLBENZENE

0.0000 0.0000sec-BUTYLBENZENE

0.0000 0.0000UNKNOWN

0.0000 0.00001-METHYL-3-ISOPROPYLBENZENE

0.0000 0.00001,2,3-TRIMETHYLBENZENE1-METHYL-4-ISOPROPYLBENZENE

0.0000 0.0000UNKNOWN


0.0000 0.0000UNKNOWN

0.0000 0.0000N-BUTYLCYCLOHEXANE

0.0000 0.0000UNKNOWN

0.0000 0.00001,3-DIETHYLBENZENE1-METHYL-3-PROPYLBENZENE

0.0000 0.00001,2-DIETHYLBENZENEN-BUTYLBENZENE1-METHYL-4-PROPYLBENZENE

0.0000 0.00001,4-DIETHYLBENZENE

0.0000 0.00001-METHYL-2-PROPYLBENZENE

0.0000 0.00001,4-DIMETHYL-2-ETHYLBENZENE

0.0000 0.0000UNKNOWN



0.0000 0.0000UNKNOWN


0.0000 0.0000UNKNOWN

0.0000 0.0000N-UNDECANE

0.0000 0.0000UNKNOWN

0.0000 0.00001,2,4,5-TETRAMETHYLBENZENE


0.0000 0.0000UNKNOWN

0.0000 0.00001,2,3,4-TETRAMETHYLBENZENECYCLODECANE

PAGE 5



COMPONENTMOL

PERCENTWT.

PERCENT


0.0000 0.0000UNKNOWN

0.0000 0.0000NAPHTHALENE

0.0000 0.0000N-DODECANE

0.0000 0.0000ISOTRIDECANES PLUS

TOTALS 0.0000 0.0000

0.0000

0.0000

0.0000

0.0000

0.0000

TOTAL HEXANES =

TOTAL HEPTANES =

TOTAL OCTANES =

TOTAL NONANES =

TOTAL DECANES PLUS =

0.0000

0.0000

0.0000

0.0000

0.0000

PAGE 6


APPENDIX C ELECTRONIC AIR QUALITY

MODELING FILES

July 15, 2016 Mr. Stephen M. Tomasik DEC - Division of Environmental Permits 625 Broadway, 4th Floor Albany, NY 12233-1750 Subject: Millennium Pipeline Company – Hancock Compressor Station Title V Facility Application Dear Mr. Tomasik: On behalf of Millennium Pipeline Company, LLC (Millennium) TRC is submitting the enclosed Title V Permit application. Millennium has contracted TRC to prepare this application for the existing Hancock Compressor Station located in the Town of Hancock, Delaware County, NY. The Project will be constructed on the existing property of the currently permitted Hancock Compressor Station and will consist of the following emission units:

One new Solar Titan 130-22402S, 22,400 HP (ISO) natural gas fired turbine‐driven

compressor unit;

One new Waukesha VGF48GL (1,230 hp) natural gas fired emergency generator;

One new 1.2 MMBtu/hr heat input natural gas fired fuel gas heater; and

One new 1,500 gallon oil storage tank

The enclosed application document includes all the technical support information, NYSDEC air permit application forms, backup engineering calculations, an air quality impact assessment and associated air modeling files. A PDF of this complete submittal also will be sent via email. Please direct any technical questions on this application and supporting documentation to me at email [email protected] or by telephone at 201-508-6960. Sincerely, TRC Theodore Main Permitting Project Manager Cc: Ron Happach, Millennium Mike Armstrong, Millennium Lacey Ivey, Columbia Pipeline Group John Zimmer, TRC Nicole Libby, TRC Darin Ometz, TRC

mailto:[email protected]


Hancock Compressor Station Eastern System Upgrade Project

Air Title V Facility Permit Application

Prepared for:


Prepared by:

TRC Environmental Corporation 1200 Wall Street West, 5th Floor


July 2016

ii

TABLE OF CONTENTS Section Page

1.0 Introduction .......................................................................................................... 1-1

1.1 Project Overview ................................................................................................ 1-1 1.2 Application Summary ........................................................................................ 1-1

2.0 Project Description ................................................................................................ 2-1

2.1 Site Location and Surroundings ........................................................................ 2-1 2.2 Existing Facility Description and Emission Potential ...................................... 2-1 2.3 Facility Conceptual Design ................................................................................2-2

2.3.1 Compressor Turbine ................................................................................. 2-4 2.3.2 Ancillary Equipment .................................................................................. 2-5

2.4 Fuel ................................................................................................................... 2-6 2.5 Fugitive Emissions and Tanks.......................................................................... 2-6 2.6 Proposed Project Emission Potential ................................................................ 2-7

3.0 Applicable Requirements and Required Analyses ............................................... 3-1

3.1 Federal New Source Performance Standards ................................................... 3-1 3.1.1 40 CFR Part 60, Subpart A – General Provisions ......................................... 3-1 3.1.2 40 CFR Part 60 Subpart Kb - Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) ........................................................ 3-1 3.1.3 40 CFR Part 60, Subpart JJJJ – Spark Ignition Internal Combustion Engines 3-2 3.1.4 40 CFR Part 60, Subpart KKKK – Stationary Combustion Turbines ....... 3-2 3.1.5 40 CFR 60, Subparts OOOO and OOOOa – Crude Oil and Natural Gas Production, Transmission and Distribution ............................................................ 3-3

3.2 Nonattainment New Source Review ................................................................. 3-3 3.3 Prevention of Significant Deterioration (PSD) .................................................3-4 3.4 Title V Operating Permit and State Operating Permit Programs ..................... 3-5

3.4.1 Exempt and Trivial Sources ....................................................................... 3-5 3.5 National Emission Standards for Hazardous Air Pollutants ............................3-6

3.5.1 40 CFR Part 63 Subpart HHH (National Emission Standards for Hazardous Air Pollutants from Natural Gas Transmission and Storage Facilities) ..................3-6 3.5.2 40 CFR Part 63 Subpart YYYY (National Emission Standards for Hazardous Air Pollutants for Stationary Combustion Turbines) ............................................... 3-7 3.5.3 40 CFR Part 63 Subpart ZZZZ (National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines) .......... 3-7 3.5.4 40 CFR Part 63 Subpart DDDDD (National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters) .............................................................. 3-7

3.6 New York State Department of Environmental Conservation Regulations ..... 3-7

4.0 Air Quality Modeling Analysis .............................................................................. 4-1

4.1 Background Ambient Air Quality ...................................................................... 4-1 4.2 Modeling Methodology .....................................................................................4-3

4.2.1 Model Selection ..........................................................................................4-3

iii

4.2.2 Urban/Rural Area Analysis ........................................................................4-3 4.2.3 Good Engineering Practice Stack Height ................................................. 4-4 4.2.4 Meteorological Data ................................................................................... 4-5

4.3 Receptor Grid ................................................................................................... 4-6 4.3.1 Basic Grid .................................................................................................. 4-6 4.3.2 Property Line Receptors ........................................................................... 4-6

4.4 Selection of Sources for Modeling ..................................................................... 4-7 4.4.1 Emission Rates and Exhaust Parameters .................................................. 4-7

4.5 Maximum Modeled Facility Concentrations .................................................. 4-10 4.6 Toxic Ambient Air Contaminant Analysis ...................................................... 4-11 4.7 Modeling Data Files ......................................................................................... 4-12 4.8 References........................................................................................................ 4-12

LIST OF TABLES Table 2-1: Existing Facility Emissions ............................................................................. 2-1 Table 2-2: Proposed Facility Emissions ........................................................................... 2-7 Table 3-1: PSD/NNSR Applicability Assessment ...........................................................3-4 Table 4-1: Maximum Measured Ambient Air Quality Concentrations ......................... 4-2 Table 4-2: Stack Parameters and Emission Rates – Existing Solar Mars 100 Compressor

Turbine ............................................................................................................. 4-8 Table 4-3: Stack Parameters and Emission Rates – Proposed Titan 130E Compressor

Turbine ............................................................................................................. 4-9 Table 4-4: Stack Parameters and Emission Rates – Existing Emergency Generator ... 4-9 Table 4-5: Stack Parameters and Emission Rates – Proposed Emergency Generator 4-10 Table 4-6: Stack Parameters and Emission Rates – Proposed Fuel Gas Heater ......... 4-10 Table 4-7: Facility Maximum Modeled Concentrations Compared to NAAQS/NYAAQS

......................................................................................................................... 4-11

LIST OF FIGURES

Figure 2-1: Site Location Aerial....................................................................................... 2-8 Figure 2-2: Site Location Map ........................................................................................ 2-9 Figure 2-3: General Arrangement Plan ......................................................................... 2-10

LIST OF APPENDICES

Appendix A: NYSDEC Application Forms Appendix B: Detailed Emission Calculations and Vendor Data Appendix C: Electronic Air Quality Modeling Files (Available Upon Request)

Millennium Pipeline Company, LLC 1-1 Hancock Compressor Station

1.0 INTRODUCTION 1.1 Project Overview Millennium Pipeline Company, L.L.C. (Millennium) currently owns and operates the Hancock Compressor Station located in Delaware County, New York. The Hancock Compressor Station (CS) is a natural gas transmission facility covered by Standard Industrial Classification (SIC) 4922. The Hancock CS is an existing non-major facility that was constructed under and operates according to NYSDEC Air State Facility Permit ID: 4-1236-00708/00001. Millennium is seeking authorization from the Federal Energy Regulatory Commission (FERC or Commission) pursuant to Section 7(c) of the Natural Gas Act to construct, install, operate, and maintain the Eastern System Upgrade (Project). The purpose of the Project is to permit Millennium to transport an incremental volume of approximately 223,000 dekatherms per day of natural gas from Millennium’s Corning Compressor Station to an existing interconnect with Algonquin Gas Transmission, L.L.C. (Algonquin) located in Ramapo, New York. As part of the Eastern System Upgrade Project and in order to boost pressures on Millennium’s transmission pipeline system, Millennium is proposing to construct and operate one Solar Titan 130E turbine powering a C65 compressor (22,400 hp (ISO)) at the Hancock Compressor Station. Ancillary project emission sources include one (1) 1,230 hp Waukesha VGF48GL emergency generator, one (1) 1.2 MMBtu/hr gas heater, and one (1) 1,500 gallon oil tank. 1.2 Application Summary The Hancock Compressor Station is an existing minor stationary source (as defined under the Prevention of Significant Deterioration of Air Quality [PSD] and Title V rules) located in Delaware County, New York. As demonstrated in Section 3 of this application, the proposed project is not subject to PSD requirements. The Project will be located in the town of Hancock, Delaware County, which is part of the Southern Tier East Intrastate Air Quality Control Region in New York State. Delaware County is considered attainment or unclassifiable for all criteria pollutants including ozone and fine particulate matter (PM2.5). However, because New York State is part of the Northeast Ozone Transport region, the Project area is considered moderate non-attainment for ozone.


The proposed project involves the installation of new emission units at an existing minor source with respect to New Source Review (NSR) permitting requirements at 6 NYCRR Part 231 and Title V major source permitting requirements at 6 NYCRR Part 201-6. With the addition of the new emission units, the facility wide potential to emit for one or more criteria air pollutants will exceed the Title V major source permitting thresholds. As such, Millennium is submitting an initial major source Title V permit application for the modifications to the Hancock Compressor Station. The new Titan 130E combustion turbine will be subject to 40 CFR 60 Subpart KKKK, New Source Performance Standards for Stationary Gas Turbines as well as the applicable state regulations as outlined in Section 3 of this application. The new emergency generator will be subject to 40 CFR 60, Subpart JJJJ, New Source Performance Standards for Stationary Spark Ignition Internal Combustion Engines and 40 CFR 63, Subpart ZZZZ, and National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. The project will not trigger permitting requirements for non attainment areas per 6 NYCRR Part 231. Appendix A of this Title V application contains the NYSDEC application forms and a completed Professional Engineer Certification Form. Emission calculation spreadsheets providing supporting calculations for the application forms are included as Appendix B of this application.



2.1 Site Location and Surroundings The existing Hancock Compressor Station, as shown in Figures 2-1 and 2-2, is located in a rural area in the town of Hancock, Delaware County, New York. The site is currently developed, consisting of components of the existing Hancock Compressor Station. The approximate Universal Transverse Mercator (UTM) coordinates of the facility are: 488,200 meters east and 4,636,900 meters north in Zone 18 (North American Datum of 1983(NAD83)). 2.2 Existing Facility Description and Emission Potential Air emissions from the existing facility are permitted under NYSDEC Air State Facility Permit ID: 4-1236-00708/00001, which became effective on March 18, 2013. The facilitywide potential to emit of the Hancock compressor station is as summarized in the following Table 2-1.

Table 2-1: Existing Facility Emissions

Pollutant

Solar Mars 100

Turbine

Exempt (1)

Waukesha VGF36GL

880 hp Emergency Generator

Exempt (2)

Waste Liquids Storage

Tank (4,000 gal)

Trivial (3)

Station Blowdowns

Existing Facility

Total

NOx 34.24 0.97 - - 35.21

VOC 3.94 0.49 2.41 0.17 7.01

CO 47.62 1.94 - - 49.56

SO2 8.26 0.001 - - 8.26

PM10/PM2.5 12.47 0.02 - - 12.49

GHG(4) 69,319 219 - 675 70,212

HAPs 0.61 0.13 - 0.09 0.83

Individual HAP(5)

0.42

0.10 -

-

0.52


(1) Exempt per 201-3.2(c)(6) for emergency power generating stationary internal combustion engines which meet the requirements of 200.1(cq) of operation when the usual source of electric power is unavailable and no more than 500 hours per year inclusive of emergency operation, testing, and maintenance.

(2) Exempt per 201-3.2(c)(25) for storage tanks under 10,000 gallons, not otherwise subject to Parts 229 or 233 (3) Trivial per 201-3.3(94) for emissions of “….oxygen, carbon dioxide, nitrogen, simple asphyxiants including

methane and propane, trace constituents included in raw materials or byproducts, where the constituents are less than 1 percent by weight for any regulated air pollutant, or 0.1 percent by weight for any carcinogen listed by the United States Department of Health and Human Services’ Seventh Annual Report on Carcinogens (1994). The definition of “regulated air pollutant” under 200.1(bu) does not include methane or ethane.



Based on the potential emissions above, the Hancock Station is currently a minor source with respect to the Title V permitting program established under 6 NYCRR 201 6 and the major source definition per 6 NYCRR 201 2.1(b)(21). Existing permitted emission units at the Hancock compressor station include a single Solar Mars 100 natural gas fired turbine with an ISO rating of 15,900 hp. In addition to the permitted emission unit described above, several exempt emission units are located at the Hancock compressor station. These exempt sources include natural gas fired sources with heat inputs less than 10 million British thermal units per hour (MMBtu/hr) (i.e., one natural gas fired Waukesha VGF36GL emergency generator with a heat input of 7.47 mmBtu/hr). In addition, the existing natural gas liquids filter/separators and associated waste liquids storage tank (4,000 gallon) are typical for natural gas compressor stations, which may receive small amounts of condensate from upstream natural gas supply and where pipeline cleaning activities may result in residual condensate collection. Lastly, existing emissions include trivial station blowdowns consisting of two types of gas blowdown events that could occur at the Station: (1) a type of maintenance gas blowdown that could occur when a compressor is stopped and gas between the suction/discharge valves and compressors is vented to the atmosphere via a blowdown vent, and (2) an emergency shutdown (ESD) that would only occur at required U.S. Department of Transportation (DOT) test intervals or in an emergency situation. 2.3 Facility Conceptual Design As a part of the Eastern System Upgrade project, Millennium is proposing to install the following new equipment at the Hancock compressor station:


One new Solar Titan 130-22402S, 22,400 HP (ISO) natural gas fired turbinedriven compressor unit;

One new Waukesha VGF48GL (1,230 hp) natural gas fired emergency generator; One new 1.2 MMBtu/hr heat input natural gas fired fuel gas heater; and One new 1,500 gallon oil storage tank

The installation of the above equipment will increase the number of piping components at the station which could result in additional fugitive emissions due to equipment leaks. The new Waukesha (1,230 hp) emergency generator has a four stroke, lean burn, natural gas fired stationary reciprocating internal combustion engine. The proposed emergency generator will be installed to meet site wide emergency electrical demands as a result of the Eastern System Upgrade project and will be operated only during normal testing, maintenance, and emergency situations. Per 6 NYCRR 201 3.2(c)(6), emergency power generating stationary internal combustion engines, as defined in section 200.1(vq) of this Title are exempt sources. As such, this generator is an exempt source. Further, the engine will meet the definition of “emergency stationary internal combustion engine” per 40 CFR 60.4248 and will comply with the requirements for operating emergency engines in 40 CFR 60.4243(d). Millennium is proposing to install one natural gas fired fuel gas heater, with a rated heat input capacity of 1.2 MMBtu/hr. Per 6 NYCRR 201 3.2(c)(1)(i), stationary combustion installations with a maximum rated heat input capacity less than 10 MMBtu/hr burning fuels other than coal or wood are exempt from permitting. As such, the heater is an exempt source. Site wide potential fugitive emissions may also increase due to the installation of the new equipment. Typical sources of fugitive emissions from natural gas compressor stations include leaks from piping components (valves, flanges, connectors and open ended lines) as well as potential gas release events. Millennium has provided fugitive emissions estimates for VOC and greenhouse gas (GHG) emissions. Estimates of fugitive emissions are required to be included in Title V permit applications, per 6 NYCRR 201 6.2(d)(3)(ii). Existing storage tanks will not be physically modified with the project and potential emissions from these emission sources will not increase as a result of the project. However, there may be associated increases in actual emissions from these sources which are accounted for in the NSR applicability calculations for the project.


2.3.1 Compressor Turbine The proposed Solar Titan 130E natural gas-fired turbine to be installed at the Hancock Compressor Station will be equipped with Solar’s SoLoNOx dry low NOx combustor technology for NOx control. Emissions for the Solar Turbine assumes that the unit will operate up to 8,760 hours per year and up to 100% rated output. The vendor provided emission rates for normal operating conditions are as follows (all emissions rates are in terms of parts per million dry volume (ppmvd) @ 15% O2):

• 15 ppmvd NOx; • 25 ppmvd CO; • 25 ppmvd unburned hydrocarbons (UHC); and • 5 ppmvd VOC.

Depending upon demand, the turbine may operate at loads ranging from 50% to 100% of full capacity. Because of the different emission rates and exhaust characteristics that occur at different loads and ambient temperatures, a matrix of operating modes is presented in this air permit application. Emission parameters for three turbine loads (50%, 75%, and 100%) and six ambient temperatures (0oF, 20oF, 40oF, 60oF, 80oF and 100oF) are accounted for in this air permit application to cover the range of steady-state turbine operations. At very low load and cold temperature extremes, the turbine system must be controlled differently in order to assure stable operation. The required adjustments to the turbine controls at these conditions cause emissions of NOx, CO and VOC to increase (emission rates of other pollutants are unchanged). Low-load operation (non-normal SoLoNOx operation) of the turbines is expected to occur only during periods of startup and shutdown and for maintenance or unforeseen emergency events. Solar has provided emissions estimates during start-up and shutdown and low load operation (see Solar Product Information Letter (PIL) 170, included as part of the vendor attachments in Appendix B). The annual hours of operation during low load operation was assumed to be not more than 10 hours per year. Similarly, Solar has provided emission estimates for low temperature operation (inlet combustion air temperature less than 0° F and greater than -20° F). Table 3.1 provides estimated pre-control emissions from the turbines at low temperature conditions.

• 120 ppmvd NOx; • 150 ppmvd CO; • 50 ppmvd unburned hydrocarbons (UHC); and


• 10 ppmvd VOC. Millennium reviewed historic meteorological data from the previous five years for the region to estimate the worst case number of hours per year under sub-zero (less than 0° F) conditions. The annual hours of operation during sub-zero conditions was assumed to be not more than 120 hours per year. Turbine emission rates during start-up and shutdown events increase for NOx, CO and VOC as compared to operating above 50% load. The start-up process for the Solar Titan 130E turbine takes approximately 10 minutes from the initiation of start-up to normal operation (equal to or greater than 50% load). Shutdown takes approximately 10 minutes. Millennium has estimated there would be 100 start-up/shutdown events per year. Emissions per start- up and shutdown event for the turbine were estimated based on Table 3 from the Solar PIL 170 entitled “Emission Estimates at Start-up, Shutdown, and Commissioning for SoLoNOx Combustion Products”. Appendix B contains these per-event emission calculations for start- up and shutdown and the associated Solar PIL 170. 2.3.2 Ancillary Equipment Millennium is proposing to install a new Waukesha VGF48GL (1,230 hp) four stroke lean burn natural gas fired emergency generator. The emergency generator will operate for no more than 500 hours/year, and therefore meets the definition of an “emergency power generating stationary internal combustion engine” under 6 NYCRR 200.1(cq). As previously indicated, the generator is an exempt source per 6 NYCRR 201 3.2(c)(6), however the potential emissions for this new unit are included for NSR and Title V applicability purposes. Maximum hourly and annual emission rates for the emergency generator are provided in Appendix B. Emissions of NOx, CO, and VOC are based on regulatory limits under New Source Performance Standard (NSPS) Subpart JJJJ. Emission rates for SO2, particulates, and HAPs are based on US EPA AP-42 emission factors (Table 3.2-2). GHG emissions are based on 40 CFR Part 98 Tables A-1, C-1, and C-2. The emission rates are based on the emergency generator operating at peak load. Millennium is proposing to install one new 1.2 MMBtu/hr (heat input) natural gas heater. Appendix B provides information on the emission factors used to calculate emissions from the heater. As previously indicated, the heater is an exempt source per 6 NYCRR 201 3.2(c)(1)(i), however the potential emissions for this new unit are included for NSR and Title V applicability purposes.


2.4 Fuel The Hancock Station will utilize pipeline natural gas as the sole fuel for all proposed equipment. The natural gas is assumed to have a higher heating value (HHV) of approximately 1,024.5 Btu/standard cubic foot (SCF) and will contain no more than 2.0 grains of sulfur per 100 SCF of gas on an annual average basis. 2.5 Fugitive Emissions and Tanks Fugitive emissions are defined as those emissions which do not pass through a stack, vent, or other functionally equivalent opening, and include natural gas leaks from valves, flanges, pumps, compressors, seals, connections, etc. Vented emissions are defined as those emissions which pass through a stack, vent, or equivalent opening. A compressor may be vented for startup, shutdown, maintenance, or for protection of gas seals from contamination. An individual compressor or the entire station may be blown down (i.e., vented) for testing, or in the event of an emergency. Fugitive emissions at natural gas compressor stations include leaks from piping components (valves, flanges, connectors and open ended lines) as well as potential gas release events. The vast majority of gas release events are associated with startup, shutdown, or maintenance activities. Millennium has provided fugitive emissions estimates for VOC and greenhouse gas (GHG) emissions in Appendix B. The calculations in Appendix B are based on a methodology described in Interstate Natural Gas Association of America guidelines and a recent analysis of a Millennium Pipeline natural gas sample, which is also included in Appendix B. The calculations for operational vented natural gas conservatively assume that the Hancock Station will conduct two full-station blowdowns per year. Estimates of fugitive emissions are required to be included in Title V permit applications, per 6 NYCRR 201 6.2(d)(3)(ii). Existing tanks at the Hancock Station may have associated emissions increases due to the proposed project; however, the associated tanks will not be physically modified with the project. Flashing losses occur when the pressure of a liquid is decreased or the temperature is increased. At Hancock, flashing losses occur at the pipeline waste liquids storage tank and include VOCs and GHGs. Total flashing losses are calculated based on a flash gas rate and a representative flash gas density. The flash gas rate is calculated based on a liquids input rate and a flash factor. Emissions of individual VOCs and GHGs are calculated from total flashing losses using a representative pipeline liquids compositions. The details of the calculations are provided in Appendix B.


Lastly, Millennium is proposing to install a new 1,500 gallon lube oil tank for the Solar Titan 130E turbine. The 1,500 gallon oil storage tank is considered an exempt activity per 6 NYCRR 201- 3.2(c)(25) as a storage tank with a capacity under 10,000 gallons. Estimated emissions were calculated using the Tanks 4.09d estimation tool for storage tank working and standing losses. 2.6 Proposed Project Emission Potential Table 2-2 presents project emission potentials from the new and modified units to be installed as a part of the proposed modifications at Hancock. For new units, project emission potential is equal to potentials to emit. For modified and existing units, the project emission potential equals the potential emissions of the unit minus baseline actual emissions. Per 6 NYCRR 231 4.1(b)(41)(ii), potential emissions are used in place of projected actual emissions. For the existing, unmodified units with associated emission increases, project emission potential may be calculated as projected actual emissions minus baseline actual emissions. However, project emission potential is conservatively set equal to potential emissions. Detailed emission calculations can be found in Appendix B of this permit application.

Table 2-2: Proposed Facility Emissions

Pollutant

Solar Titan 130E

Turbine

Exempt Waukesha Emergency Generator

Exempt Fuel Gas Heater

Trivial Station

Blowdowns

Trivial Station

Fugitives

Proposed

Project Total

NOx 47.92 1.36 0.53 - - 49.80

VOC 5.45 0.68 0.03 0.04 0.88 7.08

CO 77.28 2.71 0.44 - - 80.44

SO2 4.51 0.015 0.030 - - 4.54

PM10/PM2.5 12.10 0.04 0.04 - - 12.16

CO2e 94,373 285 631 573 14,012 109,874

HAPs 2.45 0.18 0.01 - - 2.63 Maximum

Individual HAP (Formaldehyde)

1.69 0.13 0.0003 - -

1.82


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3.0 APPLICABLE REQUIREMENTS AND REQUIRED ANALYSES

This section contains an analysis of the applicability of federal and state air quality regulations to the proposed project. The specific regulations included in this applicability review are the Federal New Source Performance Standards (NSPS), Prevention of Significant Deterioration (PSD) and Non-Attainment New Source Review (NNSR) requirements, Maximum Achievable Control Technology (MACT) requirements for HAPs, and NYSDEC Regulations and Policy. 3.1 Federal New Source Performance Standards The 40 CFR 60 NSPS are technology-based standards that apply to new and modified stationary sources. The 40 CFR 60 NSPS requirements have been established for approximately 70 source categories. The proposed project is subject to the following four subparts: General Provisions (40 CFR Part 60, Subpart A), Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (40 CFR Part 60, Subpart JJJJ), Standards of Performance for Stationary Combustion Turbines (40 CFR Part 60, Subpart KKKK), and the Standards of Performance for Oil and Natural Gas Sector: Emission Standards for New, Reconstructed, and Modified Sources (40 CFR Part 60, Subpart OOOOa. 3.1.1 40 CFR Part 60, Subpart A – General Provisions The new Titan 130E turbine is subject to the general provisions for NSPS units in 40 CFR Part 60 Subpart A. These include the requirements for notification, record keeping, and performance testing contained in 40 CFR Parts 60.7 and 60.8. 3.1.2 40 CFR Part 60 Subpart Kb - Volatile Organic Liquid Storage Vessels

(Including Petroleum Liquid Storage Vessels)

Subpart Kb potentially applies to storage vessels with a capacity greater than 75 cubic meters (m3) (19,813 gallons) that will store volatile organic liquids. Tanks with a capacity greater than 75 m3 are not proposed to be constructed, reconstructed, or modified at Hancock. Therefore, this subpart will not apply.


3.1.3 40 CFR Part 60, Subpart JJJJ – Spark Ignition Internal Combustion Engines

On January 18, 2008, the USEPA promulgated NSPS Subpart JJJJ for new stationary spark-ignited (SI) internal combustion engines (ICE). Under NSPS Subpart JJJJ, all new, modified, and reconstructed stationary SI engines, both emergency and non-emergency, are covered regardless of size and fuel type. Owners/operators have several options to demonstrate compliance with Subpart JJJJ. The rule allows compliance to be demonstrated by purchase of a certified engine or a non-certified engine and an initial performance test. The performance test for a non-certified engine must show compliance with applicable emission limits of:

• NOx – 2.0 g/bhp-hr or 160 ppmvd @ 15% O2; • CO – 4.0 g/bhp-hr or 540 ppmvd @ 15% O2 ; and • VOC (not including formaldehyde) – 1.0 g/bhp-hr or 86 ppmvd @ 15% O2.

If the spark-ignition engine is a non-certified engine, the owner/operator has the option of complying with the emissions standards in either set of units. 3.1.4 40 CFR Part 60, Subpart KKKK – Stationary Combustion Turbines On July 6, 2006, the USEPA promulgated Subpart KKKK to establish emission standards and compliance schedules for the control of emissions from new stationary combustion turbines that commence construction, modification, or reconstruction after February 18, 2005. Note that stationary combustion turbines regulated under Subpart KKKK are exempt from Subpart GG requirements, which are applicable to units constructed, modified, or reconstructed prior to February 18, 2005. Pursuant to 40 CFR 60.4305(a), the new Solar gas turbine is subject to requirements of 40 CFR 60 Subpart KKKK, because the heat input at peak load will be greater than or equal to 10 MMBtu/hr (HHV) and Millennium will have commenced the construction or modification of the turbine after February 18, 2005. Pursuant to 40 CFR 60.4320(a) and Table 1 to Subpart KKKK of Part 60 – Nitrogen Oxide Emission Limits for New Stationary Combustion Turbines, the new gas turbine, which will have HHV heat inputs of between 50 and 850 MMBtu/hr, will comply with a NOx emission standard of 25 ppm at 15 percent O2 or 1.2 lb/MWh useful output as indicated by the vendor guarantee shown in Appendix B. Subpart KKKK also includes a NOx limit of 150 ppmvd at 15% O2 or 8.7 lb/MWh for turbine operation at temperatures less than 0°F and turbine operation at loads less than 75 % of peak load which the new turbine will meet as indicated by the vendor guarantee


shown in Appendix B. The new turbine will not burn any fuel that has the potential to emit in excess of 0.060 lb/MMBtu SO2 heat input, pursuant to 40 CFR 60.4330(a)(1) and (2), respectively. 3.1.5 40 CFR 60, Subparts OOOO and OOOOa – Crude Oil and Natural Gas

Production, Transmission and Distribution Subpart OOOO currently applies to affected facilities that commenced construction, reconstruction, or modification after August 23, 2011. Subpart OOOO establishes emissions standards and compliance schedules for the control of VOCs and SO2 emissions for affected facilities producing, transmitting, or distributing natural gas. Compressors located between the wellhead and the point of custody transfer to the natural gas transmission and storage segment are subject to this Subpart. Custody transfer is defined as the transfer of natural gas after processing and/or treatment in the producing operations. Hancock Station is located after the point of custody transfer, and therefore centrifugal compressors driven by the proposed turbines are not currently subject to this regulation. Storage vessels located in the natural gas transmission and storage segment that have the potential for VOC emissions equal to or greater than 6 tpy are also subject to this Subpart. All storage vessels at Hancock will emit less than this threshold, and thus will not be subject to this regulation. On August 18, 2015, EPA proposed amendments to 40 CFR 60, Subpart OOOO and proposed an entirely new Subpart OOOOa. Based on the effective date of August 2, 2016 for the new Subpart, this project will be required to comply with the requirements of NSPS Subpart OOOOa. While storage tanks remain covered, Subpart OOOOa also includes provisions intended to reduce emissions from compressors and equipment leaks at compressor stations. For equipment leaks, Subpart OOOOa proposes requiring periodic surveys using optical gas imaging (OGI) technology and subsequent repair of any identified leaks. The project will comply with all applicable leak detection provisions of proposed Subpart OOOOa. 3.2 Nonattainment New Source Review The location of the Hancock Compressor Station is in an area currently designated as attainment or unclassifiable for SO2, NO2, CO, PM10, PM2.5 and ozone (O3). However, the project is located in the ozone transport region (OTR). Facilities with the potential to emit more than 100 tons per year of NOx or 50 tons per year of VOC in an OTR are subject to NNSR for these pollutants. The proposed Project will not trigger nonattainment NSR because potential emissions are less than the applicable emissions thresholds as shown


in Table 3-1. As the facility will be a minor source for all nonattainment pollutants, offsets and the application of the Lowest Achievable Emission Rate (LAER) are not necessary.

Table 3-1: PSD/NNSR Applicability Assessment Pollutant PSD/NNSR

Major Source Threshold

(tons/year)

Existing Facility Emissions

(tons/year)

Proposed Modification

Emissions (tons/year)

Total Facility

Emissions (tons/year)

Carbon Monoxide (CO) 250 49.56 77.28 130.00 Sulfur Dioxide (SO2) 250 8.26 4.54 12.80

TSP 250 12.49 12.16 24.65 PM10 250 12.49 12.16 24.65 PM2.5 250 12.49 12.16 24.65

Nitrogen Oxides (NOx) 100 35.21 49.80 85.01 VOC 50 6.87 7.08 13.95

Greenhouse Gases (CO2e)

100,000 70,521 109,874 180,395

Total HAP 25 1.04 2.63 3.67 Individual HAP -

Formaldehyde 10 0.52 1.82 2.34

3.3 Prevention of Significant Deterioration (PSD) Preconstruction air permitting programs that regulate the construction of new stationary sources of air pollution and the modification of existing stationary sources are commonly referred to as NSR. NSR can be divided into major NSR and minor NSR. Major NSR is comprised of the Prevention of Significant Deterioration (PSD). Major NSR requirements are established on a federal level but may be implemented by state or local permitting authorities under either a delegation agreement with USEPA or as a SIP program approved by USEPA. NYSDEC administers its major NSR permitting program through 6 NYCRR Part 231, which establishes preconstruction, construction, and operation requirements for new and modified sources. The Hancock Compressor Station is not classified as one of the 28 named source categories listed in Section 169 of the Clean Air Act. Therefore, to be considered a “major stationary source”, the facility would need to have potential emissions of 250 tons per year or more of any regulated pollutant (except CO2). The final PSD and Title V GHG Tailoring Rule was published in the Federal Register on June 3, 2010 (75 FR 31514) but was ultimately overturned on June 23, 2014 by the US Supreme Court. Under the formerly effective rule, GHGs could, as of July 1, 2011, become “subject to regulation” under the PSD program for construction projects that would result in potential GHG emissions of 100,000 tons per year (tpy) carbon dioxide equivalents (CO2e) or more. However, the June 23, 2014 Supreme Court Decision clarifies that construction projects cannot trigger major NSR for GHGs unless major NSR is otherwise triggered for criteria pollutants.


As shown in Table 3-1, the existing Hancock Compressor Station is a minor stationary source with respect to PSD. With the proposed additions to the Hancock Station the facility will remain a minor source with respect to PSD and thus, the proposed Project is not subject to PSD. 3.4 Title V Operating Permit and State Operating Permit Programs The Title V permit program in 40 CFR Part 70 requires major sources of air pollutants to obtain federal operating permits. The major source thresholds under the Title V program, as defined in 40 CFR 70.2 and which are different from the federal NSR major source thresholds, are 100 tpy of any air pollutant, 10 tpy of any single hazardous air pollutant (HAP), or 25 tpy of total HAPs. More stringent Title V major source thresholds apply for VOC and NOx in ozone nonattainment areas, namely 50 tpy of VOC or NOx in areas defined as serious, 25 tpy in areas defined as severe, and 10 tpy in areas classified as extreme. The State of New York’s Title V Operating Permit Program is administered through a USEPA-approved program at 6 NYCRR 201-6. NYSDEC also administers a state operating permit program through 6 NYCRR 201-5 for certain non-Title V facilities that do not qualify for a minor facility registration under 6 NYCRR Subpart 201-4, including synthetic minor facilities and facilities with actual emissions greater than fifty percent of Title V thresholds. Emission sources or activities listed under NYCRR 201-3 are exempt from the registration and permitting provisions of 6 NYCRR Subparts 201-4, 201-5, and 201-6. As shown in Table 3-1, potential emissions of CO and CO2e exceed the Title V major source thresholds of 100 and 100,000 tons per year, respectively. As such, the facility is subject to Title V permitting requirements for these pollutants. 3.4.1 Exempt and Trivial Sources Exempt activities cannot be excluded when determining applicability of Title V, nonattainment NSR, or PSD. Table 3-1 includes emissions from exempt equipment at the Station (the emergency generators, fuel gas heater, oil storage tank, and waste liquids storage tank). A list of exempt activities is included with the NYSDEC permit application forms in Appendix A. The emergency generators are considered an exempt activity per 6 NYCRR 201-3.2(c)(6) as an emergency power generating internal combustion engine. They conform to the


definition of such an exempt unit under 6 NYCRR 200.1(cq) because they will operate as an electric power source only when the usual supply of electric power is unavailable and will operate for no more than 500 hours per year, inclusive of emergency situations, maintenance, and testing. Pursuant to 6 NYCRR 201-3.2(c)(1)(i), natural gas-fired heaters with a maximum rated heat input capacity less than 10 million British thermal units per hour (MMBtu/hr) are considered exempt sources. The 4,000 gallon waste liquids storage tank and 1,500 gallon lube oil tank are considered an exempt activity per 6 NYCRR 201- 3.2(c)(25) as a storage tank with a capacity under 10,000 gallons. Blowdowns are considered a trivial activity per 6 NYCRR 201-3.3(94) which covers “Emissions of the following pollutants: water vapor, oxygen, carbon dioxide, nitrogen, inert gases such as argon, helium, neon, krypton and xenon, hydrogen, simple asphyxiants including methane and propane, trace constituents included in raw materials or byproducts, where the constituents are less than 1 percent by weight for any regulated air pollutant, or 0.1 percent by weight for any carcinogen listed by the United States Department of Health and Human Services' Seventh Annual Report on Carcinogens (1994).” The natural gas composition at the Hancock Station meets the definition in 6 NYCRR 201-3.3 as shown in Appendix B. 3.5 National Emission Standards for Hazardous Air Pollutants The USEPA has established National Emission Standards for Hazardous Air Pollutants (NESHAP) for specific pollutants and industries in 40 CFR Part 61. The Project does not include any of the specific sources for which NESHAP have been established in Part 61. Therefore, Part 61 NESHAP requirements will not apply to the Project. The USEPA has also established NESHAP requirements in 40 CFR Part 63 for various source categories. The Part 63 NESHAP apply to certain emission units at facilities that are major sources of HAP. The applicability to the Project of several NESHAP rules is discussed below.

3.5.1 40 CFR Part 63 Subpart HHH (National Emission Standards for Hazardous Air Pollutants from Natural Gas Transmission and Storage Facilities)

Subpart HHH applies to natural gas transmission and storage facilities that are major sources of HAPs and that transport or store natural gas prior to entering the pipeline to a local distribution company or to a final end user (if there is no local distribution company). The Hancock Station is an area source (i.e., not major source) of HAPs. Therefore, this subpart will not apply because it only applies to major sources.


3.5.2 40 CFR Part 63 Subpart YYYY (National Emission Standards for Hazardous Air Pollutants for Stationary Combustion Turbines)

Subpart YYYY applies to stationary combustion turbines at major sources of HAPs. Emissions and operating limitations under Subpart YYYY apply to new and reconstructed stationary combustion turbine. The Hancock Station is an area source (i.e., not major source) of HAPs. Therefore, this subpart will not apply because it only applies to major sources.

3.5.3 40 CFR Part 63 Subpart ZZZZ (National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines)

Subpart ZZZZ, applies to existing, new, and reconstructed stationary reciprocating internal combustion engines (ICE) depending on size, use, and whether the engine is located at a major or area source of HAP. The Project includes the installation of one new emergency stationary RICE with a site rating greater than 500 hp at the Hancock Station. New stationary ICE located at area sources of HAP, such as the emergency engine proposed for the Project, must meet the requirements of Subpart ZZZZ by meeting the NSPS. As discussed above, the new emergency engine is subject to the NSPS at 40 CFR Part 60, Subpart JJJJ, therefore the requirements of Subpart ZZZZ will be met.

3.5.4 40 CFR Part 63 Subpart DDDDD (National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters)

Subpart DDDDD applies to certain new and existing boilers and process heaters at major HAP sources. The Hancock Station is an area source (i.e., not major source) of HAPs. Therefore, this subpart will not apply because it only applies to major sources.

3.6 New York State Department of Environmental Conservation Regulations

Applicable NYSDEC air regulations and the associated proposed means of project compliance are identified below: Part 200 defines general terms and conditions, requires sources to restrict

emissions, and allows NYSDEC to enforce NSPS, PSD, and National Emission Standards for Hazardous Air Pollutants (NESHAP). Part 200 is a general applicable requirement; no action is required by the facility.


Part 200.1(cq) defines emergency power generating stationary internal combustion engines as stationary internal combustion engines that operate as mechanical or electrical power sources only when the usual supply of power is unavailable, and operate for no more than 500 hours per year (i.e., applicable to the proposed emergency generator, which has been assumed to operate no more than 500 hours per year, including periodic testing and maintenance activities to ensure reliability).

Part 202-1 requires sources to conduct emissions testing upon the request of NYSDEC. Permit conditions covering construction of the proposed project will likely require stack testing as a condition of receiving its permit to construct.

Part 202-2 requires sources to submit annual emission statements for emissions tracking and fee assessment. Pollutants are required to be reported in an emission statement if certain annual thresholds are exceeded. Project emissions will be reported as required.

Part 211-3 defines general opacity limits for sources of air pollution in New York State. General applicable requirement facility-wide visible emissions are limited to 20 percent opacity (6-minute average) except for one continuous six-minute period per hour of not more than 57 percent opacity. Note that the opacity requirements under Part 227-1 (see below) are more restrictive and effectively supersede the requirements of Part 211-3.

Visible emissions (opacity) for stationary fuel-burning equipment are regulated under 6 NYCRR Subpart 227-1.3. Facility stationary combustion installations must be operated so that the following opacity limits are not violated; 227-1.3(a) 20 percent opacity (six minute average), except for one six-minute period per hour of not more than 27 percent opacity.


4.0 AIR QUALITY MODELING ANALYSIS At the federal level, because the emission increases from the Hancock Station modifications are less than applicable major source thresholds, Millennium will not trigger federal NSR requirements for any regulated air pollutant under either PSD or NNSR permitting programs. At the state level, the Project triggers air permitting through the NYSDEC as a major Title V facility for CO and GHGs. If the agency considers that any project triggering minor NSR permitting could threaten attainment with the National Ambient Air Quality Standards (NAAQSs) or human health from toxic air pollutant (TAP) concentrations, NYSDEC can require air dispersion modeling for the Project. A site wide modeling analysis for criteria pollutants has been performed in accordance with their impact analysis modeling guidance, Policy DAR 10. In addition, a modeling analysis that addresses TAPs is performed per Policy DAR 1. This section details the NAAQS and TAPs modeling assessment for the proposed Hancock Station. 4.1 Background Ambient Air Quality Background ambient air quality data was obtained from various existing monitoring locations. Based on a review of the locations of Pennsylvania and New York ambient air quality monitoring sites, the closest monitoring sites were used to represent the current background air quality in the site area. Background data for CO, NO2, and PM2.5 was obtained from a monitoring station located in Lackawanna County, Pennsylvania (USEPA AIRData # 42-069-2006). This monitor is located in the city of Scranton that has a higher population density and higher density of industrial facilities than the Hancock area in Delaware County. Further, this monitor is located in an area with a greater amount of mobile and point sources of air emissions as compared to the project area. Thus, this monitor is considered to conservatively represent the ambient air quality within the project area.

Background data for SO2 and PM10 was obtained from a monitoring station located in Luzerne County, Pennsylvania (USEPA AIRData # 42-079-1101). This monitor is located in city of Wilkes Barre that has a higher population density and higher density of industrial facilities than the area around the Hancock Station. Further, this monitor is located in an area with a greater amount of mobile and point sources of air emissions as compared to the project area. Thus, this monitor is also considered to conservatively represent the ambient air quality within the project study area.


The monitoring data for the most recent three years (2012 – 2014) are presented and compared to the NAAQS in Table 4-1. The maximum measured concentrations for each of these pollutants during the last three years are all below applicable standards and are proposed to be used as representative background values for comparison of facility concentrations to the NAAQS.


Pollutant Averaging

Period

Maximum Ambient Concentrations ( g/m3) NAAQS

( g/m3) 2012 2013 2014

SO2 1-Houra 24-Hour Annual

21.0 13.6 2.1

18.3 13.6 1.4

23.6 13.9 2.1

196 365 80

NO2 1-Hourb

Annual

67.7

16.1

75.2

15.4

84.6

20.0

188

100

CO 1-Hour 8-Hour

1,380 920

2,070 1,495

1,725 1,150

40,000 10,000

PM10 24-Hour 34 45 32 150

PM2.5c 24-Hour Annual

20 8.3

24 9.2

23 11.1

35 12

a1-hour 3-year average 99th percentile value for SO2 is 21.0 g/m3. b1-hour 3-year average 98th percentile value for NO2 is 75.8 g/m3. c24-hour 3-year average 98th percentile value for PM-2.5 is 22.3 g/m3; Annual 3-year average value for PM2.5 is 9.5 g/m3. High second-high short term (1-, 3-, 8-, and 24-hour) and maximum annual average concentrations presented for all pollutants other than PM2.5 and 1-hour SO2 and NO2. Bold values represent the proposed background values for use in any necessary NAAQS/NYAAQS analyses. Monitored background concentrations obtained from the USEPA AirData website (https://www3.epa.gov/airdata/).

Millennium Pipeline Company LLC 4-3 Hancock Compressor Station

4.2 Modeling Methodology An air quality modeling analysis was performed consistent with the procedures found in the following documents: Guideline on Air Quality Models (Revised) (USEPA, 2005), New Source Review Workshop Manual (USEPA, 1990), Screening Procedures for Estimating the Air Quality Impact of Stationary Sources (USEPA, 1992), and DAR-10: NYSDEC Guidelines on Dispersion Modeling Procedures for Air Quality Impact Analysis (NYSDEC, 2006). 4.2.1 Model Selection The USEPA has compiled a set of preferred and alternative computer models for the calculation of pollutant impacts. The selection of a model depends on the characteristics of the source, as well as the nature of the surrounding study area. Of the four classes of models available, the Gaussian type model is the most widely used technique for estimating the impacts of nonreactive pollutants. The AERMOD model was designed for assessing pollutant concentrations from a wide variety of sources (point, area, and volume). AERMOD is currently recommended by the USEPA for modeling studies in rural or urban areas, flat or complex terrain, and transport distances less than 50 kilometers, with one hour to annual averaging times. The latest version of USEPA’s AERMOD model (Version 15181) was used in the analysis. AERMOD was applied with the regulatory default options and 5-years (2011-2015) of hourly meteorological data consisting of surface observations from Binghamton Edwin A Link Field in Binghamton, NY and concurrent upper air data from Albany, NY. 4.2.2 Urban/Rural Area Analysis A land cover classification analysis was performed to determine whether the URBAN option in the AERMOD model should be used in quantifying ground-level concentrations. The methodology utilized to determine whether the project is located in an urban or rural area is described below. The following classifications relate the colors on a United States Geological Survey (USGS) topographic quadrangle map to the land use type that they represent:

Blue – water (rural); Green – wooded areas (rural);


White – parks, unwooded, non-densely packed structures (rural); Purple – industrial; identified by large buildings, tanks, sewage disposal or

filtration plants, rail yards, roadways, and, intersections (urban); Pink – densely packed structures (urban); and, Red – roadways and intersections (urban)

The USGS map covering the area within a 3-kilometer radius of the facility was reviewed and indicated that the vast majority of the surrounding area is denoted as blue, green, or white, which represent water, wooded areas, parks, and non-densely packed structures. Additionally, the “AERMOD Implementation Guide” published on August 3, 2015 cautions users against applying the Land Use Procedure on a source-by-source basis and instead to consider the potential for urban heat island influences across the full modeling domain. This approach is consistent with the fact that the urban heat island is not a localized effect, but is more regional in character. Because the urban heat island is more of a regional effect, the Urban Source option in AERMOD was not utilized since the area within 3 kilometers of the facility as well as the full modeling domain (20 kilometers by 20 kilometers) is predominantly rural. 4.2.3 Good Engineering Practice Stack Height Section 123 of the Clean Air Act (CAA) required the USEPA to promulgate regulations to assure that the degree of emission limitation for the control of any air pollutant under an applicable State Implementation Plan (SIP) was not affected by (1) stack heights that exceed Good Engineering Practice (GEP) or (2) any other dispersion technique. The USEPA provides specific guidance for determining GEP stack height and for determining whether building downwash will occur in the Guidance for Determination of Good Engineering Practice Stack Height (Technical Support Document for the Stack Height Regulations), (USEPA, 1985). GEP is defined as “…the height necessary to ensure that emissions from the stack do not result in excessive concentrations of any air pollutant in the immediate vicinity of the source as a result of atmospheric downwash, eddies, and wakes that may be created by the source itself, or nearby structures, or nearby terrain “obstacles”.” The GEP definition is based on the observed phenomenon of atmospheric flow in the immediate vicinity of a structure. It identifies the minimum stack height at which significant adverse aerodynamics (downwash) are avoided. The USEPA GEP stack height regulations (40 CFR 51.100) specify that the GEP stack height (HGEP) be calculated in the following manner:


HGEP = HB + 1.5L Where: HB = the height of adjacent or nearby structures, and

L = the lesser dimension (height or projected width of the adjacent or nearby structures).

A detailed plot plan of the proposed facility is shown in Figure 2-3. A GEP stack height analysis has been conducted using the USEPA approved Building Profile Input Program with PRIME (BPIPPRM, version 04274). The maximum calculated GEP stack height for the new emission sources is 131 feet; the controlling structure is the existing compressor building (52.5 feet). Direction-specific downwash parameters were determined using BPIPPRM, version 04274. Electronic input and output files for the BPIPPRM model have been provided on the DVD-ROM contained in Appendix C. 4.2.4 Meteorological Data If at least one year of hourly on-site meteorological data is not available, the application of the AERMOD dispersion model requires five years of hourly meteorological data that are representative of the project site. In addition to being representative, the data must meet quality and completeness requirements per USEPA guidelines. The closest source of representative hourly surface meteorological data is Binghamton Edwin A Link Field located in Binghamton, NY located approximately 48 miles to the northwest of the Hancock Compressor Station. The meteorological data at the Binghamton Edwin A Link Field is recorded by an Automated Surface Observing System (ASOS) that records 1-minute measurements of wind direction and wind speed along with hourly surface observations necessary. The USEPA AERMINUTE program was used by the NYSDEC to process 1-minute ASOS wind data (2011 – 2015) from the Binghamton surface station in order to generate hourly averaged wind speed and wind direction data to supplement the standard hourly ASOS observations. The hourly averaged wind speed and direction data generated by AERMINUTE was merged with the aforementioned hourly surface data. The AERMOD assessment utilized five (5) years (2011–2015) of concurrent meteorological data collected from a meteorological tower at the Binghamton Edwin A Link Field and from radiosondes launched from Albany, New York. Both the surface and upper air sounding data were processed by the NYSDEC using AERMOD’s meteorological processor, AERMET (version 15181). The output from AERMET was used as the meteorological database for the modeling analysis and consists of a surface data file and


a vertical profile data file. These data, which were prepared and processed to AERMOD format by the NYSDEC, was provided for use in the modeling analyses for the proposed facility. 4.3 Receptor Grid 4.3.1 Basic Grid The AERMOD model requires receptor data consisting of location coordinates and ground-level elevations. The receptor generating program, AERMAP (Version 11103), was used to develop a complete receptor grid to a distance of 10 kilometers from the proposed facility. AERMAP uses digital elevation model (DEM) or the National Elevation Dataset (NED) data obtained from the USGS. The preferred elevation dataset based on NED data was used in AERMAP to process the receptor grid. This is currently the preferred data to be used with AERMAP as indicated in the USEPA AERMOD Implementation Guide published August 3, 2015. AERMAP was run to determine the representative elevation for each receptor using 1/3 arc second NED files that were obtained for an area covering at least 10 kilometers in all directions from the proposed facility. The NED data was obtained through the USGS Seamless Data Server (http://seamless.usgs.gov/index.php). The following rectangular (i.e. Cartesian) receptors were used to assess the air quality impact of the proposed facility:

Consistent with DAR-10 guidance, fine grid receptors (70 meter spacing) for a 20 km (east-west) x 20 km (north-south) grid centered on the proposed facility site.

4.3.2 Property Line Receptors The facility has a fenced property line that precludes public access to the site. Ambient air is therefore defined as the area at and beyond the fence. The modeling receptor grid includes receptors spaced at 25-meter intervals along the entire fence line. Any Cartesian receptors located within the fence line were removed.


4.4 Selection of Sources for Modeling The emission sources responsible for most of the potential emissions from the Hancock Compressor Station are the two (2) combustion turbines. These units were included in and are the main focus of the modeling analyses. The modeling includes consideration of operation over a range of turbine loads, ambient temperatures, and operating scenarios. Ancillary sources (emergency diesel generators and fuel gas heater) were included in the modeling for appropriate pollutants and averaging periods. The emergency equipment may operate for up to 30 minutes in any day for readiness testing and maintenance purposes. Operation of the emergency equipment for longer periods of time in an emergency mode will not be expected to occur when the turbines are operating. Although only limited operation is expected from the emergency equipment, initial modeling to assess short-term facility impacts assumed concurrent operation of the emergency equipment for readiness testing (i.e., up to 30 minutes per day) with the combustion turbines. 4.4.1 Emission Rates and Exhaust Parameters The dispersion modeling analysis was conducted with emission rates and flue gas exhaust characteristics (flow rate and temperature) that are expected to represent the range of possible values for the proposed and existing natural gas fired turbines. Because emission rates and flue gas characteristics for a given turbine load vary as a function of ambient temperature and fuel use, data were derived for a number of ambient temperature cases for natural gas fuel at 100%, 75% and 50% operating loads. The temperatures were:

• <0°F, 0°F, 20°F, 40°F, 60°F, 80°F and 100°F. A detailed summary of the stack exhaust and emissions data for all loads and ambient temperatures cases are provided in Appendix B. To be conservative and limit the number of cases to be modeled, the short-term modeling analysis was conducted using the lowest stack exhaust temperature and exit velocity coupled with the maximum emission rate over all ambient temperature cases for each operating load (with the exception of 1-hour NO2 modeling which excluded the <0ºF data as discussed below). Annual modeling was based on the 100% load 40°F case (vendor performance data for the turbine was available for 40°F and 60°F). The annual average temperature for the project area is approximately 50°F. Use of the 40ºF emissions data is conservative as emissions are slightly higher than


the 60°F case.). Tables 4-2 and 4-3 summarize the stack parameters and emission rates used in the modeling for the compressor turbines. Note that the modeling for 1-hour NO2 excluded the emergency generator for which normal operations (maintenance purposes only) will be limited to no more than 30 minutes per day with an annual limit of 100 hours per year for testing and maintenance purposes. The 1-hour NO2 modeling also did not consider combustion turbine operations under sub-zero ambient temperature conditions as these conditions are extremely limited annually. The exclusion of the emergency generator and sub-zero operations for the combustion turbines for the 1-hour NO2 modeling is based on USEPA guidance provided in the March 1, 2011 memorandum, “Additional Clarification Regarding Application of Appendix W Modeling Guidance for the 1-hour NO2 National Ambient Air Quality Standard” for intermittent sources such as emergency generators. In the memo, US EPA states the following:


The emergency generator and sub-zero operation of the combustion turbine are considered as intermittent emissions, and thus, were excluded from the 1-hour NO2 modeling assessment.

Table 4-2: Stack Parameters and Emission Rates – Existing Solar Mars 100 Compressor Turbine

Parameter Values

Load 50% 75% 100% Annual(2) Stack Height (m) 18.29 18.29 18.29 18.29

Stack Diameter (m)(1) 2.72 2.72 2.72 2.72 Exhaust Velocity (m/s) 12.23 13.38 14.52 15.94 Exhaust Temperature (K) 737.03 738.71 736.48 752.04

Pollutant Emissions (g/s)

NOx 0.6886 0.8632 0.9236 0.9850 CO 4.5110 5.2552 5.7442 -- SO2 0.1866 0.2174 0.2376 0.2376 PM10/PM2.5 0.2818 0.3283 0.3588 0.3588


(1) The turbine stack is square (95 inches x 95 inches). The value listed and used in the modeling is the effective diameter for an equivalent area circular stack. (2) Based on conservative annual average exhaust parameters for 40ºF and annual potential to emit discussed in Section 2.

Table 4-3: Stack Parameters and Emission Rates – Proposed Titan 130E

Compressor Turbine

Parameter Values Load 50% 75 100% Annual(2) Stack Height (m) 21.34 21.34 21.34 21.34

Stack Diameter (m)(1) 2.92 2.92 2.92 2.92 Exhaust Velocity (m/s) 11.83 14.03 15.63 17.66 Exhaust Temperature (K) 720.9 730.9 758.7 765.9


NOx 0.858 1.063 1.254 1.375 CO 5.224 6.471 7.628 - SO2 0.094 0.113 0.130 0.130 PM10/PM2.5 0.251 0.304 0.348 0.348

(1) The turbine stack is square (102 inches x 102 inches). The value listed and used in the modeling is the effective diameter for an equivalent area circular stack. (2) Based on conservative annual average exhaust parameters for 40ºF and annual potential to emit discussed in Section 2.

Tables 4-4 through 4-6 present the stack parameters and emission rates for the emergency diesel generators and fuel gas heater. The emergency diesel generators were included in the modeling analysis for appropriate pollutants and averaging periods when used for readiness testing (i.e., up to 30 minutes per day).

Table 4-4: Stack Parameters and Emission Rates – Existing Emergency Generator

Parameter Values

Stack Height (m) 6.25 Stack Diameter (m) 0.30 Exhaust Velocity (m/s) 29.39 Exhaust Temperature (K) 723.7 Averaging Period 1-hr 3-hr 8-hr 24-hr Annual

Pollutant Emissions (g/sec)

NOx 0.24 -- -- -- 0.028 CO 0.49 -- 0.061 -- -- SO2 2.77E-04 9.22E-05 -- 1.15E-05 3.16E-05 PM10/PM2.5 -- -- -- 1.96E-04 5.47E-04


Notes: Hourly emission rates divided by 2 to simulate limit of 30 minutes testing per day. For the 3-, 8- and 24-hour period the hourly emission rate is further divided by the number of hours in the period.

Table 4-5: Stack Parameters and Emission Rates – Proposed Emergency

Generator

Parameter Values Stack Height (m) 5.94 Stack Diameter (m) 0.30 Exhaust Velocity (m/s) 39.84 Exhaust Temperature (K) 721.5 Averaging Period 1-hr 3-hr 8-hr 24-hr Annual


NOx 0.3422 - - - 0.039 CO 0.683 - 0.085 - - SO2 0.0004 0.00013 - 0.000017 0.00004 PM10/PM2.5 0.0061 - - 0.00025 0.00069

Notes: Hourly emission rate divided by 2 to simulate limit of 30 minutes testing per day. For the 3-, 8- and 24-hour period the hourly emission rate is further divided by the number of hours in the period.

Table 4-6: Stack Parameters and Emission Rates – Proposed Fuel Gas

Heater

Parameter Values Stack Height (m) 4.877 Stack Diameter (m) 0.406 Exhaust Velocity (m/s) 1.86 Exhaust Temperature (K) 510.9


NOx 0.015 CO 0.012 SO2 0.0008 PM10/PM2.5 0.0011

4.5 Maximum Modeled Facility Concentrations Table 4-7 presents the maximum modeled air quality concentrations of the proposed facility calculated by AERMOD. As shown in this table, the maximum modeled


concentrations when combined with a representative background concentration, are less than the applicable NAAQS/NYAAQS for all pollutants.


Pollutant Averaging

Period

NAAQS/NYAAQS ( g/m3)

Maximum Modeled

Concentration ( g/m3)

Background Concentration

( g/m3)

Total Concentration

( g/m3)

CO 1-Hour 40,000 452 2,070 2,522 8-Hour 10,000 192 1,495 1,687

SO2

1-Hour 196 9.2 21.0 30.2 3-Hour 1,300 8.9 23.6a 32.5

24-Hour -/260 5.2 13.9 19.1 Annual -/60 0.35 2.1 2.5

PM-10 24-Hour 150 7.8 45 52.8

PM-2.5 24-Hour 35 3.8 22.3 26.1 Annual 12 0.52 9.5 10.0

NO2 1-Hour 188 34.9b 75.8 110.7

Annual 100 5.0c 20.0 25.0 aConservatively based upon maximum 1-hour SO2 monitored concentration. bAssumed 80% of NOx is NO2 per USEPA guidance. cAssumed 75% of NOx is NO2 per USEPA guidance.

4.6 Toxic Ambient Air Contaminant Analysis Air quality modeling was conducted for potential toxic (non-criteria) air pollutant emissions from the proposed non-exempt facility sources. The modeling methodology used in the toxic air pollutant analysis was the same as used in the Part 201 air quality analyses for criteria air pollutants. Maximum modeled short-term and annual ground level concentrations of each toxic air pollutant were compared to the DEC’s short-term guideline concentration (SGC) and annual guideline concentration (AGC), respectively. The DEC SGCs and AGCs used in the analysis are listed in the DAR-1 (formerly Air Guide-1) tables that were published by the DEC in February 2014. Unit concentrations for the 1-hour and annual averaging periods were calculated for the combustion turbines. The maximum toxic air pollutant-specific emission rate was multiplied by the modeled unit concentration to determine the maximum pollutant-specific concentration. Note that summing the individual maximum source


concentrations, regardless of time and location, provides a conservative estimate of the actual toxic air pollutant concentrations resulting from the facility. Presented in Table 4-8 are the NYSDEC SGCs and AGCs and the facility maximum modeled concentrations for each toxic air pollutant. As shown in the table, all of the maximum modeled toxic air pollutants are well below their corresponding NYSDEC SGC and AGC. 4.7 Modeling Data Files All modeling data files to determine the maximum ambient ground-level concentrations from the proposed facility are included on DVD-ROM in Appendix C. 4.8 References NYSDEC, 2006. NYSDEC Guidelines on Dispersion Modeling Procedures for Air Quality

Impact Analysis – DAR 10. Impact Assessment and Meteorology Section, Bureau of Stationary Sources. May 9, 2006.

USEPA, 2015. AERMOD Implementation Guide. AERMOD Implementation Workgroup, Office of Air Quality Planning and Standards, Air Quality Assessment Division, Research Triangle Park, North Carolina. August 3, 2015.

USEPA, 2014. Clarification on the Use of AERMOD Dispersion Modeling for Demonstrating Compliance with the NO2 National Ambient Air Quality Standard. USEPA. September 30, 2014.

USEPA, 2011. Additional Clarification Regarding Application of Appendix W Modeling Guidance for the 1-Hour NO2 NAAQS. USEPA. March 1, 2011.

USEPA, 2005. Guideline on Air Quality Models (Revised). Appendix W to Title 40 U.S. Code of Federal Regulations (CFR) Parts 51 and 52, Office of Air Quality Planning and Standards, U.S. Environmental Protection Agency. Research Triangle Park, North Carolina. November 6, 2005.

USEPA, 1992. "Screening Procedures for Estimating the Air Quality Impact of Stationary Sources, Revised". EPA Document 454/R-92-019, Office of Air Quality Planning and Standards, Research Triangle Park, North Carolina.

USEPA, 1990. "New Source Review Workshop Manual, Draft". Office of Air Quality Planning and Standards, U.S. Environmental Protection Agency. Research Triangle Park, North Carolina.

USEPA, 1985. Guidelines for Determination of Good Engineering Practice Stack Height (Technical Support Document for the Stack Height Regulations-Revised). EPA-450/4-80-023R. U.S. Environmental Protection Agency.

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APPENDIX ANYSDEC APPLICATION FORMS

-

Subdivision Paragraph Subparagraph ClauseFacility State Only Requirements Continuation Sheet(s)

SubclauseTitle Type Part Subpart Section

For all emission units subject to any applicable requirements that will become effective during the term of the permit, this facility will meet such requirements on a timely basis.

Compliance certification reports will be submitted at least once per year. Each report will certify compliance status with respect to each applicable requirement, and the method used to determine the status.

Title Type Part Subparagraph ClauseSubpart SubclauseSection Subdivision Paragraph

Affected States (Title V Facilities Only) Vermont Massachusetts Rhode Island Pennsylvania Tribal Land: __________________

New Hampshire Connecticut New Jersey Ohio Tribal Land:

NAICS Code(s)SIC Code(s)

Facility Description Continuation Sheet(s)

Facility Applicable Federal Requirements Continuation Sheet(s)

Compliance Statements (Title V Facilities Only)I certify that as of the date of this application the facility is in compliance with all applicable requirements. Yes NoIf one or more emission units at the facility are not in compliance with all applicable requirements at the time of signing this application (the 'NO" box must be checked), the noncomplying units must be identified in the "Compliance Plan" block on page 8 of this form along with the compliance plan information required. For all emission units at the facility that are operating in compliance with all applicable requirements, complete the following:

This facility will continue to be operated and maintained in such a manner as to assure compliance for the duration of the permit, except those emission units referenced in the compliance plan portion of this application.


DEC ID

Project Description Continuation Sheet(s)

Section III - Facility InformationFacility Classification

Hospital Residential Educational/Institutional Commercial Industrial Utility

4 1 2 3 6 0 0 7 0 8

As part of the Eastern System Upgrade Project and in order to boost pressures on Millennium’s transmission pipelinesystem, Millennium is proposing to construct and operate one Solar Titan 130E compressor turbine at the HancockCompressor Station. Ancillary project emission sources include one (1) 1,230 hp emergency generator, one (1) 1.2MMBtu/hr gas heater, and a 1,500 gallon oil tank.

4922

Millennium Pipeline Company, L.L.C. (Millennium) currently owns and operates the Hancock Compressor Stationlocated in Delaware County, New York. The Hancock Compressor Station (CS) is a natural gas transmission facilitycovered by Standard Industrial Classification (SIC) 4922. The Hancock CS is an existing non-major facility that wasconstructed under and operates according to NYSDEC Air State Facility Permit ID: 4-1236-00708/00001.

6 NYCRR 202 1

6 NYCRR 211 1

6 NYCRR 212

6 NYCRR 227 1

6 NYCRR 201 3

6 NYCRR 201 6

Version 1.2 - 3/4/2015

-

007439 - 92 - 1 Lead (elemental)

0NY750 - 00 - 0 Carbon Dioxide Equivalents

0NY998 - 00 - 0 Total Volatile Organic Compounds

0NY100 - 00 - 0 Total Hazardous Air Pollutants

000630 - 08 - 0 Carbon Monoxide

007446 - 09 - 5 Sulfur Dioxide

0NY210 - 00 - 0 Oxides of Nitrogen

0NY075 - 00 - 5 PM-10

Range Code

(lbs/yr)

0NY750 - 02 - 5 PM-2.5


Facility Emissions Summary Continuation Sheet(s)Potential to Emit

Actual (lbs/yr)

Averaging Method Monitoring Frequency Reporting RequirementsCode Description Code Description Code Description

LimitUpper Lower


Work PracticeType Code Description

Process Material Reference Test Method

ParameterCode Description Manufacturer's Name/Model Number

Applicable Federal Requirement State Only Requirement

CappingCAS Number Contaminant Name

Monitoring Information Ambient Air Monitoring Work Practice Involving Specific Operations Record Keeping/Maintenance Procedures

Description

SubclauseRule Citation

Title Type Part Subpart Section Subdivision Paragraph Subparagraph Clause

DEC ID

Facility Compliance Certification Continuation Sheet(s)


4 1 2 3 6 0 0 7 0 8

C >= 1

C >= 1

C >= 1

F >= 5

G >= 1

-

C >= 1

B >= 2

J >= 10

50-00-0 Formaldehyde Y > 0 b

-

-

Version 1.2 - 3/4/2015

-

-

Design Capacity

Design Capacity Units Waste Feed Waste TypeCode Description Code Description Code Description


Date of Operation

Date of Removal

Control Type Manufacturer's Name/Model NumberID Type Code Description

Design Capacity




Date of Operation


DescriptionManufacturer's

Name/Model NumberEmission Source

ID TypeDate of

RemovalControl Type

Code

Emission Source/Control Information Continuation Sheet(s)

Exit Velocity (FPS)

Exit Flow (ACFM)


Date of Removal






Emission Point

Date of RemovalExit Velocity (FPS)

Exit Flow (ACFM)





Emission PointEmission Point Information Continuation Sheet(s)

Building ID Length (ft) Width (ft) OrientationBuilding Name

Emission Unit


Building Information Continuation Sheet(s)

Air Permit ApplicationDEC ID

Section IV - Emission Unit InformationEmission Unit Description Continuation Sheet(s)

4 1 2 3 6 0 0 7 0 8

U 0 0 0 0 1

Solar Mars 100 Combustion Turbine

1 Compressor Building - Mars 100 90 60 20

2 Station Control/Auxiliary Building 93 36 20

3 Compressor Building - Titan 130E 100 60 20

0 0 0 0 1

1,680 60 7.5 866 95 95

47.6 179,106 488.119 4636.928 1 61

0 0 0 0 2

1,680 70 26 9.58 919 102 102

58.0 251,130 488.170 4636.919 3 67

T U R B 1 C 5/2013 11/2013 Solar Mars 100

135.6 25

S L N X 1 K 5/2013 11/2013 103 Solar SoLoNOx

Version 1.2 - 3/4/2015

- -

-



DEC ID

Section IV - Emission Unit InformationEmission Unit Description (continuation)

Emission Unit

4 1 2 3 6 0 0 7 0 8

U 0 0 0 0 2


- -

-


Code DescriptionDesign

CapacityDesign Capacity Units Waste Feed Waste Type

Code Description Code Description


Date of Operation

Date of Removal

Control Type Manufacturer's Name/Model No.ID Type Code Description





Date of Operation

Date of Removal






Date of Operation

Date of Removal






Date of Operation

Date of Removal






Date of Operation

Date of Removal



Design Capacity



Control TypeCode Description

Manufacturer's Name/Model No.


Date of Operation

Emission Unit

Emission SourceID Type

Date of Removal


DEC ID

Section IV - Emission Unit InformationEmission Source/Control (continuation)

4 1 2 3 6 0 0 7 0 8

U 0 0 0 0 2

TURB2 C Solar Titan 130E

165.5 25

SLNX2 K 103 Solar Turbines SoLoNOx

-

-

-





Throughput Quantity UnitsQuantity/Hr Quantity/Yr


Description

Code

Operating ScheduleBuilding Floor/Location

Hours/Day Days/Year

Floor/Location


Operating ScheduleHours/Day


Quantity/Hr Quantity/YrThroughput Quantity Units

Building


Description

Code Description


Description


Days/Year


DEC ID

Process Information Continuation Sheet(s)

4 1 2 3 6 0 0 7 0 8

U 0 0 0 0 1 0 0 1

Solar Mars 100 Combustion Turbine

2-02-002-01

24 365 1 Ground

00001

TURB1

SLNX1

U 0 0 0 0 2 0 0 1


2-02-002-01

24 365 3 Ground

00002

TURB2

SLNX2

Version 1.2 - 3/4/2015

-

Applicable Federal Requirement State Only Requirement CappingEmission Source


Rule CitationTitle Type Part Subpart Section Subdivision

Monitoring Information

Emission Unit Emission Point

Process

Emission Unit Compliance Certification Continuation Sheet(s)

SubclauseParagraph Subparagraph Clause

Subparag. Cl. Subcl. Continuation Sheet(s)

Title Type PartEmission Unit

Emission Point

ProcessEmission Source

Emission Unit State Only RequirementsSubpart Section Subdiv. Parag.

ProcessEmission Source Title Subpart Subparag.Section Subdiv. Parag. Cl. Subcl.

Emission Unit Applicable Federal Requirements

DEC ID


PartType Continuation Sheet(s)

Emission UnitEmission

Point

Description

Ambient Air Monitoring Record Keeping/Maintenance ProceduresDescription

Work Practice Process MaterialReference Test Method

Type

ParameterManufacturer's Name/Model Number

Code Description

Continuous Emission Monitoring Monitoring of a Process or Control Device Parameters as a Surrogate Intermittent Emission Testing Work Practice Involving Specific Operations

Code Description

Limit Limit UnitsUpper Lower Code Description

Averaging Method Monitoring Frequency Reporting RequirementsCode Description Code Description

Code

4 1 2 3 6 0 0 7 0 8

U00001/U00002 40 CFR 60 KKKK 4305 a

U00001/U00002 40 CFR 60 KKKK 4320 a

U00001/U00002 40 CFR 60 KKKK 4330

U00001/U00002 40 CFR 60 KKKK 4333 a

40 CFR 60 KKKK 4320 a

U00001/U00002 001 0NY210-00-0 Oxides of Nitrogen

The owner or operator of a stationary combustion turbine must meet the appropriate emission limit for the operationcondition listed in Table 1 of this Subpart. The emission limit is 25 ppm at 15 percent Oxygen for operation at ambient

temperatures greater than 0 degrees F.

25 275

20 14 16

Version 1.2 - 3/4/2015

- -

Subpart Section Subdiv. Parag.


Type Part Clause


DEC ID

Section IV - Emission Unit InformationEmission

UnitEmission

PointProcess

Emission Source

Emission Unit Applicable Federal Requirements (continuation)Title Subparag. Subcl.

4 1 2 3 6 0 0 7 0 8

U00001,U00002 40 CFR 60 KKKK 4340 a

U00001,U00002 40 CFR 60 KKKK 4365 a

U00001,U00002 40 CFR 60 KKKK 4375 b

U00001,U00002 40 CFR 60 KKKK 4400

U00001,U00002 6 NYCRR 202 1 1

U00001,U00002 6 NYCRR 202 1 2

U00001,U00002 6 NYCRR 211 1

U00001,U00002 6 NYCRR 227 1 2

U00001,U00002 6 NYCRR 227 1 3 b

- -

Applicable Federal Requirement State Only Requirement Capping

Subparagraph Clause

Emission Unit CAS No. Contaminant Name


Description

Code Description Code Description Code DescriptionAveraging Method Monitoring Frequency Reporting Requirements

LimitUpper


ParameterCode Description

Manufacturer Name/Model No.

Work PracticeType

Process MaterialCode Description

Reference Test Method

Lower

Emission Point Process

Subclause

Section IV - Emission Unit InformationEmission Unit Compliance Certification (continuation)

Rule CitationTitle Type Part Subpart Section Subdivision Paragraph

Monitoring Information Continuous Emission Monitoring Intermittent Emission Testing Ambient Air Monitoring

Monitoring of Process or Control Device Parameters as a Surrogate Work Practice Involving Specific Operations Record Keeping/Maintenance Procedures

Emission Source


DEC ID4 1 2 3 6 0 0 7 0 8

40 CFR KKKK a

U00001/U00002 001 007446-09-5

The facility may elect not to monitor the total sulfur content of the fuel combusted in the turbine, if the fuel isdemonstrated not to exceed potential sulfur emissions of 0.060 lb/SO2/mmBtu of heat input. The facility must use thefuel quality characteristics in a current, valid purchase contract, tariff sheet, or transportation contract for the fuel,specifying that"

1. The total sulfur content for natural gas use is 20 grains of sulfur or less per 100 standard cubic feet, or2. Has potential sulfur emissions less than 0.060 lb SO2/mmBtu heat input.

The FERC gas tariff will be used to demonstrate compliance with this requirement

25

13 14

-

-

-

-


Clause SubclausePart Subpart Section Subdivision Paragraph Subparagraph

DEC ID

Determination of Non-Applicability (Title V Only) Continuation Sheet(s)Rule Citation

Title Type


Type Part Subpart Section Subdivision Paragraph

Description

Rule CitationTitle



Description

Process Emissions Summary Continuation Sheet(s)

Subparagraph Clause Subclause

ERP How DeterminedCAS Number Contaminant Name % Thruput % Capture % Control ERP (lbs/hr)

Process

Potential to Emit(lbs/hr) (lbs/yr) (standard units)

Standard Units



Emission Unit

(standard units) (lbs/hr) (lbs/yr)






(lbs/hr) (lbs/yr)




Actual Emissions(lbs/hr) (lbs/yr) (standard units)

4 1 2 3 6 0 0 7 0 8

60

U00001/U00002

Sulfur Dioxide

Version 1.2 - 3/4/2015

-

-


ERP (lbs/yr)Potential to Emit

(lbs/hr) (lbs/yr)Actual Emissions

(lbs/hr) (lbs/yr)


DEC ID

Emission Unit Emission Unit Emissions Summary Continuation Sheet(s)


(lbs/yr) (lbs/hr) (lbs/yr)





(lbs/hr)


Certified progress reports are to be submitted every 6 months beginning / /



Parag. Subparag. Clause Subcl.

Compliance Plan Continuation Sheet(s)For any emission units which are not in compliance at the time of permit application, the applicant shall complete the following:

Consent Order

Emission Unit Process Emission Source

Applicable Federal RequirementTitle Type Part Subpart Section Subdiv.

Date ScheduledR/IRemedial Measure(s) / Intermediate Milestone(s)

4 1 2 3 6 0 0 7 0 8

N/A - All emission units are in compliance at the time of permit applicaiton

Version 1.2 - 3/4/2015

-

- - /

- - /

Continuation Sheet(s)Emission Source

Date MethodBaseline Period ____ /____ /________ to ____ / ____ / ________


DEC ID

Request for Emission Reduction Credits

Emission Reduction Description

Contaminant Emission Reduction DataReduction

Facility to Use Future Reduction

CAS Number Contaminant NameERC (lbs/yr)

Netting Offset

Use of Emission Reduction Credits Continuation Sheet(s)

CAS Number Contaminant Name PEP (lbs/yr)

Application ID

Name

Location Address


Name

Permit ID

Location Address

Emission SourceProposed Project Description

Contaminant Emissions Increase Data

ERC (lbs/yr)Netting OffsetContaminant Name

Statement of Compliance All facilities under the ownership of this "owner/firm" are operating in compliance with all applicable requirements and state

regulations including any compliance certification requirements under Section 114(a)(3) of the Clean Air Act Amendments of 1990, or are meeting the schedule of a consent order.

Source of Emission Reduction Credit - Facility


Emission Source CAS Number

4 0 0 7 0 81 2 3 6

Version 1.2 - 3/4/2015

-

Required Supporting Documentation: List of Exempt Activities (form attached) Plot Plan Process Flow Diagram Methods Used to Determine Compliance (form attached) Calculations

Optional Supporting Documentation: Air Quality Model ( ____ / ____ / _____ ) Confidentiality Justification Ambient Air Monitoring Plan ( ____ / ____ / _____ ) Stack Test Protocols/Reports ( ____ / ____ / _____ ) Continuous Emissions Monitoring Plans/QA/QC ( ____ / ____ / _____ ) MACT Demonstration ( ____ / ____ / _____ ) Operational Flexibility: Description of Alternative Operating Scenarios and Protocols Title IV: Application/Registration (where appropriate) ERC Quantification (form attached) Baseline Period Demonstration Use of ERC(s) (form attached) Analysis of Contemporaneous Emissions Increase/Decrease LAER Demonstration ( ____ / ____ / _____ ) BACT Demonstration ( ____ / ____ / _____ ) Other Document(s):

( / / )

( / / )

( / / )

( / / )


DEC ID

Supporting Documentation

( / / )

( / / )

( / / )

( / / )

( / / )

( / / )

( / / )

( / / )

( / / )

( / / )

4 1 2 3 6 0 0 7 0 8

Version 1.2 - 3/4/2015

- -


DEC ID

Methods Used to Determine ComplianceEmission Unit

IDCompliance

Date

Sheet _____ of _____Version 1 / /201

Applicable Requirement

Method Used to Determine Compliance

4 1 2 3 6 0 0 7 0 8

U00001U00002

40 CFR60.4320(a)

An initial compliance test will be performed after installationand annual stack testing will be performed after installationas required by the regulation for compliance with the NSPS

U00001U00002

40 CFR60.4365

The FERC gas tariff will be used to demonstratecompliance with this requirement

U00001U00002

6 NYCRR200.6

An initial compliance test will be performed after installationand annual stack testing will be performed following the NSPSrequirements to demonstrate compliance with the NOx limit.

- -

3/30/2015 Page 1 of 6

(4) Reserved.

(5) Gas turbines with a heat input at peak load less then 10 mmBtu/hour

(3)(ii)

Stationary or portable internal combustion engines that are liquid or gaseous fuel powered and located outside of the New York City metropolitan area or the Orange County towns of Blooming Grove, Chester, Highlands, Monroe, Tuxedo, Warwick, or Woodbury, and have a maximum mechanical power rating of less than 400 brake horsepower.

(3)(iii)Stationary or portable internal combustion engines that are gasoline powered and have a maximum mechanical power rating of less than 50 brake horsepower.

(3)(i)

Stationary or portable internal combustion engines that are liquid or gaseous fuel powered and located within the New York City metropolitan area or the Orange County towns of Blooming Grove, Chester, Highlands, Monroe, Tuxedo, Warwick, or Woodbury, and have a maximum mechanical power rating of less than 200 brake horsepower.

Combustion

Rule Citation


Number of

Activities

Building Location

(1)

Stationary or portable combustion installations where the furnace has a maximum heat input capacity less than 10 mmBtu/hr burning fuels other than coal or wood; or a maximum heat input capacity of less than 1 mmBtu/hr burning coal or wood. This activity does not include combustion installations burning any material classified as solid waste, as defined in 6 NYCRR Part 360, or waste oil, as defined in 6 NYCRR Subpart 225-2.


DEC ID

List of Exempt ActivitiesInstructions

Applicants for Title V facility permits must provide a listing of each exempt activity, as described in 6 NYCRR Part 201-3.2(c), that is currently operated at the facility. This form provides a means to fulfill this requirement.

In order to complete this form, enter the number and building location of each exempt activity. Building IDs used on this form should match those used in the Title V permit application. If a listed activity is not operated at the facility, leave the corresponding information blank.

(2)

Space heaters burning waste oil at automotive service facilities, as defined in 6 NYCRR Subpart 225-2, generated on-site or at a facility under common control, alone or in conjunction with used oil generated by a do-it-yourself oil changer as defined in 6 NYCRR Subpart 374-2.

4 1 2 3 6 0 0 7 0 8

2 NA

- -

3/30/2015 Page 2 of 6

Commercial - Graphic Arts

(12)Screen printing inks/coatings or adhesives which are applied by a hand-held squeegee. A hand-held squeegee is one that is not propelled though the use of mechanical conveyance and is not an integral part of the screen printing process.

(13)

Graphic arts processes at facilities located outside the New York City metropolitan area or the Orange County towns of Blooming Grove, Chester, Highlands, Monroe, Tuxedo, Warwick, or Woodbury whose facility-wide total emissions of volatile organic compounds from inks, coatings, adhesives, fountain solutions and cleaning solutions are less than three tons during any 12-month period.

Commercial - Food Service Industries

(10)Flour silos at bakeries, provided all such silos are exhausted through an appropriate emission control device.

(11)Emissions from flavorings added to a food product where such flavors are manually added to the product.

Agricultural

(8)

Feed and grain milling, cleaning, conveying, drying and storage operations including grain storage silos, where such silos exhaust to an appropriate emissions control device, excluding grain terminal elevators with permanent storage capacities over 2.5 million U.S. bushels, and grain storage elevators with capacities above one million bushels.

(9)Equipment used exclusively to slaughter animals, but not including other equipment at slaughterhouses, such as rendering cookers, boilers, heating plants, incinerators, and electrical power generating equipment.

(6)

Emergency power generating stationary internal combustion engines, as defined in 6 NYCRR Part 200.1(cq), and engine test cells at engine manufacturing facilities that are utilized for research and development, reliability performance testing, or quality assurance performance testing. Stationary internal combustion engines used for peak shaving and/or demand response programs are not exempt.

Combustion Related

(7)Non-contact water cooling towers and water treatment systems for process cooling water and other water containers designed to cool, store or otherwise handle water that has not been in direct contact with gaseous or liquid process streams.


DEC ID

Rule Citation


Number of

Activities

Building Location

g

4 1 2 3 6 0 0 7 0 8

2 NA

- -

(21)Distillate fuel oil, residual fuel oil, and liquid asphalt storage tanks with storage capacities below 300,000 barrels.

3/30/2015 Page 3 of 6

Municipal/Public Health Related

(20)

Landfill gas ventilating systems at landfills with design capacities less than 2.5 million megagrams (3.3 million tons) and 2.5 million cubic meters (2.75 million cubic yards), where the systems are vented directly to the atmosphere, and the ventilating system has been required by, and is operating under, the conditions of a valid 6 NYCRR Part 360 permit, or order on consent.

Storage Vessels

(18)Abrasive cleaning operations which exhaust to an appropriate emission control device.

(19) Ultraviolet curing operations.

Commercial - Other

(16)Gasoline dispensing sites registered with the department pursuant to 6 NYCRR Part 612.

(17)

Surface coating and related activities at facilities which use less than 25 gallons per month of total coating materials, or with actual volatile organic compound emissions of 1,000 pounds or less from coating materials in any 12-month period. Coating materials include all paints and paint components, other materials mixed with paints prior to application, and cleaning solvents, combined. This exemption is subject to the following:

(i) The facility is located outside of the New York City metropolitan area or the Orange County towns of Blooming Grove, Chester, Highlands, Monroe, Tuxedo, Warwick, or Woodbury; and

(ii) All abrasive cleaning and surface coating operations are performed in an enclosed building where such operations are exhausted into appropriate emission control devices.

(14)Graphic label and/or box labeling operations where the inks are applied by stamping or rolling.

(15)Graphic arts processes which are specifically exempted from regulation under 6 NYCRR Part 234, with respect to emissions of volatile organic compounds which are not given an A rating as described in 6 NYCRR Part 212.


DEC ID

Rule Citation


Number of

Activities

Building Location

age 3 o 6

4 1 2 3 6 0 0 7 0 8

- -

3/30/2015 Page 4 of 6

Industrial

(28)

Processing equipment at existing sand and gravel and stone crushing plants which were installed or constructed before August 31, 1983, where water is used for operations such as wet conveying, separating, and washing. This exemption does not include processing equipment at existing sand and gravel and stone crushing plants where water is used for dust suppression.

(29)(i)Sand and gravel processing or crushed stone processing lines at a non-metallic mineral processing facility that are a permanent or fixed installation with a maximum rated processing capacity of 25 tons of minerals per hour or less.

(26) Horizontal petroleum or volatile organic liquid storage tanks.

(27)Storage silos storing solid materials, provided all such silos are exhausted through an appropriate emission control device. This exemption does not include raw material, clinker, or finished product storage silos at Portland cement plants.

(24)

External floating roof tanks which are used for the storage of a petroleum or volatile organic liquid with a true vapor pressure less than 4.0 psi (27.6 kPa), are of welded construction and are equipped with one of the following:

(i) a metallic-type shoe seal;

(ii) a liquid-mounted foam seal;

(iii) a liquid-mounted liquid-filled type seal; or

(iv) equivalent control equipment or device.

(25)Storage tanks, including petroleum liquid storage tanks as defined in 6 NYCRR Part 229, with capacities less than 10,000 gallons, except those subject to 6 NYCRR Part 229 or Part 233.

Building Location

(22)Pressurized fixed roof tanks which are capable of maintaining a working pressure at all times to prevent emissions of volatile organic compounds to the outdoor atmosphere.

(23)External floating roof tanks which are of welded construction and are equipped with a metallic-type shoe primary seal and a secondary seal from the top of the shoe seal to the tank wall.


DEC ID

Rule Citation


Number of

Activities

g

4 1 2 3 6 0 0 7 0 8

2 NA

- -

39(ii)Cold cleaning degreasers that use a solvent with a VOC content or five percent or less by weight, unless subject to the requirements of 40 CFR 63 Subpart T.

3/30/2015 Page 5 of 6

(38)Cement storage operations not located at Portland cement plants where materials are transported by screw or bucket conveyors.

(39)(i)Cold cleaning degreasers with an open surface area of 11 square feet or less and an internal volume of 93 gallons or less or, having an organic solvent loss of 3 gallons per day or less.

(36)Presses used exclusively for molding or extruding plastics except where halogenated carbon compounds or hydrocarbon solvents are used as foaming agents.

(37)Concrete batch plants where the cement weigh hopper and all bulk storage silos are

exhausted through fabric filters, and the batch drop point is controlled by a shroud or other emission control device.

(34) Powder coating operations.

(35)All tumblers used for the cleaning and/or deburring of metal products without abrasive blasting.

(32) Pharmaceutical tablet branding operations.

(33)Thermal packaging operations, including, but not limited to, therimage labeling, blister packing, shrink wrapping, shrink banding, and carton gluing.

(30) Reserved.

(31)Surface coating operations which are specifically exempted from regulation under 6 NYCRR Part 228, with respect to emissions of volatile organic compounds which are not given an A rating pursuant to 6 NYCRR Part 212.

(29)(ii)Sand and gravel processing or crushed stone processing lines at a non-metallic mineral processing facility that are a portable emission source with a maximum rated processing capacity of 150 tons of minerals per hour or less.

(29)(iii)Sand and gravel processing or crushed stone processing lines at a non-metallic mineral processing facility that are used exclusively to screen minerals at a facility where no crushing or grinding takes place.


DEC ID

Rule Citation


Number of

Activities

Building Location

age 5 o 6

4 1 2 3 6 0 0 7 0 8

- -

(48) Manure spreading, handling and storage at farms and agricultural facilities.

3/30/2015 Page 6 of 6

(46) Hydrogen fuel cells.

(47)Dry cleaning equipment that uses only water-based cleaning processes or those using liquid carbon dioxide.

(44)Research and development activities, including both stand-alone and activities within a major facility, until such time as the administrator completes a rule making to determine how the permitting program should be structured for these activities.

(45) The application of odor counteractants and/or neutralizers.

(42)Exhaust systems for paint mixing, transfer, filling or sampling and/or paint storage rooms or cabinets, provided the paints stored within these locations are stored in closed containers when not in use.

(43)Exhaust systems for solvent transfer, filling or sampling, and/or solvent storage rooms provided the solvent stored within these locations are stored in containers when not in use.

Miscellaneous

(40)Ventilating and exhaust systems for laboratory operations. Laboratory operations do not include processes having a primary purpose to produce commercial quantities of materials.

(41)Exhaust or ventilating systems for the melting of gold, silver, platinum and other precious metals.

Building Location

(39)(iii)Conveyorized degreasers with an air/vapor interface smaller than 22 square feet (2 square meters), unless subject to the requirements of 40 CFR 63 Subpart T.

(39)(iv)Open-top vapor degreasers with an open-top area smaller than 11 square feet (1 square meter), unless subject to the requirements of 40 CFR 63 Subpart T.


DEC ID

Rule Citation


Number of

Activities

4 1 2 3 6 0 0 7 0 8

APPENDIX BEMISSION CALCULATIONS

AND VENDOR DATA

Mil

len

niu

m P

ipel

ine

Com

pan

y, L

LC

Han

cock

Com

pre

ssor

Sta

tion

Tab

le B

-1. E

xist

ing,

Pro

pos

ed P

roje

ct, a

nd

Tot

al F

acil

ity

Pot

enti

al E

mis

sion

s S

um

mar

y

NO

xC

OV

OC

SO

2P

M/P

M-1

0/

PM

-2.5

CO

2T

otal

HA

PS

CH

4N

2OC

O2e

Sola

r M

ars

100

34.2

447

.62

3.94

8.26

12.4

769

,427

.40.

611.

310.

1369

,499

Wau

kesh

a V

GF3

6 E

mer

genc

y E

ngin

e0.

971.

940.

490.

0011

0.02

218.

30.

130.

010.

001

219

Blo

wdo

wns

-0.

17-

0.01

0.09

32.1

40.

0080

4

-2.

27-

--

0.21

--

-T

otal

s (t

on/y

ear)

35.2

14

9.5

66

.87

8.2

612

.49

69

,64

5.7

1.0

433

.46

0.1

370

,521

NO

xC

OV

OC

SO

2P

M/P

M-1

0/

PM

-2.5

CO

2T

otal

HA

PS

CH

4N

2OC

O2e

Sola

r Ti

tan

130E

47.9

277

.28

5.45

4.51

12.1

094

,275

.32.

451.

780.

1894

,373

Wau

kesh

a V

GF4

8GL

Em

erge

ncy

Eng

ine

1.36

2.71

0.68

0.00

140.

0228

4.4

0.18

0.01

0.00

128

5Fu

el G

as H

eate

r0.

530.

440.

030.

0301

0.04

630.

60.

010.

010.

001

631

Lube

Oil

Tank

-0.

0017

--

--

--

Blo

wdo

wns

-0.

04-

0.02

-22

.92

-57

3-

-0.

88-

-0.

48-

560.

47-

14,0

12T

otal

s (t

on/y

ear)

49

.80

80

.44

7.0

84

.54

12.1

69

5,19

0.9

2.6

358

5.18

0.1

810

9,8

74

NO

xC

OV

OC

SO

2P

M/P

M-1

0/

PM

-2.5

CO

2T

otal

HA

PS

CH

4N

2OC

O2e

Exi

stin

g M

ars

100

and

Aux

iliar

y E

quip

men

t35

.21

49.5

66.

878.

2612

.49

69,6

45.7

1.04

33.4

60.

1370

,521

Prop

osed

Tit

an 1

30E

and

Aux

iliar

y E

quip

men

t49

.80

80.4

47.

084.

5412

.16

95,1

90.9

2.63

585.

180.

1810

9,87

4T

otal

s (t

on/y

ear)

85.

01

130

.00

13.9

512

.80

24.6

516

4,8

36.6

3.6

76

18.6

40

.31

180

,39

5

Exi

stin

g P

erm

itte

d S

ourc

es

Pro

pos

ed S

ourc

es

Tot

al F

acil

ity

Was

te L

iqui

ds S

tora

ge T

ank

Stat

ion

Fugi

tive

s

Mil

len

niu

m P

ipel

ine

Com

pan

y, L

LC

Han

cock

Com

pre

ssor

Sta

tion

Tab

le B

-2. S

olar

Tit

an 1

30E

Sp

ecif

icat

ion

s

Fuel

Nat

ural

Gas

NG

NG

NG

NG

NG

NG

NG

NG

NG

NG

NG

NG

NG

NG

NG

NG

NG

NG

NG

NG

NG

Load

50<

5050

5050

5050

5075

7575

7575

7575

100

100

100

100

100

100

100

Hp

Out

put (

Net

)11

,021

11,0

2111

,021

10,6

1910

,200

9,78

39,

092

8,23

316

,532

16,5

3215

,928

15,3

0014

,674

13,6

3712

,351

22,0

4322

,043

21,2

3720

,400

19,5

6518

,183

16,4

67

Am

bien

tTe

mpe

ratu

re (F

)be

low

00

020

4060

8010

0be

low

00

2040

6080

100

belo

w 0

020

4060

8010

0

% R

H60

6060

6060

6060

6060

6060

6060

6060

6060

6060

6060

60E

leva

tion

ft1,

695

1,69

51,

695

1,69

51,

695

1,69

51,

695

1,69

51,

695

1,69

51,

695

1,69

51,

695

1,69

51,

695

1,69

51,

695

1,69

51,

695

1,69

51,

695

1,69

5Fu

el L

HV

(Btu

/vol

ume)

920.

9092

0.9

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

920.

9092

0.90

Hea

t Inp

u LH

V(M

MB

tu/h

r) b

yvo

lum

e11

9.49

119.

4911

9.49

115.

7411

2.01

109.

0710

4.62

99.7

414

4.63

144.

6313

8.80

133.

2112

8.26

122.

2811

5.78

165.

5216

5.52

159.

0815

2.69

146.

5613

8.26

129.

52

Hea

t Inp

ut H

HV

(MM

Btu

/hr)

(=LH

V*1

.112

5)13

2.93

132.

9313

2.93

128.

7612

4.61

121.

3411

6.39

110.

9616

0.90

160.

9015

4.42

148.

2014

2.69

136.

0412

8.81

184.

1418

4.14

176.

9816

9.87

163.

0515

3.81

144.

09

Exh

aust

lb/h

r38

1,21

438

1,21

438

1,21

436

0,28

433

9,63

131

7,89

129

5,94

827

4,75

343

6,98

743

6,98

741

6,35

739

5,31

237

4,89

835

1,27

732

4,26

845

2,30

045

2,30

043

9,76

742

6,62

541

3,10

539

0,70

836

2,99

0E

xhau

st A

CFM

210,

923

210,

923

210,

923

203,

560

196,

008

185,

757

176,

718

168,

190

245,

134

245,

134

237,

017

228,

480

220,

831

211,

414

199,

477

263,

364

263,

364

257,

282

251,

130

244,

926

234,

978

222,

361

Stac

k H

eigh

t (ft

)70

7070

7070

7070

7070

7070

7070

7070

7070

7070

7070

70

Stac

k H

eigh

t (m

)21

.34

21.3

421

.34

21.3

421

.34

21.3

421

.34

21.3

421

.34

21.3

421

.34

21.3

421

.34

21.3

421

.34

21.3

421

.34

21.3

421

.34

21.3

421

.34

21.3

4

Squa

re S

tack

Sid

e(i

nche

s)10

210

210

210

210

210

210

210

210

210

210

210

210

210

210

210

210

210

210

210

210

210

2

Squa

re S

tack

Sid

e(f

t)2.

592.

592.

592.

592.

592.

592.

592.

592.

592.

592.

592.

592.

592.

592.

592.

592.

592.

592.

592.

592.

592.

59

Squa

re S

tack

Equ

ivD

iam

eter

(ft)

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

9.59

Squa

re S

tack

Exh

aust

(m/s

)14

.83

14.8

314

.83

14.3

113

.78

13.0

612

.43

11.8

317

.24

17.2

416

.66

16.0

615

.53

14.8

614

.03

18.5

218

.52

18.0

917

.66

17.2

216

.52

15.6

3

Exh

aust

M.W

.28

.55

28.5

528

.55

28.5

428

.51

28.4

728

.37

28.2

928

.55

28.5

528

.54

28.5

128

.47

28.3

728

.29

28.5

528

.55

28.5

428

.51

28.4

728

.37

28.2

9

Exh

aust

Tem

pera

ture

(F)

838

838

838

865

892

907

932

963

856

856

875

894

918

943

970

906

906

912

919

927

942

964

Exh

aust

Tem

pera

ture

(K)

720.

972

0.9

720.

973

5.9

750.

975

9.3

773.

279

0.4

730.

973

0.9

741.

575

2.0

765.

477

9.3

794.

375

8.7

758.

776

2.0

765.

977

0.4

778.

779

0.9

NO

Xpp

m@

15%

O2

120

7015

1515

1515

1512

015

1515

1515

1512

015

1515

1515

15

NO

Xlb

/hr

54.4

8031

.780

6.81

06.

590

6.37

06.

180

5.89

05.

550

67.5

208.

440

8.09

07.

750

7.44

07.

040

6.59

079

.600

9.95

09.

550

9.15

08.

750

8.20

07.

590

NO

Xg/

s6.

864

4.00

40.

858

0.83

00.

803

0.77

90.

742

0.69

98.

508

1.06

31.

019

0.97

70.

937

0.88

70.

830

10.0

301.

254

1.20

31.

153

1.10

31.

033

0.95

6

CO

ppm

@ 1

5% O

215

08,

000

2525

2525

2525

150

2525

2525

2525

150

2525

2525

2525

CO

lb/h

r41

.460

2211

.26.

910

6.69

06.

460

6.18

05.

890

5.55

051

.360

8.56

08.

210

7.87

07.

550

7.15

06.

690

60.5

4010

.090

9.69

09.

280

8.88

08.

320

7.70

0C

O g

/s5.

224

278.

611

0.87

10.

843

0.81

40.

779

0.74

20.

699

6.47

11.

079

1.03

40.

992

0.95

10.

901

0.84

37.

628

1.27

11.

221

1.16

91.

119

1.04

80.

970

UH

C p

pm@

15% O

250

800

2525

2525

2525

5025

2525

2525

2550

2525

2525

2525

UH

C lb

/hr

7.92

012

6.72

03.

960

3.83

03.

700

3.59

03.

420

3.22

09.

800

4.90

04.

700

4.51

04.

320

4.09

03.

830

11.5

605.

780

5.55

05.

320

5.09

04.

760

4.41

0

VO

C p

pm@

15%

O2

(20%

of U

HC

)10

160

55

55

55

105

55

55

510

55

55

55

VO

C lb

/hr

1.58

425

.344

0.79

20.

766

0.74

00.

718

0.68

40.

644

1.96

00.

980

0.94

00.

902

0.86

40.

818

0.76

62.

312

1.15

61.

110

1.06

41.

018

0.95

20.

882

sulfu

r gr

/100

scf

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

2.0

SO2

lb/h

r0.

743

0.74

30.

743

0.72

00.

697

0.67

80.

651

0.62

00.

899

0.89

90.

863

0.82

80.

798

0.76

00.

720

1.02

91.

029

0.98

90.

950

0.91

10.

860

0.80

5SO

2 g/

s0.

094

0.09

40.

094

0.09

10.

088

0.08

50.

082

0.07

80.

113

0.11

30.

109

0.10

40.

101

0.09

60.

091

0.13

00.

130

0.12

50.

120

0.11

50.

108

0.10

1Pa

rtic

ulat

eslb

/MM

Btu

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

0.01

50.

015

PM10

/2.5

lb/h

r1.

991.

991.

991.

931.

871.

821.

751.

662.

412.

412.

322.

222.

142.

041.

932.

762.

762.

652.

552.

452.

312.

16PM

10/2

.5g/

s0.

251

0.25

10.

251

0.24

30.

236

0.22

90.

220

0.21

00.

304

0.30

40.

292

0.28

00.

270

0.25

70.

243

0.34

80.

348

0.33

40.

321

0.30

80.

291

0.27

2C

O2

lb/m

mB

tu11

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

711

7C

O2

lb/h

r15

,538

15,5

3815

,538

15,0

5114

,566

14,1

8313

,605

12,9

7018

,808

18,8

0818

,049

17,3

2216

,679

15,9

0115

,056

21,5

2421

,524

20,6

8719

,856

19,0

5917

,979

16,8

43C

H4

lb/m

mB

tu0.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

220.

0022

0.00

22C

H4

lb/h

r0.

2931

0.29

310.

2931

0.28

390.

2747

0.26

750.

2566

0.24

460.

3547

0.35

470.

3404

0.32

670.

3146

0.29

990.

2840

0.40

600.

4060

0.39

020.

3745

0.35

950.

3391

0.31

77N

2O lb

/mm

Btu

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

0.00

020.

0002

N2O

lb/h

r0.

0293

0.02

930.

0293

0.02

840.

0275

0.02

680.

0257

0.02

450.

0355

0.03

550.

0340

0.03

270.

0315

0.03

000.

0284

0.04

060.

0406

0.03

900.

0374

0.03

590.

0339

0.03

18C

O2e

lb/m

mB

tu11

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

011

7.0

117.

0C

O2e

lb/h

r15

,554

15,5

5415

,554

15,0

6614

,581

14,1

9813

,619

12,9

8318

,827

18,8

2718

,068

17,3

4016

,696

15,9

1815

,071

21,5

4621

,546

20,7

0819

,876

19,0

7817

,998

16,8

60

Not

es1.

Dat

a pr

ovid

ed b

y So

lar

for

100%

, 75%

and

50%

load

cas

es: n

et o

utpu

t pow

er, f

uel f

low

(MM

Btu

/hr,

LH

V),

exh

aust

flow

(lb/

hr),

exh

aust

tem

pera

ture

, NO

X/C

O/U

HC

con

cent

rati

ons

and

lb/h

r.2.

Bel

ow z

ero

and

low

load

ope

rati

on u

ses

0ºF

for

oper

atin

g pa

ram

eter

s an

d us

es c

once

ntra

tion

s fr

om S

olar

PIL

167

.3.

Gre

enho

use

gase

s ar

e ca

lcul

ated

usi

ng e

mis

sion

fact

ors

from

Par

t 98,

Tab

les

C1

and

C2

and

glob

al w

arm

ing

pote

ntia

ls fr

om T

able

A1

(CO

2=

1, C

H4

= 2

5, N

2O =

298

).

Mil

len

niu

m P

ipel

ine

Com

pan

y, L

LC

Han

cock

Com

pre

ssor

Sta

tion

Tab

le B

-3. S

olar

Tit

an 1

30E

Pot

enti

al t

o E

mit

Op

erat

ion

sP

oten

tial

to

Em

it

Incl

ud

ing

Sta

rtu

p/S

hu

tdow

nd

uri

ng

Nor

mal

T

emp

erat

ure

Op

erat

ion

Max

imu

m Y

earl

y P

oten

tial

to

Em

it

Max

imu

mA

nn

ual

Com

bin

ed E

ven

t F

req

uen

cy

8,76

0 hr

s/yr

8,76

0 hr

s/yr

Pol

luta

nt

Hou

rly

(lb/

hr)

Max

imum

Ann

ual

(tpy

)

Eve

nt(l

b/ev

ent)

Max

imum

Ann

ual

(tpy

)

Eve

nt(l

b/ev

ent)

Max

imum

Ann

ual

(tpy

)

Max

imum

Ann

ual

(tpy

)H

ourl

y(l

b/hr

)M

axim

umA

nnua

l(t

py)

Hou

rly

(lb/

hr)

Max

imum

Ann

ual

(tpy

)

Max

imum

Ann

ual

(tpy

)

NO

X9.

9543

.58

1.90

0.10

2.40

0.12

43.6

379

.60

4.78

31.7

80.

1647

.92

CO

10.0

944

.19

176.

908.

8520

7.60

10.3

863

.25

60.5

43.

632,

211.

2011

.06

77.2

8SO

21.

034.

510

00

04.

511.

030.

060.

740.

004

4.51

PM10

/2.5

2.76

12.1

00

00

012

.10

2.76

0.1 7

1.99

0.01

12.1

0C

O2e

21,5

4694

,373

00

00

94,3

7321

,546

1,29

315

,554

7894

,373

CO

221

,524

94,2

750

00

094

,275

21,5

241,

291

15,5

3878

94,2

75N

2O0.

040.

180

00

00.

180.

040.

002

0.03

0.00

010.

18TO

C (T

otal

)5.

7825

.32

10.1

00.

5111

.90

0.60

26.3

211

.56

0.69

126.

720.

6327

.27

CH

40.

411.

780

00

01.

780.

410.

020.

290.

001

1.78

VO

C (T

otal

)1.

165.

062.

020.

102.

380.

125.

262.

310.

1425

.34

0.13

5.45

Low

Loa

d O

per

atio

n (

<50

%)

10 h

rs/y

r8,

760

hrs/

yr10

0 E

vent

s/Yr

(1

0 M

inut

e E

vent

Dur

atio

n)10

0 E

vent

s/Ye

ar(1

0 M

inut

e E

vent

Dur

atio

n)12

0 hr

s/yr

Nor

mal

Am

bie

nt

Tem

per

atu

res

(>

0 d

egre

es F

)

Sta

rtu

pS

hu

tdow

nL

ow A

mbi

ent

Tem

per

atu

res

(<

0 d

egre

es F

)

Mil

len

niu

m P

ipel

ine

Com

pan

y, L

LC

Han

cock

Com

pre

ssor

Sta

tion

Tab

le B

-4.

Au

xili

ary

Gen

erat

or P

oten

tial

Em

issi

ons

Su

mm

ary

(Wau

kesh

a V

GF

48

GL

)

En

gin

e p

aram

eter

sPo

wer

out

put b

ase

load

1,23

0hp

Hea

t Inp

ut C

apac

ity

(HH

V)

9.72

6M

MB

tu/h

rM

axim

um A

nnua

l Ope

rati

on50

0hr

/yr

Pol

luta

nt

g/b

hp

-hr1

lb/M

MB

tu2

lb/h

rT

otal

An

nu

al

(ton

/yr)

3

NO

x2.

005.

421.

36C

O

4.00

10.8

52.

71V

OC

1.00

2.71

0.68

PM10

/2.5

0.00

999

0.10

0.02

4SO

25.

88E

-04

0.00

60.

0014

CO

2e11

7.10

1138

.912

284.

73C

O2

116.

9800

1137

.738

284.

43C

H4

0.00

220.

021

0.01

N2O

0.00

020.

002

0.00

1N

otes

:

2 Em

issi

ons

for

PM10

/PM

2.5

and

SO2

calc

ulat

ed u

sing

AP-

42 e

mis

sion

fact

ors

(Tab

le 3

.2-2

).

Em

issi

on fo

r G

HG

s ba

sed

upon

40

CFR

Par

t 98,

Sub

part

C

Pot

enti

al E

mis

sion

s

1 NO

x, C

O, V

OC

bas

ed o

n N

SPS

Subp

art J

JJJ,

Tab

le 1

3 Aux

iliar

y G

ener

ator

is L

imit

ed to

500

hou

rs /

yea

r.

Millennium Pipeline Company, LLCHancock Compressor Station

Table B-5. Gas-Fired Heater Potential Emissions Summary

Engine parametersHeat Input Capacity (HHV) 1.23 MMBtu/hrFuel Firing Rate 1,201 SCF/hrMaximum Annual Operation 8,760 hr/yr

Pollutant lb/mmscf lb/hrTotal Annual

(ton/yr)

NOx 100 0.12 0.53CO 84 0.10 0.44VOC 5.5 0.007 0.03PM/PM-10/PM-2.5 7.6 0.01 0.04SO2

(2) 5.71 0.0069 0.03CO2e 119,970 144.12 631.26CO2 119,846 143.98 630.61CH4 2.26 0.0027 0.01N2O 0.23 0.00027 0.0012

(1) NOx, CO, VOC and PM emissions are based upon AP-42 Emission Factors (2) Emissions of SO2 from based on mass balance of sulfur in fuel:

Sulfur Content 2.0 grains/100 SCFHigher Heating Value 1,025 Btu/SCF

Molecular Weight of S = 32 lb/lbmolMolecular Weight of SO2 = 64 lb/lbmol

(3) GHG Emissions are based upon 40 CFR Part 98, Subpart C

Potential Emissions


Table B-6. Fugitive Blowdowns Potential Emissions Summary




Molecular Weight 16.35Btu/Scf 1024.5Specific Gravity 0.566lb/Scf 0.0433Scf/lb 23.10

BuildingShutdown

Emergency StationShutdown

Gas Blowdown (scf/event) 49,000 454,057Blowdowns per Year 4 2

VOC Emissions (lb/event) 3.2 29.5CO2 Emissions (lb/event) 1.8 16.4CH4 Emissions (lb/event) 2,034.0 18,847.7CO2e Emissions (lb/event) 50,851.1 471,209.7

VOC Emissions (tpy) 0.0064 0.0295CO2 Emissions (tpy) 0.0035 0.0164CH4 Emissions (tpy) 4.1 18.8CO2e Emissions (tpy) 101.7 471.2

Blowdown Events

Parameter

Natural Gas Properties


Table B-7. Waste Liquids Tank Potential Emissions Summary

Capacity (gal) 4,000 4,000Liquids Input Rate (gal/yr) 4,000 667 (gal/hr)

Flash Gas Density (lb/scf) 0.1107 0.1107

Flash Factor (scf/bbl) 640.3 629.71Flash Gas Rate (scf/yr) 60,980.95 10,000.39 (scf/hr)Flash Losses (lb/yr) 6,750.59 Maximum 1,107.04 MaximumIndividual Constituents Weight

Percentage (%)Annual

Emissions(tpy)

WeightPercentage (%)

HourlyEmissions

(lb/hr)VOC (Total) 67.38 2.274 67.38 745.93HAP (Total) 6.17 0.208 6.17 68.30Benzene 0.7598 0.026 0.7598 8.41Ethylbenzene 0.047 0.002 0.047 0.52Hexane (n ) 1.6563 0.056 1.6563 18.34Toluene 2.4744 0.084 2.4744 27.39Trimethylpentane (2,2,4 )

0.2072 0.007 0.2072 2.29Xylenes 1.0253 0.035 1.0253 11.35Notes:Liquid input rates:a. maximum hourly based on the minimum of vessel capacity or maximum annual throughput divided by 6;b. maximum annual based on operating experience and safety factor; andc. average hourly is the maximum annual divided by 8,760 hrs/yr.

Flash gas density is 110% of the value extracted from laboratory analysis results.Laboratory Density:Flash factor extracted from laboratory analysis results:0.1006 lb/scf Safety Factor: 110%Speciated emissions vapor weight percentages caculated from laboratory analysis results.


Table B-8. Potential Fugitive Emissions Summary

CH4 Emission Factor¹,²

CO2 Emission Factor¹,²

Compressor Station Fugitives 135,260.0 7,813.1Centrifugal Compressor Fugitives 467,660.0 27,013.7

2Based on 93.4 vol% CH4 and 2 vol% CO2 in natural gas, per INGAA Guideline




Segment CO Emissions3

(tpy) CH4

Emissions3

(tpy)

CO eEmissions3,4

(tpy)

VOCEmissions3

(tpy)

Compressor Station Fugitives 0.06 70.8 1,770.4 0.1Mars 100 Fugitives 0.2 244.8 6,121.0 0.4Titan 130E Fugitives 0.2 244.8 6,121.0 0.4Total 0.5 560.5 14,012.3 0.9

3Based upon natural gas specfications and INGAA factors above.4Calculated using global warming potentials from Part 98, Table A 1 (CO2 = 1, CH4 = 25)

1Greenhouse Gas Emission Estimation Guidelines for Natural Gas Transmission and Storage, Volume 1 - GHG Emission Estimation Methodologies and Procedures, Interstate Natural Gas Association of America, September 28, 2005. See Table 4.4.

Component Units

lb/station-yrlb/compressor-yr

Mil

len

niu

m P

ipel

ine

Com

pan

y, L

LC

Han

cock

Com

pre

ssor

Sta

tion

Tab

le B

-9.

Pro

pos

ed P

roje

ct P

oten

tial

HA

P E

mis

sion

s S

um

mar

y

Em

issi

on F

acto

rM

ax H

ourl

yA

nn

ual

Pot

enti

alE

mis

sion

Fac

tor

Max

An

nu

alP

oten

tial

EF

Max

An

nu

alP

oten

tial

Pro

ject

Bas

is(1

)B

asis

(2)

Hou

rly

Bas

is(3

)H

ourl

yP

TE

Haz

ard

ous

Air

Pol

luta

nts

(H

AP

s)lb

/MM

Btu

lb/h

rto

ns/

year

lb/M

MB

tulb

/hr

ton

s/ye

arlb

/MM

Btu

lb/h

rto

ns/

year

ton

s/yr

Ace

tald

ehyd

e1.

18E

-04

2.17

E-0

29.

52E

-02

8.36

E-0

38.

13E

-02

2.03

E-0

21.

16E

-01

Acr

olei

n1.

89E

-05

3.48

E-0

31.

52E

-02

5.14

E-0

35.

00E

-02

1.25

E-0

22.

77E

-02

Ben

zene

3.54

E-0

56.

52E

-03

2.86

E-0

22.

06E

-06

2.53

E-0

61.

11E

-05

4.40

E-0

44.

28E

-03

1.07

E-0

32.

97E

-02

1,3-

But

adie

ne1.

27E

-06

2.34

E-0

41.

02E

-03

2.67

E-0

42.

60E

-03

6.49

E-0

41.

67E

-03

Car

bon

Tetr

achl

orid

e0.

00E

+00

0.00

E+

003.

67E

-05

3.57

E-0

48.

92E

-05

8.92

E-0

5C

hlor

oben

zene

0.00

E+

000.

00E

+00

3.04

E-0

52.

96E

-04

7.39

E-0

57.

39E

-05

Chl

orof

orm

0.00

E+

000.

00E

+00

2.85

E-0

52.

77E

-04

6.93

E-0

56.

93E

-05

Dic

hlor

oben

zene

0.00

E+

000.

00E

+00

1.18

E-0

61.

45E

-06

6.34

E-0

66.

34E

-06

1,3-

Dic

hlor

opro

pene

0.00

E+

000.

00E

+00

2.64

E-0

52.

57E

-04

6.42

E-0

56.

42E

-05

Eth

ylbe

nzen

e9.

45E

-05

1.74

E-0

27.

62E

-02

3.97

E-0

53.

86E

-04

9.65

E-0

57.

63E

-02

Eth

ylen

e D

ibro

mid

e0.

00E

+00

0.00

E+

004.

43E

-05

4.31

E-0

41.

08E

-04

1.08

E-0

4Fo

rmal

dehy

de

2.10

E-0

33.

86E

-01

1.69

E+

007.

35E

-05

9.05

E-0

53.

96E

-04

5.28

E-0

25.

14E

-01

1.28

E-0

11.

82E

+00

Hex

ane

0.00

E+

000.

00E

+00

1.76

E-0

32.

17E

-03

9.51

E-0

31.

11E

-03

1.08

E-0

22.

70E

-03

1.22

E-0

2M

etha

nol

0.00

E+

000.

00E

+00

2.50

E-0

32.

43E

-02

6.08

E-0

36.

08E

-03

Met

hyle

ne C

hlor

ide

0.00

E+

000.

00E

+00

2.00

E-0

51.

95E

-04

4.86

E-0

54.

86E

-05

Nap

htha

lene

3.84

E-0

67.

07E

-04

3.10

E-0

35.

98E

-07

7.36

E-0

73.

22E

-06

7.44

E-0

57.

24E

-04

1.81

E-0

43.

28E

-03

PAH

6.50

E-0

61.

20E

-03

5.24

E-0

32.

69E

-05

2.62

E-0

46.

54E

-05

5.30

E-0

3Pr

opyl

ene

Oxi

de8.

56E

-05

1.58

E-0

26.

91E

-02

6.91

E-0

21,

1,2,

2-Te

trac

hlor

oeth

ane

0.00

E+

000.

00E

+00

4.00

E-0

53.

89E

-04

9.73

E-0

59.

73E

-05

1,1,

2-Tr

ichl

oroe

than

e0.

00E

+00

0.00

E+

003.

18E

-05

3.09

E-0

47.

73E

-05

7.73

E-0

52,

2,4

Trim

ethy

lpen

tane

0.00

E+

000.

00E

+00

2.50

E-0

42.

43E

-03

6.08

E-0

46.

08E

-04

Tolu

ene

3.84

E-0

47.

07E

-02

3.10

E-0

13.

33E

-06

4.10

E-0

61.

80E

-05

4.08

E-0

43.

97E

-03

9.92

E-0

43.

11E

-01

Vin

yl C

hlor

ide

0.00

E+

000.

00E

+00

1.49

E-0

51.

45E

-04

3.62

E-0

53.

62E

-05

Xyl

enes

1.89

E-0

43.

48E

-02

1.52

E-0

11.

84E

-04

1.79

E-0

34.

47E

-04

1.53

E-0

1

Ace

naph

then

e1.

76E

-09

3.25

E-0

71.

42E

-06

1.76

E-0

92.

17E

-09

9.51

E-0

91.

25E

-06

1.22

E-0

53.

04E

-06

4.47

E-0

6A

cena

phth

ylen

e1.

76E

-09

3.25

E-0

71.

42E

-06

1.76

E-0

92.

17E

-09

9.51

E-0

95.

53E

-06

5.38

E-0

51.

34E

-05

1.49

E-0

5A

nthr

acen

e2.

35E

-09

4.33

E-0

71.

90E

-06

2.35

E-0

92.

90E

-09

1.27

E-0

81.

91E

-06

Ben

z(a)

anth

race

ne1.

76E

-09

3.25

E-0

71.

42E

-06

1.76

E-0

92.

17E

-09

9.51

E-0

91.

43E

-06

Ben

zo(a

)pyr

ene

1.18

E-0

92.

17E

-07

9.49

E-0

71.

18E

-09

1.45

E-0

96.

34E

-09

4.15

E-0

74.

04E

-06

1.01

E-0

61.

96E

-06

Ben

zo(b

)flu

oran

then

e1.

76E

-09

3.25

E-0

71.

42E

-06

1.76

E-0

92.

17E

-09

9.51

E-0

91.

66E

-07

1.61

E-0

64.

04E

-07

1.84

E-0

6B

enzo

(g,h

,i)pe

ryle

ne1.

18E

-09

2.17

E-0

79.

49E

-07

1.18

E-0

91.

45E

-09

6.34

E-0

94.

14E

-07

4.03

E-0

61.

01E

-06

1.96

E-0

6B

enzo

(k)f

luor

anth

ene

1.76

E-0

93.

25E

-07

1.42

E-0

61.

76E

-09

2.17

E-0

99.

51E

-09

1.66

E-0

71.

61E

-06

4.04

E-0

71.

84E

-06

Bip

heny

l2.

12E

-04

2.06

E-0

35.

15E

-04

5.15

E-0

4C

hrys

ene

1.76

E-0

93.

25E

-07

1.42

E-0

61.

76E

-09

2.17

E-0

99.

51E

-09

6.93

E-0

76.

74E

-06

1.69

E-0

63.

12E

-06

Dib

enzo

(a,h

)ant

hrac

ene

1.18

E-0

92.

17E

-07

9.49

E-0

71.

18E

-09

1.45

E-0

96.

34E

-09

9.55

E-0

77,

12-D

imet

hylb

enz(

a)an

thra

cene

1.57

E-0

82.

89E

-06

1.27

E-0

51.

57E

-08

1.93

E-0

88.

46E

-08

1.27

E-0

5Fl

uora

nthe

ne2.

94E

-09

5.42

E-0

72.

37E

-06

2.94

E-0

93.

62E

-09

1.59

E-0

81.

11E

-06

1.08

E-0

52.

70E

-06

5.09

E-0

6Fl

uore

ne2.

75E

-09

5.05

E-0

72.

21E

-06

2.75

E-0

93.

38E

-09

1.48

E-0

85.

67E

-06

5.51

E-0

51.

38E

-05

1.60

E-0

53-

Met

hylc

hlor

anth

rene

1.76

E-0

93.

25E

-07

1.42

E-0

61.

76E

-09

2.17

E-0

99.

51E

-09

1.43

E-0

62-

Met

hyln

apht

hale

ne2.

35E

-08

4.33

E-0

61.

90E

-05

2.35

E-0

82.

90E

-08

1.27

E-0

73.

32E

-05

3.23

E-0

48.

07E

-05

9.98

E-0

5In

deno

(1,2

,3-c

d)py

rene

1.76

E-0

93.

25E

-07

1.42

E-0

61.

76E

-09

2.17

E-0

99.

51E

-09

1.43

E-0

6Ph

enan

thre

ne1.

67E

-08

3.07

E-0

61.

34E

-05

1.67

E-0

82.

05E

-08

8.98

E-0

81.

04E

-05

1.01

E-0

42.

53E

-05

3.88

E-0

5Ph

enol

2.40

E-0

52.

33E

-04

5.84

E-0

55.

84E

-05

Pyre

ne4.

90E

-09

9.03

E-0

73.

95E

-06

4.90

E-0

96.

03E

-09

2.64

E-0

81.

36E

-06

1.32

E-0

53.

31E

-06

7.29

E-0

6St

yren

e2.

36E

-05

2.30

E-0

45.

74E

-05

5.74

E-0

5To

tal P

OM

8.65

E-0

81.

59E

-05

6.97

E-0

58.

65E

-08

1.06

E-0

74.

66E

-07

3.20

E-0

43.

11E

-03

7.78

E-0

48.

48E

-04

Tot

al H

AP

s2.

450.

010.

182.

63M

axim

um

In

div

idu

al H

AP

:1.

8T

otal

Pro

ject

HA

Ps:

2.6

(1) E

mis

sion

s ba

sed

on A

P-42

5th

Edi

tion

, Sec

tion

3.1

. E

mis

sion

s ba

sed

on s

calin

g of

AP-

42 v

alue

s us

ing

Ven

dor

Gua

rant

ee fo

r TO

C(2

) Em

issi

ons

base

d on

AP-

42 5

th E

diti

on, S

ecti

on 1

.4.

(3) E

mis

sion

s ba

sed

on A

P-42

5th

Edi

tion

, Sec

tion

3.2

.

Fu

el G

as H

eate

rA

uxi

liar

y G

ener

ator

Pol

ycyc

lic

Org

anic

Com

pou

nd

s (P

OM

)

VO

C-H

AP

Sol

ar T

itan

130

E


Customer


Hancock

Inquiry Number

HO15-0146

Run By Date Run


Engine Model

TITAN 130-22402S

CS/MD 59F MATCH


CHOICE GAS NO


REV. 0.0



15.00 25.00 25.00 PPMvd at 15% O2

29.82 30.26 17.33 ton/yr


0.83 0.84 0.48 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

28.87 29.29 16.78 ton/yr


0.83 0.84 0.48 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

27.90 28.31 16.21 ton/yr


0.84 0.85 0.49 lbm/(MW-hr)


Notes








Customer


Hancock

Inquiry Number

HO15-0146

Run By Date Run


Engine Model

TITAN 130-22402S

CS/MD 59F MATCH


CHOICE GAS NO


REV. 0.0



15.00 25.00 25.00 PPMvd at 15% O2

27.07 27.47 15.73 ton/yr


0.85 0.86 0.49 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

25.80 26.18 14.99 ton/yr


0.87 0.88 0.50 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

24.30 24.66 14.12 ton/yr


0.90 0.92 0.53 lbm/(MW-hr)


Notes








Customer


Hancock

Run By Date Run



REV. 4.17.1.19.11 REV. 0.0

Model


CS/MD Match


GAS Fuel Type

CHOICE GAS


Elevation feet 1695




1 2 3 4 5 6








Therm Eff % 23.469 23.345 23.171 22.822 22.112 21.004





Methane (CH4) 97.79

Ethane (C2H6) 1.88

Propane (C3H8) 0.05

N-Butane (C4H10) 0.0020


Nitrogen (N2) 0.24





Customer


Hancock

Inquiry Number

HO15-0146

Run By Date Run


Engine Model

TITAN 130-22402S

CS/MD 59F MATCH


CHOICE GAS NO


REV. 0.0



15.00 25.00 25.00 PPMvd at 15% O2

36.96 37.50 21.48 ton/yr


0.68 0.69 0.40 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

35.44 35.96 20.60 ton/yr


0.68 0.69 0.40 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

33.96 34.46 19.74 ton/yr


0.68 0.69 0.39 lbm/(MW-hr)


Notes








Customer


Hancock

Inquiry Number

HO15-0146

Run By Date Run


Engine Model

TITAN 130-22402S

CS/MD 59F MATCH


CHOICE GAS NO


REV. 0.0



15.00 25.00 25.00 PPMvd at 15% O2

32.58 33.06 18.93 ton/yr


0.68 0.69 0.40 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

30.85 31.31 17.93 ton/yr


0.69 0.70 0.40 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

28.86 29.28 16.77 ton/yr


0.72 0.73 0.42 lbm/(MW-hr)


Notes








Customer


Hancock

Run By Date Run



REV. 4.17.1.19.11 REV. 0.0

Model


CS/MD Match


GAS Fuel Type

CHOICE GAS


Elevation feet 1695




1 2 3 4 5 6








Therm Eff % 29.084 29.198 29.224 29.111 28.377 27.142





Methane (CH4) 97.79

Ethane (C2H6) 1.88

Propane (C3H8) 0.05

N-Butane (C4H10) 0.0020


Nitrogen (N2) 0.24





Customer


Hancock

Inquiry Number

HO15-0146

Run By Date Run


Engine Model

TITAN 130-22402S

CS/MD 59F MATCH


CHOICE GAS NO


REV. 0.0



15.00 25.00 25.00 PPMvd at 15% O2

43.57 44.21 25.32 ton/yr


0.61 0.61 0.35 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

41.83 42.45 24.31 ton/yr


0.60 0.61 0.35 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

40.08 40.66 23.29 ton/yr


0.60 0.61 0.35 lbm/(MW-hr)


Notes








Customer


Hancock

Inquiry Number

HO15-0146

Run By Date Run


Engine Model

TITAN 130-22402S

CS/MD 59F MATCH


CHOICE GAS NO


REV. 0.0



15.00 25.00 25.00 PPMvd at 15% O2

38.32 38.89 22.27 ton/yr


0.60 0.61 0.35 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

35.91 36.43 20.87 ton/yr


0.60 0.61 0.35 lbm/(MW-hr)



15.00 25.00 25.00 PPMvd at 15% O2

33.22 33.71 19.31 ton/yr


0.62 0.63 0.36 lbm/(MW-hr)


Notes








Customer


Hancock

Run By Date Run



REV. 4.17.1.19.11 REV. 0.0

Model


CS/MD Match


GAS Fuel Type

CHOICE GAS


Elevation feet 1695




1 2 3 4 5 6




Specified Load HP FULL FULL FULL FULL FULL FULL




Therm Eff % 33.885 33.968 33.995 33.966 33.462 32.350





Methane (CH4) 97.79

Ethane (C2H6) 1.88

Propane (C3H8) 0.05

N-Butane (C4H10) 0.0020


Nitrogen (N2) 0.24





SoLoNOx Products:Emissions in Non-SoLoNOx Modes


PURPOSESolar’s gas turbine dry low NOx emissions combustion systems, known as SoLoNOx™,have been developed to provide the lowest emissions possible during normal operating conditions. In order to optimize the performance of the turbine, the combustion and fuel systems are designed to reduce NOx, CO and unburned hydrocarbons (UHC) without penalizing stability or transient capabilities. At very low load and cold temperature extremes, the SoLoNOx system must be controlled differently in order to assure stable operation. The required adjustments to the turbine controls at these conditions cause emissions to increase.

The purpose of this Product Information Letter is to provide emissions estimates, and in some cases warrantable emissions for NOx, CO and UHC, at off-design conditions.

Historically, regulatory agencies have not required a specific emissions level to be met at low load or cold ambient operating conditions, but have asked what emissions levels are expected. The expected values are necessary to appropriately estimate emissions for annual emissions inventory purposes and for New Source Review applicability determinations, air dispersion modeling, and permitting.

COLD AMBIENT EMISSIONS ESTIMATESSolar’s standard temperature range warranty for gas turbines with SoLoNOx combustion is

0°F (–20°C). The Titan™ 250 is an exception, with a lower standard warranty at–20°F (–29°C). At ambient temperatures below 0°F, many of Solar’s turbine engine

models are controlled to increase pilot fuel which improves flame stability but leads to higher emissions. Without the increase in pilot fuel at temperatures below 0°F the engines may exhibit combustor rumble, as operation may be near the lean stability limit.

If a cold ambient emissions warranty is requested, a new production turbine configured with the latest combustion hardware is required. For most models this refers to the inclusion of “Cold Ambient Fuel Control Logic”. A cold ambient emissions warranty is only available on gas turbines being fired on natural gas and not offered for ambient temperatures below –20°F (–29°C). In general, standard natural gas as defined in ES9-98 is required to offer a cold ambient warranty, but non-standard fuels on a project basis can be reviewed by Solar to determine applicability. In addition, cold ambient emissions warranties cannot be offered for the Centaur® 40 turbine. Note that a cold ambient warranty cannot be offered for liquid fuel operation at this time.

Table 1 provides expected and warrantable (upon Solar’s documented approval) emissionslevels for Solar’s SoLoNOx combustion turbines. All emissions levels are in ppm at 15% O2. Refer to Product Information Letter 205 for Mercury™ 50 turbine emissions estimates.

For information on the availability and approvals for cold ambient temperature emissions warranties, please contact Solar’s sales representatives.





1


Table 1. Warrantable Emissions Between 0°F and –20°F (–20° to –29°C) for New Production (NOx ppm values corrected to 15% O2.)

Turbine Model


LoadNOx, ppm

CO, ppm

UHC, ppm



Taurus™ 60 Gas Only or Dual Fuel Gas 50 to 100% load 42 100 50



Mars® 90 Gas Only Gas 50 to 100% load 42 100 50



Titan 250Gas Only Gas 40 to 100% load 25 50 25

Gas Only Gas 40 to 100% load 15 25 25

Table 2 summarizes “expected” emissions levels for ambient temperatures below 0°F (–20°C) for Solar’s SoLoNOx turbines that do not have current production hardware or for new production hardware that is not equipped with the Cold Ambient Fuel Control Logic.The emissions levels are extrapolated from San Diego factory tests and may vary at extreme temperatures and as a result of variations in other parameters, such as fuel composition, fuel quality, etc.

For more conservative NOx emissions estimate on new equipment, customers can refer to the New Source Performance Standard (NSPS) 40CFR60, subpart KKKK, where the allowable NOx emissions level for ambient temperatures < 0°F (–20°C) is 150 ppm NOx at 15% O2. For pre-February 18, 2005, SoLoNOx combustion turbines subject to 40CFR60 subpart GG, a conservative estimate is the appropriate subpart GG emissions level. Subpart GG levels range from 150 to 214 ppm NOx at 15% O2 on natural gas (and 150-210 on liquid fuel) depending on the turbine model.

Table 2. Expected Emissions below 0°F (–20°C) for SoLoNOx Combustion Turbines (NOx ppm values corrected to 15% O2.)

Turbine Model


LoadNOx, ppm

CO, ppm

UHC, ppm

Centaur 40 Gas Only or Dual Fuel Gas 80 to 100% load 120 150 50






Mars 90 Gas Only Gas 80 to 100% load 120 150 50







Mars 100 Dual Fuel Liquid 65 to 100% load 150 150 75

Titan 130 Dual Fuel Liquid 65 to 100% load 150 150 75




2


Table 3 summarizes “expected” emissions levels for ambient temperatures below –20°F (–29°C) for the Titan 250.

Table 3. Expected Emissions below –20°F (–29°C) for the Titan 250 SoLoNOx Combustion Turbine (NOx ppm values corrected to 15% O2.)

Turbine Model


LoadNOx, ppm

CO, ppm

UHC, ppm

Titan 250 Gas Only Gas 40 to 100% load 70 150 50

COLD AMBIENT PERMITTING STRATEGYThere are several permitting options to consider when permitting in cold ambient climates. Customers can use a tiered permitting approach or choose to permit a single emission rate over all temperatures. Some customers have used a tiered permitting strategy. For purposes of compliance and annual emissions inventories, a digital thermometer is installed to record ambient temperature. The amount of time is recorded

that the ambient temperature falls below 0 F. The amount of time below 0°F is then used with the emissions estimates shown in Tables 1 and 2 to estimate “actual” emissions during sub-zero operation.

A conservative alternative to using the NOx values in Tables 1, 2 and 3 is to reference 40CFR60 subpart KKKK, which allows 150 ppm NOx at 15% O2 for sub-zero operation.

For customers who wish to permit at a single emission rate over all ambient temperatures, inlet air heating can be used to raise the engine inlet air temperature (T1)above 0°F. With inlet air heating to keep T1 above 0°F, standard emission warranty levels may be offered.

Inlet air heating technology options include an electric resistance heater, an inlet air to exhaust heat exchanger and a glycol heat exchanger.

If an emissions warranty is desired, and ambient temperatures are commonly below –20°F (–29°C), inlet air heating can be used to raise the turbine inlet temperature (T1) to at least –20°F. In such cases, the values shown in Table 1 can be warranted for new production natural gas fired turbine.

EMISSIONS ESTIMATES IN NON-SOLONOX MODE (LOW LOAD)At operating loads < 50% (<40% load for the Titan 250) on natural gas fuel and < 65%(< 80% load for Centaur 40) on liquid fuels, SoLoNOx engines are controlled to increase stability and transient response capability. The control steps that are required affect emissions in two ways: 1) pilot fuel flow is increased, increasing NOx emissions, and 2) airflow through the combustor is increased, increasing CO emissions. Note that the load levels are approximate. Engine controls are triggered either by power output for single-shaft engines or gas producer speed for two-shaft engines.

A conservative method for estimating emissions of NOx at low loads is to use the applicable NSPS: 40CFR60 subpart GG or KKKK. For projects that commence construction after February 18, 2005, subpart KKKK is the applicable NSPS and contains a NOx level of 150 ppm @ 15% O2 for operating loads less than 75%.

Table 4 provides estimates of NOx, CO, and UHC emissions when operating in non-SoLoNOx mode for natural gas or liquid fuel. The estimated emissions can be assumed to vary linearly as load is decreased from just below 50% load for natural gas (or 65% load for liquid fuel) to idle.




3


The estimates in Table 4 apply for any product for gas only or dual fuel systems using pipeline quality natural gas. Refer to Product Information Letter 205 for Mercury 50 emissions estimates.

Table 4. Estimated Emissions in non-SoLoNOx Mode(NOx ppm values corrected to 15% O2.)

Ambient Fuel System Engine Load NOx, ppm CO, ppm UHC, ppm

Centaur 40/50, Taurus 60/65/70, Mars 90/100, Titan 130

–20°F (–29°C) Natural GasLess than 50% 70 8,000 800

Idle 50 10,000 1,000

< –20°F (–29°C) Natural GasLess than 50% 120 8,000 800

Idle 120 10,000 1,000

Titan 250

–20°F (–29°C) Natural GasLess than 40% 50 25 20

Idle 50 2,000 200

< –20°F (–29°C) Natural GasLess than 40% 70 150 50

Idle 70 2,000 200

Centaur 50, Taurus 60/70, Mars 100, Titan 130


Idle 150 10,000 3,000


Idle 150 10,000 3,000

Centaur 40


Idle 150 10,000 3,000


Idle 150 10,000 3,000


Caterpillar is a registered trademark of Caterpillar Inc. Solar, Centaur, Taurus, Mars, Titan and SoLoNOx are trademarks of Solar Turbines Incorporated. All other trademarks are the intellectual property of their respective companies. Specifications are subject to change without notice.

© 2015 Solar Turbines Incorporated. All rights reserved. Specifications are subject to change without notice.




4


1

Volatile Organic Compound, Sulfur Dioxide,and Formaldehyde Emission Estimates


PURPOSEThis Product Information Letter summarizes methods that are available to estimate emissions of volatile organic compounds (VOC), sulfur dioxide (SO2), and formaldehyde from gas turbines. Emissions esti-mates of these pollutants are often necessary during the air permitting process.

INTRODUCTIONIn absence of site-specific or representative source test data, Solar refers customers to a United States Environmental Protection Agency (EPA) document titled “AP-42” or other appropriate EPA reference documents. AP-42 is a collection of emission factors for different emission sources. The emission factors found in AP-42 provide a generally accepted way of estimating emissions when more representative data are not available. The most recent version of AP-42 (dated April 2000) can be found at:

http://www.epa.gov/ttn/chief/ap42/ch03/index.html

Solar does not typically warranty the emission rates for VOC, SO2 or formaldehyde.

Volatile Organic CompoundsMany permitting agencies require gas turbine users to estimate emissions of VOC, a subpart of the un-burned hydrocarbon (UHC) emissions, during the air permitting process. Volatile organic compounds, non-methane hydrocarbons (NMHC), and reactive organic gases (ROG) are some of the many ways of referring to the non-methane (and non-ethane) portion of an “unburned hydrocarbon” emission estimate.

For natural gas fuel, Solar’s customers use 10-20% of the UHC emission rate to represent VOC emis-sions. The estimate of 10-20% is based on a ratio of total non-methane hydrocarbons to total organic compounds. The use of 10-20% provides a conservative estimate of VOC emissions. The balance of the UHC is assumed to be primarily methane.

For liquid fuel, it is appropriate to estimate that 100% of the UHC emission estimate is VOC.

Sulfur DioxideSulfur dioxide emissions are produced by conversion of sulfur in the fuel to SO2. Since Solar does not control the amount of sulfur in the fuel, we are unable to predict SO2 emissions without a site fuel compo-sition analysis. Customers generally estimate SO2 emissions with a mass balance calculation by assum-ing that any sulfur in the fuel will convert to SO2. For reference, the typical mass balance equation is shown below.

SulfurMWSOMW

hrfuelMMBtu

MMBtuBtu10

Btufuellb

100Sulfurwt%

hrSOlb 2

62

Variables: wt % of sulfur in fuelBtu/lb fuel (LHV)MMBtu/hr fuel flow (LHV)

PIL 168Product Information Letter



2

As an alternative to the mass balance calculation, EPA’s AP-42 document can be used. AP-42 (Table 3.1-2a, April 2000) suggests emission factors of 0.0034 lb/MMBtu for gas fuel (HHV) and 0.033 lb/MMBtu for liquid fuel (HHV).

FormaldehydeIn gas turbines, formaldehyde emissions are a result of incomplete combustion. Formaldehyde in the ex-haust stream is unstable and very difficult to measure. In addition to turbine characteristics including combustor design, size, maintenance history, and load profile, the formaldehyde emission level is also affected by:

Ambient temperature

Humidity

Atmospheric pressure

Fuel quality

Formaldehyde concentration in the ambient air

Test method measurement variability

Operational factors

The emission factor data in Table 1 is an excerpt from an EPA memo: “Revised HAP Emission Factors for Stationary Combustion Turbines, 8/22/03.” The memo presents hazardous air pollutant (HAP) emission factor data in several categories including: mean, median, maximum, and minimum. The emission fac-tors in the memo are a compilation of the HAP data EPA collected during the Maximum Achievable Con-trol Technology (MACT) standard development process. The emission factor documentation shows there is a high degree of variability in formaldehyde emissions from gas turbines, depending on the manufac-turer, rating size of equipment, combustor design, and testing events. To estimate formaldehyde emis-sions from gas turbines, users should use the emission factor(s) that best represent the gas turbines ac-tual / planned operating profile. Refer to EPA’s memo for alternative emission factors.

Table 1. EPA’s Total HAP and Formaldehyde Emission Factors for <50 MW Lean-Premix Gas Turbines burning Natural Gas

(Source: Revised HAP Emission Factors for Stationary Combustion Turbines, OAR-2002-0060, IV-B-09, 8/22/03)

PollutantEngine Load

95% Upper Confidence of Mean, lb/MMBtu HHV

95% Upper Confidence of Data, lb/MMBtu HHV

Memo Reference

Total HAP > 90% 0.00144 0.00258 Table 19

Total HAP All 0.00160 0.00305 Table 16

Formaldehyde > 90% 0.00127 0.00241 Table 19

Formaldehyde All 0.00143 0.00288 Table 16


Cat and Caterpillar are registered trademarks of Caterpillar Inc. Solar, Saturn, Centaur, Taurus, Mercury, Mars, Titan, SoLoNOx, Turbotronic, InSight System, and InSight Connect, are trademarks of Solar Turbines Incorporated. All other trademarks are the intel-lectual property of their respective companies.© 2015 Solar Turbines Incorporated. All rights reserved. Specifications are subject to change without notice.





Emission Estimates at Start-up, Shutdown, andCommissioning for SoLoNOx Combustion

ProductsLeslie Witherspoon

Solar Turbines Incorporated

PURPOSEThe purpose of this Product Information Letter (PIL) is to provide emission estimates for start-up and shutdown events for Solar® gas turbines with SoLoNOx™ dry low emissions combustion systems. The commissioning process is also discussed.

INTRODUCTIONThe information presented in this document is representative for both generator set (GS) and compressor set/mechanical drive (CS/MD) combustion turbine applications. Operation of duct burners and/or any add-on control equipment is not accounted for in the emissions estimates. Emissions related to the start-up, shutdown, and commissioning of combustion turbines will not be guaranteed or warranted.

Combustion turbine start-up occurs in one of three modes: cold, warm, or hot. On large, utility size, combustion turbines, the start-up time varies by the “mode”. The start-upduration for a hot, warm, or cold Solar turbine is less than 10 minutes in simple-cycle and most combined heat and power applications.

Heat recovery steam generator (HRSG) steam pressure is usually 250 psig or less. At 250 psig or less, thermal stress within the HRSG is minimized and, therefore, firing ramp-up is not limited. However, some combined heat and power plant applications will desire or dictate longer start-up times, therefore emissions assuming a 60-minute start are also estimated.

A typical shutdown for a Solar turbine is <10 minutes. Emissions estimates for an elongated shutdown, 30-minutes, are also included.

Start-up and shutdown emissions estimates for the Mercury™ 50 engine are found in PIL 205.

For start-up and shutdown emissions estimates for conventional combustion turbines, landfill gas, digester gas, or other alternative fuel applications, contact Solar’s Environmental Programs Department.

START-UP SEQUENCEThe start-up sequence, or getting to SoLoNOx combustion mode, takes three steps:

1. Purge-crank

2. Ignition and acceleration to idle

3. Loading / thermal stabilization

During the “purge-crank” step, rotation of the turbine shaft is accomplished with a starter motor to remove any residual fuel gas in the engine flow path and exhaust. During






“ignition and acceleration to idle,” fuel is introduced into the combustor and ignited in a diffusion flame mode and the engine rotor is accelerated to idle speed.

The third step consists of applying up to 50% load1 while allowing the combustion flame to transition and stabilize. Once 50% load is achieved, the turbine transitions to SoLoNOxcombustion mode and the engine control system begins to hold the combustion primary zone temperature and limit pilot fuel to achieve the targeted nitrogen oxides (NOx), carbon monoxide (CO), and unburned hydrocarbons (UHC) emission levels.

Steps 2 and 3 are short-term transient conditions making up less than 10 minutes.

SHUTDOWN PROCESSNormal, planned cool down/shutdown duration varies by engine model. The Centaur® 40, Centaur 50, Taurus™ 60, and Taurus 65 engines take about 5 minutes. The Taurus 70, Mars® 90 and Mars 100, Titan™ 130 and Titan 250 engines take about 10 minutes. Typically, once the shutdown process starts, the emissions will remain in SoLoNOx mode for approximately 90 seconds and move into a transitional mode for the balance of the estimated shutdown time (assuming the unit was operating at full-load).

START-UP AND SHUTDOWN EMISSIONS ESTIMATESTables 1 through 5 summarize the estimated pounds of emissions per start-up and shutdown event for each product. Emissions estimates are presented for both GS and CS/MD applications on both natural gas and liquid fuel (diesel #2). The emissions estimates are calculated using empirical exhaust characteristics.

COMMISSIONING EMISSIONSCommissioning generally takes place over a two-week period. Static testing, where no combustion occurs, usually requires one week and no emissions are expected. Dynamic testing, where combustion will occur, will see the engine start and shutdown a number of times and a variety of loads will be placed on the system. It is impossible to predict how long the turbine will run and in what combustion / emissions mode it will be running. The dynamic testing period is generally followed by one to two days of “tune-up” during which the turbine is running at various loads, most likely within low emissions mode (warranted emissions range).


Caterpillar is a registered trademark of Caterpillar Inc.Solar, Titan, Mars, Taurus, Mercury, Centaur, Saturn, SoLoNOx, and Turbotronic are trademarks of Solar Turbines Incorporated. All other trademarks are the intellectual property of their respective companies. Specifications are subject to change without notice.

1 40% load for the Titan 250 engine on natural gas. 65% load for all engines on liquid fuel (except 80% load for the Centaur 40).

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CYL #1000

GAS ANALYSIS REPORT NO.: DATE:

FOR: SAMPLE IDENTIFICATION:

COMPANY:

FIELD:

LEASE:

STA #:

REMARKS:

CARBON DIOXIDE

NITROGEN

METHANE

ETHANE

PROPANE

ISO-BUTANE

N-BUTANE

ISO-PENTANE

N-PENTANE

TOTAL

MOL WEIGHT:

BTU/LB: ISO-PENTANE + GPM:

PROPANE + GPM:

ETHANE + GPM:

BTU/CUFT. (REAL) 60 DEG.F. - PSIA: 14.650 14.696 15.025

DRY:

SAT:

( N2)

(CO2)

( C1)

( C2)

( C3)

(IC4)

(NC4)

(IC5)

(NC5)

46-082715-42 (381316)


LORI MARTIN SHAFFER

1700 MACCORKLE AVE SE

CHARLESTON WV 25314


N/P

MINISINK C.S.

CS-7C4175

0.031

0.244

97.794

1.876

0.053

0.000

0.002

0.000

0.000

100.000

16.35

23715.3

0.518

0.016

0.000

1021.3 1024.5 1026.9 1047.4

1003.4 1006.6 1009.0 1029.6

0.502

0.015

0.000

0.001

0.000

0.000

ATTN:

08/27/15

HEXANES PLUS (C6+) 0.000 0.000

14.730

SAMPLE TYPE: BY REQUEST FROM:08/20/15 TO:08/20/15

SAMPLE DATA: DATE:

PSIG:

BY:

TEMP: DEG.F. LBS H20DP:

08/20/15

700

JOE LASTATZA

N/P N/P

HYDROCARBON ANALYSIS - METHOD GPA 2261-13

COMPONENT NAME MOL PERCENT GPM @ 14.730 PSIA

COMPRESSIBILITY FACTOR:

SPECIFIC GRAVITY @ 60 DEG. F. (AIR = 1):

0.9979

0.566

LAB ANALYST:MP

2129 WEST WILLOW SCOTT LA 70583 337-232-3568


REVIEWED BY:

DATE:

SAMPLE IDENTIFICATION

COMPANY:FIELD:LEASE:STA #:

SAMPLE DATE:

08/27/15

COLUMBIA PIPELINE GROUPN/PMINISINK C.S.CS-7C4175

08/20/15(381316)


COMPONENTMOL

PERCENTWT.

PERCENT


0.0000 0.0000METHANE

0.0000 0.0000ETHANE

0.0000 0.0000PROPANE

0.0000 0.0000ISO-BUTANE

0.0000 0.0000N-BUTANE

0.0000 0.00002,2-DIMETHYLPROPANE (NEOPENTANE)

0.0000 0.0000ISOPENTANE

0.0000 0.0000N-PENTANE

0.0000 0.00002,2-DIMETHYLBUTANE (NEOHEXANE)

0.0000 0.00002,3-DIMETHYLBUTANECYCLOPENTANE



0.0000 0.0000N-HEXANE


0.0000 0.0000METHYLCYCLOPENTANE


0.0000 0.00002,2,3-TRIMETHYLBUTANE

0.0000 0.0000BENZENE


0.0000 0.0000CYCLOHEXANE

0.0000 0.00002-METHYLHEXANE


0.0000 0.00001,1-DIMETHYLCYCLOPENTANE3-METHYLHEXANE

0.0000 0.00001,t3-DIMETHYLCYCLOPENTANE

0.0000 0.00001,c3-DIMETHYLCYCLOPENTANE3-ETHYLPENTANE

PAGE 1



COMPONENTMOL

PERCENTWT.

PERCENT


0.0000 0.00001,t2-DIMETHYLCYCLOPENTANE2,2,4-TRIMETHYLPENTANE

0.0000 0.0000N-HEPTANE

0.0000 0.0000METHYLCYCLOHEXANE1,1,3-TRIMETHYLCYCLOPENTANE2,2-DIMETHYLHEXANE

0.0000 0.00001,C2-DIMETHYLCYCLOPENTANE


0.0000 0.00002,4-DIMETHYLHEXANE2,2,3-TRIMETHYLPENTANEETHYLCYCLOPENTANE

0.0000 0.00001,t2,c4-TRIMETHYLCYCLOPENTANE3,3-DIMETHYLHEXANE

0.0000 0.00001,t2,c3-TRIMETHYLCYCLOPENTANE

0.0000 0.00002,3,4-TRIMETHYLPENTANE

0.0000 0.0000TOLUENE


0.0000 0.00001,1,2-TRIMETHYLCYCLOPENTANE




0.0000 0.00003-METHYLHEPTANE3-ETHYLHEXANE

0.0000 0.00001,c3-DIMETHYLCYCLOHEXANE1,c2,t3-TRIMETHYLCYCLOPENTANE1,c2,t4-TRIMETHYLCYCLOPENTANE

0.0000 0.00001,t4-DIMETHYLCYCLOHEXANE


0.0000 0.00001,1-DIMETHYLCYCLOHEXANE1,methyl-t3-ETHYLCYCLOPENTANE

0.0000 0.00001-methyl-c3-ETHYLCYCLOPENTANE

0.0000 0.00001-methyl-t2-ETHYLCYCLOPENTANE2,2,4-TRIMETHYLHEXANE

0.0000 0.00001-methyl-1-ETHYLCYCLOPENTANECYCLOHEPTANEN-OCTANE

0.0000 0.00001,T2-DIMETHYLCYCLOCHEXANE

PAGE 2



COMPONENTMOL

PERCENTWT.

PERCENT


0.0000 0.0000UNKNOWN

0.0000 0.00001,t3-DIMETHYLCYCLOHEXANE1,c4-DIMETHYLCYCLOHEXANE1,c2,c3-TRIMETHYLCYCLOPENTANE


0.0000 0.0000ISOPROPYLCYCLOPENTANE

0.0000 0.0000UNKNOWN

0.0000 0.00002,2-DIMETHYLHEPTANE

0.0000 0.00002,4-DIMETHYLHEPTANE1-methyl-c2-ETHYLCYCLOPENTANE


0.0000 0.00001,c2-DIMETHYLCYCLOHEXANE2,6-DIMETHYLHEPTANE

0.0000 0.0000N-PROPYLCYCLOPENTANE1,c3,c5-TRIMETHYLCYCLOHEXANE

0.0000 0.00002,5-DIMETHYLHEPTANE3,5-DIMETHYLHEPTANEETHYLCYCLOHEXANE

0.0000 0.00001,1,3-TRIMETHYLCYCLOHEXANE2,3,3-TRIMETHYLHEXANE3,3-DIMETHYLHEPTANE


0.0000 0.0000UNKNOWN


0.0000 0.0000ETHYLBENZENE

0.0000 0.00001,t2,t4-TRIMETHYLCYCLOHEXANE1,c3,t5-TRIMETHYLCYCLOHEXANE2,3-DIMETHYLHEPTANE

0.0000 0.0000M-XYLENEP-XYLENE3,4-DIMETHYLHEPTANE

0.0000 0.00002-METHYLOCTANE4-METHYLOCTANE

0.0000 0.0000UNKNOWN

0.0000 0.00003-METHYLOCTANE

0.0000 0.0000UNKNOWN

0.0000 0.00001,t2,c3-TRIMETHYLCYCLOHEXANE1,t2,c4-TRIMETHYLCYCLOHEXANE

PAGE 3



COMPONENTMOL

PERCENTWT.

PERCENT


0.0000 0.0000O-XYLENE


0.0000 0.0000UNKNOWN

0.0000 0.0000ISOBUTYLCYCLOPENTANE

0.0000 0.0000N-NONANE

0.0000 0.0000UNKNOWN

0.0000 0.00001,c2,c3-TRIMETHYLCYCLOHEXANE1,c2,t3-TRIMETHYLCYCLOHEXANE

0.0000 0.0000UNKNOWN

0.0000 0.0000ISOPROPYLBENZENE


0.0000 0.0000ISOPROPYLCYCLOHEXANECYCLOOCTANE

0.0000 0.0000UNKNOWN

0.0000 0.0000N-BUTYLCYCLOPENTANEN-PROPYLCYCLOHEXANE


0.0000 0.0000UNKNOWN

0.0000 0.0000N-PROPYLBENZENE

0.0000 0.0000UNKNOWN

0.0000 0.0000m-ETHYLTOLUENE

0.0000 0.0000p-ETHYLTOLUENE2,3-DIMETHYLOCTANE

0.0000 0.00004-METHYLNONANE5-METHYLNONANE1,3,5-TRIMETHYLBENZENE

0.0000 0.00002-METHYLNONANE

0.0000 0.00003-ETHYLOCTANE

0.0000 0.0000O-ETHYLTOLUENE3-METHYLNONANE

0.0000 0.0000UNKNOWN

0.0000 0.00001,2,4-TRIMETHYLBENZENEt-BUTYLBENZENEMETHYLCYCLOOCTANE

0.0000 0.0000tert-BUTYLCYCLOHEXANE

PAGE 4



COMPONENTMOL

PERCENTWT.

PERCENT


0.0000 0.0000ISO-BUTYLCYCLOHEXANE

0.0000 0.0000N-DECANE

0.0000 0.0000ISOBUTYLBENZENE

0.0000 0.0000sec-BUTYLBENZENE

0.0000 0.0000UNKNOWN


0.0000 0.00001,2,3-TRIMETHYLBENZENE1-METHYL-4-ISOPROPYLBENZENE

0.0000 0.0000UNKNOWN


0.0000 0.0000UNKNOWN

0.0000 0.0000N-BUTYLCYCLOHEXANE

0.0000 0.0000UNKNOWN

0.0000 0.00001,3-DIETHYLBENZENE1-METHYL-3-PROPYLBENZENE

0.0000 0.00001,2-DIETHYLBENZENEN-BUTYLBENZENE1-METHYL-4-PROPYLBENZENE

0.0000 0.00001,4-DIETHYLBENZENE

0.0000 0.00001-METHYL-2-PROPYLBENZENE


0.0000 0.0000UNKNOWN



0.0000 0.0000UNKNOWN


0.0000 0.0000UNKNOWN

0.0000 0.0000N-UNDECANE

0.0000 0.0000UNKNOWN



0.0000 0.0000UNKNOWN

0.0000 0.00001,2,3,4-TETRAMETHYLBENZENECYCLODECANE

PAGE 5



COMPONENTMOL

PERCENTWT.

PERCENT


0.0000 0.0000UNKNOWN

0.0000 0.0000NAPHTHALENE

0.0000 0.0000N-DODECANE

0.0000 0.0000ISOTRIDECANES PLUS

TOTALS 0.0000 0.0000

0.0000

0.0000

0.0000

0.0000

0.0000

TOTAL HEXANES =

TOTAL HEPTANES =

TOTAL OCTANES =

TOTAL NONANES =

TOTAL DECANES PLUS =

0.0000

0.0000

0.0000

0.0000

0.0000

PAGE 6


APPENDIX C ELECTRONIC AIR QUALITY

MODELING FILES

Resource Report 9 – Air and Noise Quality 9D-i Eastern System Upgrade

APPENDIX 9D

Air Quality Modeling Assessments



Eastern System Upgrade Project

Ambient Air Quality Modeling Assessment

Prepared for:


Prepared by:



July 2016

Millennium Pipeline Company, LLC ii Ambient Air Quality Modeling Assessment Highland Compressor Station


1.0 Introduction .......................................................................................................... 1-1

1.1 Project Overview ................................................................................................ 1-1

2.0 Project Description ................................................................................................2-2

2.1 Site Location and Surroundings ........................................................................2-2 2.2 Facility Conceptual Design ................................................................................2-2

2.2.1 Compressor Turbine .................................................................................. 2-3 2.2.2 Ancillary Equipment ................................................................................. 2-4

2.3 Proposed Project Emission Potential ................................................................ 2-5


3.1 Background Ambient Air Quality ...................................................................... 3-1 3.2 Modeling Methodology ..................................................................................... 3-3

3.2.1 Model Selection .......................................................................................... 3-3 3.2.2 Urban/Rural Area Analysis ........................................................................ 3-3 3.2.3 Good Engineering Practice Stack Height ..................................................3-4 3.2.4 Meteorological Data ................................................................................... 3-5

3.3 Receptor Grid ....................................................................................................3-6 3.3.1 Basic Grid ...................................................................................................3-6 3.3.2 Property Line Receptors ............................................................................ 3-7

3.4 Selection of Sources for Modeling ..................................................................... 3-7 3.4.1 Emission Rates and Exhaust Parameters .................................................. 3-7

3.5 Maximum Modeled Facility Concentrations .................................................. 3-10 3.6 Toxic Ambient Air Contaminant Analysis ...................................................... 3-11 3.7 References ........................................................................................................ 3-13

LIST OF TABLES

Table 2-1: Proposed Facility Emissions (tons/year) .................................................................................... 2-5 Table 3-1: Maximum Measured Ambient Air Quality Concentrations ....................................................... 3-2 Table 3-2: Stack Parameters and Emission Rates – Proposed Titan 130E Compressor Turbine .............. 3-9 Table 3-3: Stack Parameters and Emission Rates – Proposed Emergency Generator .............................. 3-9 Table 3-4: Stack Parameters and Emission Rates – Proposed Fuel Gas Heater ...................................... 3-10 Table 3-5: Facility Maximum Modeled Concentrations Compared to NAAQS/NYAAQS ....................... 3-10 Table 3-6: Facility Maximum Modeled Concentrations Compared to SGCs and AGCs .......................... 3-12

Millennium Pipeline Company, LLC 1-1 Ambient Air Quality Modeling Assessment Highland Compressor Station

1.0 INTRODUCTION


Millennium Pipeline Company, L.L.C. (Millennium) is seeking authorization from the

Federal Energy Regulatory Commission (FERC or Commission) pursuant to Section 7(c)

of the Natural Gas Act to construct, install, operate, and maintain the Eastern System

Upgrade (Project). The purpose of the Project is to permit Millennium to transport an

incremental volume of approximately 223,000 dekatherms per day of natural gas from

Millennium’s Corning Compressor Station to an existing interconnect with Algonquin

Gas Transmission, L.L.C. (Algonquin) located in Ramapo, New York. As part of the

Eastern System Upgrade Project and in order to boost pressures on Millennium’s

transmission pipeline system, Millennium is proposing to construct and operate one Solar

Titan 130E compressor turbine (22,400 hp (ISO)) at a new compressor Station in the

town of Highland, Sullivan County, and known as the Highland Compressor Station. The

Highland Compressor Station (CS) will be a new natural gas transmission facility covered

by Standard Industrial Classification (SIC) 4922. Ancillary project emission sources

include one (1) 1,230 hp Waukesha VGF48GL emergency generator, one (1) 4,000 gallon

waste liquids storage tank, one (1) 1.2 MMBtu/hr gas heater, and one (1) 1,500 gallon oil

tank.

At the federal level, because the emission increases from the Highland Station

modifications are less than applicable major source thresholds, Millennium will not

trigger federal NSR requirements for any regulated air pollutant under either PSD or

NNSR permitting programs. At the state level, the Project triggers air permitting through

the NYSDEC as a minor source of air emissions subject to State Air Facility permitting. If

the agency considers that any project triggering minor NSR permitting could threaten

attainment with the National Ambient Air Quality Standards (NAAQSs) or human health

from toxic air pollutant (TAP) concentrations, NYSDEC can require air dispersion

modeling for the Project. A site wide modeling analysis for criteria pollutants has been

performed in accordance with their impact analysis modeling guidance, Policy DAR‐10.

In addition, a modeling analysis that addresses TAPs is performed per Policy DAR‐1. This

report details the NAAQS and TAPs modeling assessment for the proposed Highland

Station.




The proposed Highland Compressor Station is located in a rural area in the town of

Highland, Sullivan County, New York. The site is currently undeveloped.

The approximate Universal Transverse Mercator (UTM) coordinates of the facility are:

511,142 meters east and 4,603,785 meters north in Zone 18 (North American Datum of

1983(NAD83)).


As a part of the Eastern System Upgrade project, Millennium is proposing to install the

following equipment at the proposed Highland compressor station:

One Solar Titan 130-22402S, 22,400 HP (ISO) natural gas fired turbine‐driven

compressor unit;

One Waukesha VGF48GL (1,230 hp) natural gas fired emergency generator;

One 4,000 gallon waste liquids storage tank;

One 1.2 MMBtu/hr heat input natural gas fired fuel gas heater; and

One 1,500 gallon oil storage tank.

In addition to the single significant emission source consisting of the Solar Titan 130E

combustion turbine, several exempt emission units will be located at the Highland

compressor station. These exempt sources include natural gas‐fired heaters with heat

inputs less than 10 million British thermal units per hour (MMBtu/hr) and one natural

gas‐fired Waukesha VGF48GL emergency generator with a heat input of 9.7 mmBtu/hr.

The new Waukesha (1,230 hp) emergency generator has a four stroke, lean burn, natural

gas‐fired stationary reciprocating internal combustion engine. The proposed emergency

generator will be installed to meet site wide emergency electrical demands as a result of

the Eastern System Upgrade project and will be operated only during normal testing,

maintenance, and emergency situations. Per 6 NYCRR 201‐3.2(c)(6), emergency power

generating stationary internal combustion engines, as defined in section 200.1(vq) of this

Title are exempt sources. As such, this generator is an exempt source. Further, the engine

will meet the definition of “emergency stationary internal combustion engine” per 40 CFR


60.4248 and will comply with the requirements for operating emergency engines in 40

CFR 60.4243(d).

Millennium is proposing to install one natural gas fired fuel gas heater, with a rated heat

input capacity of 1.2 MMBtu/hr. Per 6 NYCRR 201‐3.2(c)(1)(i), stationary combustion

installations with a maximum rated heat input capacity less than 10 MMBtu/hr burning

fuels other than coal or wood are exempt from permitting. As such, the heater is an

exempt source.


The proposed Solar Titan 130E natural gas-fired turbine to be installed at the Highland

Compressor Station will be equipped with Solar’s SoLoNOx dry low NOx combustor

technology for NOx control. Emissions for the Solar Turbine assumes that the unit will

operate up to 8,760 hours per year and up to 100% rated output. The vendor provided

emission rates for normal operating conditions are as follows (all emissions rates are in

terms of parts per million dry volume (ppmvd) @ 15% O2):

• 15 ppmvd NOx;

• 25 ppmvd CO;

• 25 ppmvd unburned hydrocarbons (UHC); and

• 5 ppmvd VOC.

Depending upon demand, the turbine may operate at loads ranging from 50% to 100% of

full capacity. Because of the different emission rates and exhaust characteristics that

occur at different loads and ambient temperatures, a matrix of operating modes is

presented in this air modeling assessment. Emission parameters for three turbine loads

(50%, 75%, and 100%) and six ambient temperatures (0oF, 20oF, 40oF, 60oF, 80oF and

100oF) are accounted for in this air modeling assessment to cover the range of steady-

state turbine operations.

At very low load and cold temperature extremes, the turbine system must be controlled

differently in order to assure stable operation. The required adjustments to the turbine

controls at these conditions cause emissions of NOx, CO and VOC to increase (emission

rates of other pollutants are unchanged). Low-load operation (non-normal SoLoNOx

operation) of the turbines is expected to occur only during periods of startup and

shutdown and for maintenance or unforeseen emergency events. The annual hours of

operation during low load operation was assumed to be no more than 10 hours per year.


Similarly, Solar has provided emission estimates for low temperature operation (inlet

combustion air temperature less than 0° F and greater than -20° F). Estimated pre-

control emissions from the turbines at low temperature conditions are:

• 120 ppmvd NOx;

• 150 ppmvd CO;


• 10 ppmvd VOC.

Millennium reviewed historic meteorological data from the previous five years for the

region to estimate the worst case number of hours per year under sub-zero (less than 0°

F) conditions. The annual hours of operation during sub-zero conditions was assumed to

be not more than 120 hours per year.

Turbine emission rates during start-up and shutdown events increase for NOx, CO and

VOC as compared to operating above 50% load. The start-up process for the Solar Titan

130E turbine takes approximately 10 minutes from the initiation of start-up to normal

operation (equal to or greater than 50% load). Shutdown takes approximately 10

minutes. Millennium has estimated there would be 100 start-up/shutdown events per

year.


Millennium is proposing to install a new Waukesha VGF48GL (1,230 hp) four stroke lean

burn natural gas fired emergency generator. The emergency generator will operate for no

more than 500 hours/year, and therefore meets the definition of an “emergency power

generating stationary internal combustion engine” under 6 NYCRR 200.1(cq). As

previously indicated, the generator is an exempt source per 6 NYCRR 201‐3.2(c)(6),

however the potential emissions for this new unit are included for NSR and Title V

applicability purposes.

Millennium is proposing to install one new 1.2 MMBtu/hr (heat input) natural gas heater.

As previously indicated, the heater is an exempt source per 6 NYCRR 201‐3.2(c)(1)(i),





Table 2-1 presents project emission potentials from the new units to be installed as a part

of the proposed Highland Compressor Station. For new units, project emission potential

is equal to potentials to emit.

Table 2-1: Proposed Facility Emissions (tons/year)

Pollutant

Solar

Titan

130E

Turbine

Exempt

Waukesha

VGF48GL

Emergency

Generator(1)

Exempt

Fuel Gas

Heater(1)

Exempt Lube

Oil and Waste

Liquid

Tanks(2)

Trivial

Station

Blowdowns

(3)

Trivial Station

Fugitives(3)

Proposed

Project

Total

(tons/

year)

NOx 48.59 1.36 0.53 - - - 50.47

VOC 5.53 0.68 0.03 2.27 0.05 0.49 9.05

CO 78.08 2.71 0.44 - - - 81.23

SO2 4.57 0.0015 0.030 - - - 4.60

PM10/PM2.5 12.27 0.04 0.04 - - - 12.33

CO2e 95,690 285 631 - 758 7,891 105,255

HAPs 2.48 0.18 0.01 0.21 - - 2.87

Maximum

Individual HAP

(Formaldehyde)

1.71 0.13 0.0003

-

- - 1.84

(1) Exempt per 201-3.2(c)(6) for emergency power generating stationary internal combustion engines which meet the requirements of 200.1(cq)

of operation when the usual source of electric power is unavailable and no more than 500 hours per year inclusive of emergency operation,

testing, and maintenance.

(2) Exempt per 201-3.2(c)(25) for storage tanks under 10,000 gallons, not otherwise subject to Parts 229 or 233

(3) Trivial per 201-3.3(94) for emissions of “….oxygen, carbon dioxide, nitrogen, simple asphyxiants including methane and propane, trace

constituents included in raw materials or byproducts, where the constituents are less than 1 percent by weight for any regulated air pollutant, or

0.1 percent by weight for any carcinogen listed by the United States Department of Health and Human Services’ Seventh Annual Report on

Carcinogens (1994). The definition of “regulated air pollutant” under 200.1(bu) does not include methane or ethane.






Background ambient air quality data was obtained from various existing monitoring

locations. Based on a review of the locations of Pennsylvania and New York ambient air

quality monitoring sites, the closest representative monitoring sites were used to

represent the current background air quality in the site area.

Background data for CO, NO2, and PM2.5 was obtained from a monitoring station located

in Lackawanna County, Pennsylvania (USEPA AIRData # 42-069-2006). This monitor

is located in the city of Scranton that has a higher population density and higher density

of industrial facilities than the Highland area in Sullivan County. Further, this monitor is

located in an area with a greater amount of mobile and point sources of air emissions as

compared to the project area. Thus, this monitor is considered to conservatively

represent the ambient air quality within the project area.

Background data for SO2 and PM10 was obtained from a monitoring station located in

Luzerne County, Pennsylvania (USEPA AIRData # 42-079-1101). This monitor is located

in city of Wilkes Barre that has a higher population density and higher density of

industrial facilities than the area around the Highland Station. Further, this monitor is


compared to the project area. Thus, this monitor is also considered to conservatively

represent the ambient air quality within the project study area.

The monitoring data for the most recent three years (2012 – 2014) are presented and

compared to the NAAQS in Table 3-1. The maximum measured concentrations for each

of these pollutants during the last three years are all below applicable standards and are

used as representative background values for comparison of facility concentrations to the

NAAQS.



Pollutant Averaging

Period

Maximum Ambient Concentrations

(g/m3) NAAQS

(g/m3) 2012 2013 2014

SO2

1-Houra

24-Hour

Annual

21.0

13.6

2.1

18.3

13.6

1.4

23.6

13.9

2.1

196

365

80

NO2 1-Hourb

Annual

67.7

16.1

75.2

15.4

84.6

20.0

188

100

CO 1-Hour

8-Hour

1,380

920

2,070

1,495

1,725

1,150

40,000

10,000

PM10 24-Hour 34 45 32 150

PM2.5c 24-Hour

Annual

20

8.3

24

9.2

23

11.1

35

12 a1-hour 3-year average 99th percentile value for SO2 is 21.0 g/m3. b1-hour 3-year average 98th percentile value for NO2 is 75.8 g/m3. c24-hour 3-year average 98th percentile value for PM-2.5 is 22.3 g/m3; Annual 3-year average value for

PM2.5 is 9.5 g/m3.

High second-high short term (1-, 3-, 8-, and 24-hour) and maximum annual average concentrations

presented for all pollutants other than PM2.5 and 1-hour SO2 and NO2.

Bold values represent the proposed background values for use in any necessary NAAQS/NYAAQS analyses.

Monitored background concentrations obtained from the USEPA AirData website

(https://www3.epa.gov/airdata/).



An air quality modeling analysis was performed consistent with the procedures found in

the following documents: Guideline on Air Quality Models (Revised) (USEPA, 2005),

New Source Review Workshop Manual (USEPA, 1990), Screening Procedures for

Estimating the Air Quality Impact of Stationary Sources (USEPA, 1992), and DAR-10:

NYSDEC Guidelines on Dispersion Modeling Procedures for Air Quality Impact Analysis

(NYSDEC, 2006).

3.2.1 Model Selection The USEPA has compiled a set of preferred and alternative computer models for the

calculation of pollutant impacts. The selection of a model depends on the characteristics

of the source, as well as the nature of the surrounding study area. Of the four classes of

models available, the Gaussian type model is the most widely used technique for

estimating the impacts of nonreactive pollutants.

The AERMOD model was designed for assessing pollutant concentrations from a wide

variety of sources (point, area, and volume). AERMOD is currently recommended by the

USEPA for modeling studies in rural or urban areas, flat or complex terrain, and transport

distances less than 50 kilometers, with one hour to annual averaging times.

The latest version of USEPA’s AERMOD model (Version 15181) was used in the analysis.

AERMOD was applied with the regulatory default options and 5-years (2011-2015) of

hourly meteorological data consisting of surface observations from Binghamton Edwin A

Link Field in Binghamton, NY and concurrent upper air data from Albany, NY.


A land cover classification analysis was performed to determine whether the URBAN

option in the AERMOD model should be used in quantifying ground-level concentrations.

The methodology utilized to determine whether the project is located in an urban or rural

area is described below.

The following classifications relate the colors on a United States Geological Survey

(USGS) topographic quadrangle map to the land use type that they represent:


Blue – water (rural);

Green – wooded areas (rural);

White – parks, unwooded, non-densely packed structures (rural);

Purple – industrial; identified by large buildings, tanks, sewage disposal or

filtration plants, rail yards, roadways, and, intersections (urban);

Pink – densely packed structures (urban); and,

Red – roadways and intersections (urban)

The USGS map covering the area within a 3-kilometer radius of the facility was reviewed

and indicated that the vast majority of the surrounding area is denoted as blue, green, or

white, which represent water, wooded areas, parks, and non-densely packed structures.

Additionally, the “AERMOD Implementation Guide” published on August 3, 2015

cautions users against applying the Land Use Procedure on a source-by-source basis and

instead to consider the potential for urban heat island influences across the full modeling

domain. This approach is consistent with the fact that the urban heat island is not a

localized effect, but is more regional in character.

Because the urban heat island is more of a regional effect, the Urban Source option in

AERMOD was not utilized since the area within 3 kilometers of the facility as well as the

full modeling domain (20 kilometers by 20 kilometers) is predominantly rural.


Section 123 of the Clean Air Act (CAA) required the USEPA to promulgate regulations to

assure that the degree of emission limitation for the control of any air pollutant under an

applicable State Implementation Plan (SIP) was not affected by (1) stack heights that

exceed Good Engineering Practice (GEP) or (2) any other dispersion technique. The

USEPA provides specific guidance for determining GEP stack height and for determining

whether building downwash will occur in the Guidance for Determination of Good

Engineering Practice Stack Height (Technical Support Document for the Stack Height

Regulations), (USEPA, 1985). GEP is defined as “…the height necessary to ensure that

emissions from the stack do not result in excessive concentrations of any air pollutant in

the immediate vicinity of the source as a result of atmospheric downwash, eddies, and

wakes that may be created by the source itself, or nearby structures, or nearby terrain

“obstacles”.”


The GEP definition is based on the observed phenomenon of atmospheric flow in the

immediate vicinity of a structure. It identifies the minimum stack height at which

significant adverse aerodynamics (downwash) are avoided. The USEPA GEP stack height

regulations (40 CFR 51.100) specify that the GEP stack height (HGEP) be calculated in the

following manner:

HGEP = HB + 1.5L

Where: HB = the height of adjacent or nearby structures, and

L = the lesser dimension (height or projected width


A GEP stack height analysis has been conducted using the USEPA approved Building

Profile Input Program with PRIME (BPIPPRM, version 04274). The maximum

calculated GEP stack height for the new emission sources is 77.5 feet; the controlling

structure is the proposed compressor building (31.0 feet). Direction-specific downwash

parameters were determined using BPIPPRM, version 04274.


If at least one year of hourly on-site meteorological data is not available, the application

of the AERMOD dispersion model requires five years of hourly meteorological data that

are representative of the project site. In addition to being representative, the data must

meet quality and completeness requirements per USEPA guidelines. The closest source

of representative hourly surface meteorological data is Binghamton Edwin A Link Field

located in Binghamton, NY located approximately 71 miles to the northwest of the

Highland Compressor Station.

The meteorological data at the Binghamton Edwin A Link Field is recorded by an

Automated Surface Observing System (ASOS) that records 1-minute measurements of

wind direction and wind speed along with hourly surface observations necessary. The

USEPA AERMINUTE program was used by the NYSDEC to process 1-minute ASOS wind

data (2011 – 2015) from the Binghamton surface station in order to generate hourly

averaged wind speed and wind direction data to supplement the standard hourly ASOS

observations. The hourly averaged wind speed and direction data generated by

AERMINUTE was merged with the aforementioned hourly surface data.


The AERMOD assessment utilized five (5) years (2011–2015) of concurrent

meteorological data collected from a meteorological tower at the Binghamton Edwin A

Link Field and from radiosondes launched from Albany, New York. Both the surface and

upper air sounding data were processed by the NYSDEC using AERMOD’s meteorological

processor, AERMET (version 15181). The output from AERMET was used as the

meteorological database for the modeling analysis and consists of a surface data file and

a vertical profile data file. These data, which were prepared and processed to AERMOD

format by the NYSDEC, was provided for use in the modeling analyses for the proposed

facility.

3.3 Receptor Grid

3.3.1 Basic Grid

The AERMOD model requires receptor data consisting of location coordinates and

ground-level elevations. The receptor generating program, AERMAP (Version 11103),

was used to develop a complete receptor grid to a distance of 10 kilometers from the

proposed facility. AERMAP uses digital elevation model (DEM) or the National Elevation

Dataset (NED) data obtained from the USGS. The preferred elevation dataset based on

NED data was used in AERMAP to process the receptor grid. This is currently the

preferred data to be used with AERMAP as indicated in the USEPA AERMOD

Implementation Guide published August 3, 2015. AERMAP was run to determine the

representative elevation for each receptor using 1/3 arc second NED files that were

obtained for an area covering at least 10 kilometers in all directions from the proposed

facility. The NED data was obtained through the USGS Seamless Data Server

(http://seamless.usgs.gov/index.php).

The following rectangular (i.e. Cartesian) receptors were used to assess the air quality

impact of the proposed facility:

Consistent with DAR-10 guidance, fine grid receptors (70 meter spacing) for a 20

km (east-west) x 20 km (north-south) grid centered on the proposed facility site.



The facility has a fenced property line that precludes public access to the site. Ambient

air is therefore defined as the area at and beyond the fence. The modeling receptor grid

includes receptors spaced at 25-meter intervals along the entire fence line. Any Cartesian

receptors located within the fence line were removed.

3.4 Selection of Sources for Modeling

The emission source responsible for most of the potential emissions from the Highland

Compressor Station is the single combustion turbine. This unit was included in and is the

main focus of the modeling analyses. The modeling includes consideration of operation

over a range of turbine loads, ambient temperatures, and operating scenarios.

Ancillary sources (emergency diesel generators and fuel gas heater) were included in the

modeling for appropriate pollutants and averaging periods. The emergency equipment

may operate for up to 30 minutes in any day for readiness testing and maintenance

purposes. Operation of the emergency equipment for longer periods of time in an

emergency mode will not be expected to occur when the turbines are operating.

Although only limited operation is expected from the emergency equipment, initial

modeling to assess short-term facility impacts assumed concurrent operation of the

emergency equipment for readiness testing (i.e., up to 30 minutes per day) with the

combustion turbine.


The dispersion modeling analysis was conducted with emission rates and flue gas exhaust

characteristics (flow rate and temperature) that are expected to represent the range of

possible values for the proposed natural gas fired turbine. Because emission rates and

flue gas characteristics for a given turbine load vary as a function of ambient temperature

and fuel use, data were derived for a number of ambient temperature cases for natural

gas fuel at 100%, 75% and 50% operating loads. The temperatures were:

• <0°F, 0°F, 20°F, 40°F, 60°F, 80°F and 100°F.


To be conservative and limit the number of cases to be modeled, the short-term modeling

analysis was conducted using the lowest stack exhaust temperature and exit velocity

coupled with the maximum emission rate over all ambient temperature cases for each

operating load (with the exception of 1-hour NO2 modeling which excluded the <0ºF data

as discussed below). Annual modeling was based on the 100% load 40°F case (vendor

performance data for the turbine was available for 40°F and 60°F). The annual average

temperature for the project area is approximately 50°F. Use of the 40ºF emissions data

is conservative as emissions are slightly higher than the 60°F case.). Table 3-2

summarizes the stack parameters and emission rates used in the modeling for the

compressor turbine.

Note that the modeling for 1-hour NO2 excluded the emergency generator for which

normal operations (maintenance purposes only) will be limited to no more than 30

minutes per day with an annual limit of 100 hours per year for testing and maintenance

purposes. The 1-hour NO2 modeling also did not consider combustion turbine operations

under sub-zero ambient temperature conditions as these conditions are extremely limited

annually. The exclusion of the emergency generator and sub-zero operations for the

combustion turbines for the 1-hour NO2 modeling is based on USEPA guidance provided

in the March 1, 2011 memorandum, “Additional Clarification Regarding Application of

Appendix W Modeling Guidance for the 1-hour NO2 National Ambient Air Quality

Standard” for intermittent sources such as emergency generators. In the memo, US EPA

states the following:


The emergency generator and sub-zero operation of the combustion turbine are

considered as intermittent emissions, and thus, were excluded from the 1-hour NO2

modeling assessment.



Parameter Values

Load 50% 75%

100% Annual(2) Stack Height (m) 18.29 18.29 18.29 18.29

Stack Diameter (m)(1) 3.27 3.27 3.27 3.27

Exhaust Velocity (m/s) 9.60 11.38 12.69 14.33

Exhaust Temperature (K) 720.4 730.9 758.7 765.9


NOx 0.869 1.079 1.271 1.395

CO 5.292 6.562 7.734 -

SO2 0.095 0.115 0.132 0.132

PM10/PM2.5 0.255 0.308 0.353 0.353 (1) (1) The turbine stack is square (114 inches x 114 inches). The value listed and used in the modeling

is the effective diameter for an equivalent area circular stack. (2) (2) Based on conservative annual average exhaust parameters for 40ºF and annual potential

to emit discussed in Section 2.

Tables 3-3 and 3-4 present the stack parameters and emission rates for the emergency

diesel generator and fuel gas heater. The emergency diesel generator was included in the

modeling analysis for appropriate pollutants and averaging periods when used for

readiness testing (i.e., up to 30 minutes per day).


Parameter Values

Stack Height (m) 5.94

Stack Diameter (m) 0.30

Exhaust Velocity (m/s) 39.84

Exhaust Temperature (K) 721.5

Averaging Period 1-hr 3-hr 8-hr 24-hr Annual


NOx 0.3422 - - - 0.039

CO 0.683 - 0.085 - -

SO2 0.0004 0.00013 - 0.000015 0.00004

PM10/PM2.5 0.0061 - - 0.00025 0.00069

Notes:

Hourly emission rate divided by 2 to simulate limit of 30 minutes testing per day. For the 3-, 8- and 24-hour period the hourly emission rate is further divided by the number of hours in the period.



Parameter Values






NOx 0.015

CO 0.012

SO2 0.0008

PM10/PM2.5 0.0012


Table 3-5 presents the maximum modeled air quality concentrations of the proposed

facility calculated by AERMOD. As shown in this table, the maximum modeled

concentrations when combined with a representative background concentration, are less

than the applicable NAAQS/NYAAQS for all pollutants.


Pollutant Averaging

Period

NAAQS/

NYAAQS

(g/m3)

Maximum

Modeled

Concentration

(g/m3)

Background

Concentration

(g/m3)

Total

Concentration

(g/m3)

CO 1-Hour 40,000 312 2,070 2,382

8-Hour 10,000 89 1,495 1,584

SO2

1-Hour 196 1.8 21.0 22.8

3-Hour 1,300 1.7 23.6a 25.3

24-Hour -/260 0.8 13.9 14.7

Annual -/60 0.09 2.1 2.2

PM-10 24-Hour 150 2.1 45 47.1

PM-2.5 24-Hour 35 0.7 22.3 23.0

Annual 12 0.13 9.5 9.6

NO2 1-Hour 188 20.9b 75.8 96.7

Annual 100 1.6c 20.0 21.6

aConservatively based upon maximum 1-hour SO2 monitored concentration. bAssumed 80% of NOx is NO2 per USEPA guidance. cAssumed 75% of NOx is NO2 per USEPA guidance.



Air quality modeling was conducted for potential toxic (non-criteria) air pollutant

emissions from the proposed non-exempt facility sources. The modeling methodology

used in the toxic air pollutant analysis was the same as used in the DEC Part 201 air quality

analyses for criteria air pollutants. Maximum modeled short-term and annual ground

level concentrations of each toxic air pollutant were compared to the DEC’s short-term

guideline concentration (SGC) and annual guideline concentration (AGC), respectively.

The DEC SGCs and AGCs used in the analysis are listed in the DAR-1 (formerly Air

Guide-1) tables that were published by the DEC in February 2014.

Unit concentrations (ug/m3 per 1.0 g/s emitted) for the 1-hour and annual averaging

periods were calculated for the combustion turbine using AERMOD. The maximum toxic

air pollutant-specific emission rate was multiplied by the modeled unit concentration to

determine the maximum pollutant-specific concentration. Presented in Table 3-6 are the

NYSDEC SGCs and AGCs and the facility maximum modeled concentrations for each

toxic air pollutant. As shown in the table, all of the maximum modeled toxic air pollutants

are well below their corresponding NYSDEC SGC and AGC.


Table 3-6: Facility Maximum Modeled Concentrations Compared to SGCs and AGCs

Solar Titan 130E SGC AGC % of SGC % of AGC

1-Hour Annual 1-Hour Annual

Hazardous Air Pollutants (HAPs) (ug/m3) (ug/m3) (ug/m3) (ug/m3) % %

Acetaldehyde 4.51E-02 3.89E-04 470 0.45 0.01% 0.09%

Acrolein 7.22E-03 6.22E-05 2.5 0.35 0.29% 0.02%

Benzene 1.35E-02 1.17E-04 1,300 0.13 0.00% 0.09%

1,3-Butadiene 4.85E-04 4.18E-06 --- 0.033 --- 0.01%

Ethylbenzene 3.61E-02 3.11E-04 --- 1,000 --- 0.00%

Formaldehyde 8.01E-01 6.90E-03 30 0.06 2.67% 11.51%

Naphthalene 1.47E-03 1.26E-05 7,900 3 0.00% 0.00%

PAH 2.48E-03 2.14E-05 --- 0.02 --- 0.11%

Propylene Oxide 3.27E-02 2.82E-04 3,100 0.27 0.00% 0.10%

Toluene 1.47E-01 1.26E-03 37,000 5,000 0.00% 0.00%

Xylenes 7.22E-02 6.22E-04 22,000 100 0.00% 0.00%

Polycyclic Organic Compounds (POM)

Anthracene 8.99E-07 7.75E-09 --- 0.02 --- 0.00%

Benz(a)anthracene 6.74E-07 5.81E-09 --- 0.02 --- 0.00%

Chrysene 6.74E-07 5.81E-09 --- 0.02 --- 0.00%

Dibenzo(a,h)anthracene 4.49E-07 3.87E-09 --- 0.02 --- 0.00%

Fluorene 1.05E-06 9.04E-09 5.3 0.067 0.00% 0.00%

2-Methylnaphthalene 8.99E-06 7.75E-08 --- 7.1 --- 0.00%

Phenanthrene 6.37E-06 5.49E-08 --- 0.02 --- 0.00%

Pyrene 1.87E-06 1.61E-08 --- 0.02 --- 0.00%


3.7 References

NYSDEC, 2006. NYSDEC Guidelines on Dispersion Modeling Procedures for Air Quality

Impact Analysis – DAR 10. Impact Assessment and Meteorology Section, Bureau

of Stationary Sources. May 9, 2006.

USEPA, 2015. AERMOD Implementation Guide. AERMOD Implementation

Workgroup, Office of Air Quality Planning and Standards, Air Quality Assessment

Division, Research Triangle Park, North Carolina. August 3, 2015.

USEPA, 2014. Clarification on the Use of AERMOD Dispersion Modeling for

Demonstrating Compliance with the NO2 National Ambient Air Quality Standard.

USEPA. September 30, 2014.

USEPA, 2011. Additional Clarification Regarding Application of Appendix W Modeling

Guidance for the 1-Hour NO2 NAAQS. USEPA. March 1, 2011.

USEPA, 2005. Guideline on Air Quality Models (Revised). Appendix W to Title 40 U.S.

Code of Federal Regulations (CFR) Parts 51 and 52, Office of Air Quality Planning

and Standards, U.S. Environmental Protection Agency. Research Triangle Park,

North Carolina. November 6, 2005.

USEPA, 1992. "Screening Procedures for Estimating the Air Quality Impact of Stationary

Sources, Revised". EPA Document 454/R-92-019, Office of Air Quality Planning

and Standards, Research Triangle Park, North Carolina.

USEPA, 1990. "New Source Review Workshop Manual, Draft". Office of Air Quality

Planning and Standards, U.S. Environmental Protection Agency. Research

Triangle Park, North Carolina.

USEPA, 1985. Guidelines for Determination of Good Engineering Practice Stack Height

(Technical Support Document for the Stack Height Regulations-Revised). EPA-

450/4-80-023R. U.S. Environmental Protection Agency.


Hancock Compressor Station

Eastern System Upgrade Project

Ambient Air Quality Modeling Assessment

Prepared for:


Prepared by:



July 2016

Millennium Pipeline Company, LLC ii Ambient Air Quality Modeling Assessment Hancock Compressor Station


1.0 Introduction .......................................................................................................... 1-1

1.1 Project Overview ................................................................................................ 1-1

2.0 Project Description ................................................................................................2-2

2.1 Site Location and Surroundings ........................................................................2-2 2.2 Existing Facility Description and Emission Potential ......................................2-2 2.3 Facility Conceptual Design ................................................................................ 2-3

2.3.1 Compressor Turbine .................................................................................. 2-3 2.3.2 Ancillary Equipment .................................................................................. 2-5

2.4 Proposed Project Emission Potential ................................................................ 2-5


3.1 Background Ambient Air Quality ...................................................................... 3-7 3.2 Modeling Methodology .................................................................................... 3-8

3.2.1 Model Selection ......................................................................................... 3-8 3.2.2 Urban/Rural Area Analysis ........................................................................3-9 3.2.3 Good Engineering Practice Stack Height ................................................ 3-10 3.2.4 Meteorological Data ................................................................................. 3-11

3.3 Receptor Grid .................................................................................................. 3-11 3.3.1 Basic Grid ................................................................................................. 3-11 3.3.2 Property Line Receptors .......................................................................... 3-12 3.3.3 Selection of Sources for Modeling ........................................................... 3-12 3.3.4 Emission Rates and Exhaust Parameters ................................................ 3-13

3.4 Maximum Modeled Facility Concentrations .................................................. 3-16 3.5 Toxic Ambient Air Contaminant Analysis ...................................................... 3-17 3.6 References ........................................................................................................ 3-19

LIST OF TABLES

Table 2-1: Existing Facility Emissions .......................................................................................................... 2-2 Table 2-2: Proposed Facility Emissions ....................................................................................................... 2-6 Table 3-1: Maximum Measured Ambient Air Quality Concentrations ....................................................... 3-7 Table 3-2: Stack Parameters and Emission Rates – Existing Solar Mars 100 Compressor Turbine ....... 3-14 Table 3-3: Stack Parameters and Emission Rates – Proposed Titan 130E Compressor Turbine ............ 3-14 Table 3-4: Stack Parameters and Emission Rates – Existing Emergency Generator .............................. 3-15 Table 3-5: Stack Parameters and Emission Rates – Proposed Emergency Generator ............................ 3-15 Table 3-6: Stack Parameters and Emission Rates – Proposed Fuel Gas Heater ...................................... 3-16 Table 3-7: Facility Maximum Modeled Concentrations Compared to NAAQS/NYAAQS ....................... 3-16 Table 3-8: Facility Maximum Modeled Concentrations Compared to SGCs and AGCs .......................... 3-18

Millennium Pipeline Company, LLC 1-1 Ambient Air Quality Modeling Assessment Hancock Compressor Station

1.0 INTRODUCTION


Millennium is seeking authorization from the Federal Energy Regulatory Commission

(FERC or Commission) pursuant to Section 7(c) of the Natural Gas Act to construct,

install, operate, and maintain the Eastern System Upgrade (Project). The purpose of the

Project is to permit Millennium to transport an incremental volume of approximately

223,000 dekatherms per day of natural gas from Millennium’s Corning Compressor

Station to an existing interconnect with Algonquin Gas Transmission, L.L.C. (Algonquin)

located in Ramapo, New York. As part of the Eastern System Upgrade Project and in

order to boost pressures on Millennium’s transmission pipeline system, Millennium is

proposing to construct and operate one Solar Titan 130E compressor turbine (22,400 hp

(ISO)) at the Hancock Compressor Station. Ancillary project emission sources include

one (1) 1,230 hp Waukesha VGF48GL emergency generator, one (1) 1.2 MMBtu/hr gas

heater, and one (1) 1,500 gallon oil tank. The Hancock CS is an existing non-major facility

that was constructed under and operates according to NYSDEC Air State Facility Permit

ID: 4-1236-00708/00001.

At the federal level, because the emission increases from the Hancock Station

modifications are less than applicable major source thresholds, Millennium will not

trigger federal NSR requirements for any regulated air pollutant under either PSD or

NNSR permitting programs. At the state level, the Project triggers air permitting through

the NYSDEC as a major Title V facility for CO and GHGs. If the agency considers that any

project triggering minor NSR permitting could threaten attainment with the National

Ambient Air Quality Standards (NAAQSs) or human health from toxic air pollutant (TAP)

concentrations, NYSDEC can require air dispersion modeling for the Project. A site wide

modeling analysis for criteria pollutants has been performed in accordance with their

impact analysis modeling guidance, Policy DAR‐10. In addition, a modeling analysis that

addresses TAPs is performed per Policy DAR‐1. This report details the NAAQS and TAPs

modeling assessment for the proposed Hancock Station.




The existing Hancock Compressor Station is located in a rural area in the town of

Hancock, Delaware County, New York. The site is currently developed, consisting of

components of the existing Hancock Compressor Station.

The approximate Universal Transverse Mercator (UTM) coordinates of the facility are:

488,200 meters east and 4,636,900 meters north in Zone 18 (North American Datum of

1983(NAD83)).

2.2 Existing Facility Description and Emission Potential

Air emissions from the existing facility are permitted under NYSDEC Air State Facility

Permit ID: 4-1236-00708/00001, which became effective on March 18, 2013. The facility‐

wide potential‐to‐emit of the Hancock compressor station is as summarized in the

following Table 2-1.


Pollutant

Solar Mars 100

Turbine

Exempt (1)

Waukesha

VGF36GL

880 hp

Emergency

Generator

Exempt (2)

Waste Liquids

Storage Tank (4,000 gal)

Trivial (3)

Station Blowdowns

Existing Facility

Total

NOx 34.24 0.97 - - 35.21

VOC 3.94 0.49 2.41 0.17 7.01

CO 47.62 1.94 - - 49.56

SO2 8.26 0.001 - - 8.26

PM10/PM2.5 12.47 0.02 - - 12.49

GHG(4) 69,319 219 - 675 70,212

HAPs 0.61 0.13 - 0.09 0.83

Individual HAP(5)

0.42

0.10

-

-

0.52



Pollutant

Solar Mars 100

Turbine

Exempt (1)

Waukesha

VGF36GL

880 hp

Emergency

Generator

Exempt (2)

Waste Liquids

Storage Tank (4,000 gal)

Trivial (3)

Station Blowdowns

Existing Facility

Total

(1) Exempt per 201-3.2(c)(6) for emergency power generating stationary internal combustion engines which meet the

requirements of 200.1(cq) of operation when the usual source of electric power is unavailable and no more than 500

hours per year inclusive of emergency operation, testing, and maintenance.

(2) Exempt per 201-3.2(c)(25) for storage tanks under 10,000 gallons, not otherwise subject to Parts 229 or 233

(3) Trivial per 201-3.3(94) for emissions of “….oxygen, carbon dioxide, nitrogen, simple asphyxiants including methane and

propane, trace constituents included in raw materials or byproducts, where the constituents are less than 1 percent by

weight for any regulated air pollutant, or 0.1 percent by weight for any carcinogen listed by the United States

Department of Health and Human Services’ Seventh Annual Report on Carcinogens (1994). The definition of

“regulated air pollutant” under 200.1(bu) does not include methane or ethane.




As a part of the Eastern System Upgrade project, Millennium is proposing to install the

following new equipment at the Hancock compressor station:

One new Solar Titan 130-22402S, 22,400 HP (ISO) natural gas fired turbine‐

driven compressor unit;

One new Waukesha VGF48GL (1,230 hp) natural gas fired emergency generator;

One new 1.2 MMBtu/hr heat input natural gas fired fuel gas heater; and

One new 1,500 gallon oil storage tank

The new Waukesha (1,230 hp) emergency generator has a four stroke, lean burn, natural

gas‐fired stationary reciprocating internal combustion engine. The proposed emergency

generator will be installed to meet site wide emergency electrical demands as a result of

the Eastern System Upgrade project and will be operated only during normal testing,

maintenance, and emergency situations.


The proposed Solar Titan 130E natural gas-fired turbine to be installed at the Hancock

Compressor Station will be equipped with Solar’s SoLoNOx dry low NOx combustor


technology for NOx control. Emissions for the Solar Turbine assumes that the unit will

operate up to 8,760 hours per year and up to 100% rated output. The vendor provided

emission rates for normal operating conditions are as follows (all emissions rates are in

terms of parts per million dry volume (ppmvd) @ 15% O2):

• 15 ppmvd NOx;

• 25 ppmvd CO;


• 5 ppmvd VOC.

Depending upon demand, the turbine may operate at loads ranging from 50% to 100% of

full capacity. Because of the different emission rates and exhaust characteristics that

occur at different loads and ambient temperatures, a matrix of operating modes is

presented. Emission parameters for three turbine loads (50%, 75%, and 100%) and six

ambient temperatures (0oF, 20oF, 40oF, 60oF, 80oF and 100oF) are accounted for in this

air quality assessment to cover the range of steady-state turbine operations.

At very low load and cold temperature extremes, the turbine system must be controlled

differently in order to assure stable operation. The required adjustments to the turbine

controls at these conditions cause emissions of NOx, CO and VOC to increase (emission

rates of other pollutants are unchanged). Low-load operation (non-normal SoLoNOx

operation) of the turbines is expected to occur only during periods of startup and

shutdown and for maintenance or unforeseen emergency events. The annual hours of

operation during low load operation was assumed to be not more than 10 hours per year.

Similarly, Solar has provided emission estimates for low temperature operation (inlet

combustion air temperature less than 0° F and greater than -20° F). Estimated pre-

control emissions from the turbines at low temperature conditions are:

• 120 ppmvd NOx;

• 150 ppmvd CO;


• 10 ppmvd VOC.

Millennium reviewed historic meteorological data from the previous five years for the

region to estimate the worst case number of hours per year under sub-zero (less than 0°

F) conditions. The annual hours of operation during sub-zero conditions was assumed to

be not more than 120 hours per year.


Turbine emission rates during start-up and shutdown events increase for NOx, CO and

VOC as compared to operating above 50% load. The start-up process for the Solar Titan

130E turbine takes approximately 10 minutes from the initiation of start-up to normal

operation (equal to or greater than 50% load). Shutdown takes approximately 10

minutes. Millennium has estimated there would be 100 start-up/shutdown events per

year.


Millennium is proposing to install a new Waukesha VGF48GL (1,230 hp) four stroke lean

burn natural gas fired emergency generator. The emergency generator will operate for no

more than 500 hours/year, and therefore meets the definition of an “emergency power

generating stationary internal combustion engine” under 6 NYCRR 200.1(cq). As

previously indicated, the generator is an exempt source per 6 NYCRR 201‐3.2(c)(6),



Millennium is proposing to install one new 1.2 MMBtu/hr (heat input) natural gas heater.

As previously indicated, the heater is an exempt source per 6 NYCRR 201‐3.2(c)(1)(i),




Table 2-2 presents project emission potentials from the new and modified units to be

installed as a part of the proposed modifications at Hancock. For new units, project

emission potential is equal to potentials to emit. For modified and existing units, the

project emission potential equals the potential emissions of the unit minus baseline actual

emissions. Per 6 NYCRR 231‐4.1(b)(41)(ii), potential emissions are used in place of

projected actual emissions. For the existing, unmodified units with associated emission

increases, project emission potential may be calculated as projected actual emissions

minus baseline actual emissions. However, project emission potential is conservatively

set equal to potential emissions.


Table 2-2: Proposed Facility Emissions

Pollutant

Solar Titan 130E

Turbine

Exempt Waukesha

Emergency

Generator

Exempt Fuel Gas Heater

Trivial Station

Blowdowns

Trivial Station

Fugitives

Proposed Project

Total

NOx 47.92 1.36 0.53 - - 49.80

VOC 5.45 0.68 0.03 0.04 0.88 7.08

CO 77.28 2.71 0.44 - - 80.44

SO2 4.51 0.015 0.030 - - 4.54

PM10/PM2.5 12.10 0.04 0.04 - - 12.16

CO2e 94,373 285 631 573 14,012 109,874

HAPs 2.45 0.18 0.01 - - 2.63

Maximum

Individual HAP

(Formaldehyde)

1.69 0.13 0.0003 - -

1.82

Millennium Pipeline Company LLC 3-7 Ambient Air Quality Modeling Assessment Hancock Compressor Station



Background ambient air quality data was obtained from various existing monitoring

locations. Based on a review of the locations of Pennsylvania and New York ambient air

quality monitoring sites, the closest monitoring sites were used to represent the current

background air quality in the site area.

Background data for CO, NO2, and PM2.5 was obtained from a monitoring station located

in Lackawanna County, Pennsylvania (USEPA AIRData # 42-069-2006). This monitor

is located in the city of Scranton that has a higher population density and higher density

of industrial facilities than the Hancock area in Delaware County. Further, this monitor

is located in an area with a greater amount of mobile and point sources of air emissions

as compared to the project area. Thus, this monitor is considered to conservatively

represent the ambient air quality within the project area.

Background data for SO2 and PM10 was obtained from a monitoring station located in

Luzerne County, Pennsylvania (USEPA AIRData # 42-079-1101). This monitor is located

in city of Wilkes Barre that has a higher population density and higher density of

industrial facilities than the area around the Hancock Station. Further, this monitor is


compared to the project area. Thus, this monitor is also considered to conservatively

represent the ambient air quality within the project study area.

The monitoring data for the most recent three years (2012 – 2014) are presented and

compared to the NAAQS in Table 3-1. The maximum measured concentrations for each

of these pollutants during the last three years are all below applicable standards and are

used as representative background values for comparison of facility concentrations to the

NAAQS.


Pollutant Averaging

Period


(g/m3) NAAQS

(g/m3) 2012 2013 2014

SO2 1-Houra

24-Hour

21.0

13.6

18.3

13.6

23.6

13.9

196

365



Pollutant Averaging

Period


(g/m3) NAAQS

(g/m3) 2012 2013 2014

Annual 2.1 1.4 2.1 80

NO2 1-Hourb

Annual

67.7

16.1

75.2

15.4

84.6

20.0

188

100

CO 1-Hour

8-Hour

1,380

920

2,070

1,495

1,725

1,150

40,000

10,000

PM10 24-Hour 34 45 32 150

PM2.5c 24-Hour

Annual

20

8.3

24

9.2

23

11.1

35

12 a1-hour 3-year average 99th percentile value for SO2 is 21.0 g/m3. b1-hour 3-year average 98th percentile value for NO2 is 75.8 g/m3. c24-hour 3-year average 98th percentile value for PM-2.5 is 22.3 g/m3; Annual 3-year average value for

PM2.5 is 9.5 g/m3.

High second-high short term (1-, 3-, 8-, and 24-hour) and maximum annual average concentrations

presented for all pollutants other than PM2.5 and 1-hour SO2 and NO2.

Bold values represent the proposed background values for use in any necessary NAAQS/NYAAQS

analyses.

Monitored background concentrations obtained from the USEPA AirData website

(https://www3.epa.gov/airdata/).


An air quality modeling analysis was performed consistent with the procedures found in

the following documents: Guideline on Air Quality Models (Revised) (USEPA, 2005),

New Source Review Workshop Manual (USEPA, 1990), Screening Procedures for

Estimating the Air Quality Impact of Stationary Sources (USEPA, 1992), and DAR-10:

NYSDEC Guidelines on Dispersion Modeling Procedures for Air Quality Impact Analysis

(NYSDEC, 2006).

3.2.1 Model Selection The USEPA has compiled a set of preferred and alternative computer models for the

calculation of pollutant impacts. The selection of a model depends on the characteristics

of the source, as well as the nature of the surrounding study area. Of the four classes of

https://www3.epa.gov/airdata/


models available, the Gaussian type model is the most widely used technique for

estimating the impacts of nonreactive pollutants.

The AERMOD model was designed for assessing pollutant concentrations from a wide

variety of sources (point, area, and volume). AERMOD is currently recommended by the

USEPA for modeling studies in rural or urban areas, flat or complex terrain, and transport

distances less than 50 kilometers, with one hour to annual averaging times.

The latest version of USEPA’s AERMOD model (Version 15181) was used in the analysis.

AERMOD was applied with the regulatory default options and 5-years (2011-2015) of

hourly meteorological data consisting of surface observations from Binghamton Edwin A

Link Field in Binghamton, NY and concurrent upper air data from Albany, NY.


A land cover classification analysis was performed to determine whether the URBAN

option in the AERMOD model should be used in quantifying ground-level concentrations.

The methodology utilized to determine whether the project is located in an urban or rural

area is described below.

The following classifications relate the colors on a United States Geological Survey

(USGS) topographic quadrangle map to the land use type that they represent:

Blue – water (rural);

Green – wooded areas (rural);

White – parks, unwooded, non-densely packed structures (rural);

Purple – industrial; identified by large buildings, tanks, sewage disposal or

filtration plants, rail yards, roadways, and, intersections (urban);

Pink – densely packed structures (urban); and,

Red – roadways and intersections (urban)

The USGS map covering the area within a 3-kilometer radius of the facility was reviewed

and indicated that the vast majority of the surrounding area is denoted as blue, green, or

white, which represent water, wooded areas, parks, and non-densely packed structures.

Additionally, the “AERMOD Implementation Guide” published on August 3, 2015

cautions users against applying the Land Use Procedure on a source-by-source basis and

instead to consider the potential for urban heat island influences across the full modeling


domain. This approach is consistent with the fact that the urban heat island is not a

localized effect, but is more regional in character.

Because the urban heat island is more of a regional effect, the Urban Source option in

AERMOD was not utilized since the area within 3 kilometers of the facility as well as the

full modeling domain (20 kilometers by 20 kilometers) is predominantly rural.


Section 123 of the Clean Air Act (CAA) required the USEPA to promulgate regulations to

assure that the degree of emission limitation for the control of any air pollutant under an

applicable State Implementation Plan (SIP) was not affected by (1) stack heights that

exceed Good Engineering Practice (GEP) or (2) any other dispersion technique. The

USEPA provides specific guidance for determining GEP stack height and for determining

whether building downwash will occur in the Guidance for Determination of Good

Engineering Practice Stack Height (Technical Support Document for the Stack Height

Regulations), (USEPA, 1985). GEP is defined as “…the height necessary to ensure that

emissions from the stack do not result in excessive concentrations of any air pollutant in

the immediate vicinity of the source as a result of atmospheric downwash, eddies, and

wakes that may be created by the source itself, or nearby structures, or nearby terrain

“obstacles”.”

The GEP definition is based on the observed phenomenon of atmospheric flow in the

immediate vicinity of a structure. It identifies the minimum stack height at which

significant adverse aerodynamics (downwash) are avoided. The USEPA GEP stack height

regulations (40 CFR 51.100) specify that the GEP stack height (HGEP) be calculated in the

following manner:

HGEP = HB + 1.5L

Where: HB = the height of adjacent or nearby structures, and

L = the lesser dimension (height or projected width


A GEP stack height analysis has been conducted using the USEPA approved Building

Profile Input Program with PRIME (BPIPPRM, version 04274). The maximum

calculated GEP stack height for the new emission sources is 131 feet; the controlling

structure is the existing compressor building (52.5 feet). Direction-specific downwash

parameters were determined using BPIPPRM, version 04274.



If at least one year of hourly on-site meteorological data is not available, the application

of the AERMOD dispersion model requires five years of hourly meteorological data that

are representative of the project site. In addition to being representative, the data must

meet quality and completeness requirements per USEPA guidelines. The closest source

of representative hourly surface meteorological data is Binghamton Edwin A Link Field

located in Binghamton, NY located approximately 48 miles to the northwest of the

Hancock Compressor Station.

The meteorological data at the Binghamton Edwin A Link Field is recorded by an

Automated Surface Observing System (ASOS) that records 1-minute measurements of

wind direction and wind speed along with hourly surface observations necessary. The

USEPA AERMINUTE program was used by the NYSDEC to process 1-minute ASOS wind

data (2011 – 2015) from the Binghamton surface station in order to generate hourly

averaged wind speed and wind direction data to supplement the standard hourly ASOS

observations. The hourly averaged wind speed and direction data generated by

AERMINUTE was merged with the aforementioned hourly surface data.

The AERMOD assessment utilized five (5) years (2011–2015) of concurrent

meteorological data collected from a meteorological tower at the Binghamton Edwin A

Link Field and from radiosondes launched from Albany, New York. Both the surface and

upper air sounding data were processed by the NYSDEC using AERMOD’s meteorological

processor, AERMET (version 15181). The output from AERMET was used as the

meteorological database for the modeling analysis and consists of a surface data file and

a vertical profile data file. These data, which were prepared and processed to AERMOD

format by the NYSDEC, was provided for use in the modeling analyses for the proposed

facility.

3.3 Receptor Grid

3.3.1 Basic Grid

The AERMOD model requires receptor data consisting of location coordinates and

ground-level elevations. The receptor generating program, AERMAP (Version 11103),

was used to develop a complete receptor grid to a distance of 10 kilometers from the

proposed facility. AERMAP uses digital elevation model (DEM) or the National Elevation

Dataset (NED) data obtained from the USGS. The preferred elevation dataset based on


NED data was used in AERMAP to process the receptor grid. This is currently the

preferred data to be used with AERMAP as indicated in the USEPA AERMOD

Implementation Guide published August 3, 2015. AERMAP was run to determine the

representative elevation for each receptor using 1/3 arc second NED files that were

obtained for an area covering at least 10 kilometers in all directions from the proposed

facility. The NED data was obtained through the USGS Seamless Data Server

(http://seamless.usgs.gov/index.php).

The following rectangular (i.e. Cartesian) receptors were used to assess the air quality

impact of the proposed facility:

Consistent with DAR-10 guidance, fine grid receptors (70 meter spacing) for a 20

km (east-west) x 20 km (north-south) grid centered on the proposed facility site.


The facility has a fenced property line that precludes public access to the site. Ambient

air is therefore defined as the area at and beyond the fence. The modeling receptor grid

includes receptors spaced at 25-meter intervals along the entire fence line. Any Cartesian

receptors located within the fence line were removed.

3.3.3 Selection of Sources for Modeling

The emission sources responsible for most of the potential emissions from the Hancock

Compressor Station are the two (2) combustion turbines. These units were included in

and are the main focus of the modeling analyses. The modeling includes consideration of

operation over a range of turbine loads, ambient temperatures, and operating scenarios.

Ancillary sources (emergency diesel generators and fuel gas heater) were included in the

modeling for appropriate pollutants and averaging periods. The emergency equipment

may operate for up to 30 minutes in any day for readiness testing and maintenance

purposes. Operation of the emergency equipment for longer periods of time in an

emergency mode will not be expected to occur when the turbines are operating.

Although only limited operation is expected from the emergency equipment, initial

modeling to assess short-term facility impacts assumed concurrent operation of the

emergency equipment for readiness testing (i.e., up to 30 minutes per day) with the

combustion turbines.



The dispersion modeling analysis was conducted with emission rates and flue gas exhaust

characteristics (flow rate and temperature) that are expected to represent the range of

possible values for the proposed and existing natural gas fired turbines. Because emission

rates and flue gas characteristics for a given turbine load vary as a function of ambient

temperature and fuel use, data were derived for a number of ambient temperature cases

for natural gas fuel at 100%, 75% and 50% operating loads. The temperatures were:

• <0°F, 0°F, 20°F, 40°F, 60°F, 80°F and 100°F.

To be conservative and limit the number of cases to be modeled, the short-term modeling

analysis was conducted using the lowest stack exhaust temperature and exit velocity

coupled with the maximum emission rate over all ambient temperature cases for each

operating load (with the exception of 1-hour NO2 modeling which excluded the <0ºF data

as discussed below). Annual modeling was based on the 100% load 40°F case (vendor

performance data for the turbine was available for 40°F and 60°F). The annual average

temperature for the project area is approximately 50°F. Use of the 40ºF emissions data

is conservative as emissions are slightly higher than the 60°F case.). Tables 3-2 and 3-3

summarize the stack parameters and emission rates used in the modeling for the

compressor turbines.

Note that the modeling for 1-hour NO2 excluded the emergency generator for which

normal operations (maintenance purposes only) will be limited to no more than 30

minutes per day with an annual limit of 100 hours per year for testing and maintenance

purposes. The 1-hour NO2 modeling also did not consider combustion turbine operations

under sub-zero ambient temperature conditions as these conditions are extremely limited

annually. The exclusion of the emergency generator and sub-zero operations for the

combustion turbines for the 1-hour NO2 modeling is based on USEPA guidance provided

in the March 1, 2011 memorandum, “Additional Clarification Regarding Application of

Appendix W Modeling Guidance for the 1-hour NO2 National Ambient Air Quality

Standard” for intermittent sources such as emergency generators. In the memo, US EPA

states the following:

“Given the implications of the probabilistic form of the 1-hour NO2 NAAQS discussed above, we are concerned that assuming continuous operation of intermittent emissions would effectively impose an additional level of stringency beyond that level intended by the standard itself. As a result, we feel it would be inappropriate to implement the 1-hour NO2 standard in such a manner and


recommend that compliance demonstrations for the 1-hour NO2 NAAQS be based on emission scenarios that can logically be assumed to be relatively continuous or which occur frequently enough to contribute significantly to the annual distribution of daily maximum 1-hour concentrations.”

The emergency generator and sub-zero operation of the combustion turbine are

considered as intermittent emissions, and thus, were excluded from the 1-hour NO2

modeling assessment.

Table 3-2: Stack Parameters and Emission Rates – Existing Solar Mars 100 Compressor Turbine

Parameter Values

Load 50% 75% 100% Annual(2) Stack Height (m) 18.29 18.29 18.29 18.29

Stack Diameter (m)(1) 2.72 2.72 2.72 2.72




NOx 0.6886 0.8632 0.9236 0.9850

CO 4.5110 5.2552 5.7442 --

SO2 0.1866 0.2174 0.2376 0.2376

PM10/PM2.5 0.2818 0.3283 0.3588 0.3588

(1) The turbine stack is square (95 inches x 95 inches). The value listed and used in the modeling is the effective diameter for an equivalent area circular stack.

(2) Based on conservative annual average exhaust parameters for 40ºF and annual potential to emit discussed in Section 2.


Parameter Values

Load 50% 75%

100% Annual(2) Stack Height (m) 21.34 21.34 21.34 21.34

Stack Diameter (m)(1) 2.92 2.92 2.92 2.92




NOx 0.858 1.063 1.254 1.375

CO 5.224 6.471 7.628 -

SO2 0.094 0.113 0.130 0.130

PM10/PM2.5 0.251 0.304 0.348 0.348

(1) (1) The turbine stack is square (102 inches x 102 inches). The value listed and used in the modeling is the effective diameter for an equivalent area circular stack.

(2) (2) Based on conservative annual average exhaust parameters for 40ºF and annual potential to emit discussed in Section 2.


Tables 3-4 through 3-6 present the stack parameters and emission rates for the

emergency diesel generators and fuel gas heater. The emergency diesel generators were

included in the modeling analysis for appropriate pollutants and averaging periods when

used for readiness testing (i.e., up to 30 minutes per day).

Table 3-4: Stack Parameters and Emission Rates – Existing Emergency Generator

Parameter Values







NOx 0.24 -- -- -- 0.028

CO 0.49 -- 0.061 -- --

SO2 2.77E-04 9.22E-05 -- 1.15E-05 3.16E-05

PM10/PM2.5 -- -- -- 1.96E-04 5.47E-04

Notes:

Hourly emission rates divided by 2 to simulate limit of 30 minutes testing per day. For the 3-, 8- and 24-hour period the hourly emission rate is further divided by the number of hours in the period.


Parameter Values







NOx 0.3422 - - - 0.039

CO 0.683 - 0.085 - -

SO2 0.0004 0.00013 - 0.000017 0.00004

PM10/PM2.5 0.0061 - - 0.00025 0.00069

Notes:

Hourly emission rate divided by 2 to simulate limit of 30 minutes testing per day. For the 3-, 8- and 24-hour period the hourly emission rate is further divided by the number of hours in the period.



Parameter Values






NOx 0.015

CO 0.012

SO2 0.0008

PM10/PM2.5 0.0011


Table 3-7 presents the maximum modeled air quality concentrations of the proposed

facility calculated by AERMOD. Note that the modeling included the cumulative impacts

from both the existing station sources and the proposed Project sources. As shown in this

table, the maximum modeled concentrations when combined with a representative

background concentration, are less than the applicable NAAQS/NYAAQS for all

pollutants.


Pollutant Averaging

Period

NAAQS/

NYAAQS

(g/m3)

Maximum

Modeled

Concentration

(g/m3)

Background

Concentration

(g/m3)

Total

Concentration

(g/m3)

CO 1-Hour 40,000 452 2,070 2,522

8-Hour 10,000 192 1,495 1,687

SO2

1-Hour 196 9.2 21.0 30.2

3-Hour 1,300 8.9 23.6a 32.5

24-Hour -/260 5.2 13.9 19.1

Annual -/60 0.35 2.1 2.5

PM-10 24-Hour 150 7.8 45 52.8

PM-2.5 24-Hour 35 3.8 22.3 26.1

Annual 12 0.52 9.5 10.0

NO2 1-Hour 188 34.9b 75.8 110.7

Annual 100 5.0c 20.0 25.0

aConservatively based upon maximum 1-hour SO2 monitored concentration. bAssumed 80% of NOx is NO2 per USEPA guidance. cAssumed 75% of NOx is NO2 per USEPA guidance.



Air quality modeling was conducted for potential toxic (non-criteria) air pollutant

emissions from the proposed non-exempt facility sources. The modeling methodology

used in the toxic air pollutant analysis was the same as used in the DEC Part 201 air quality

analyses for criteria air pollutants. Maximum modeled short-term and annual ground

level concentrations of each toxic air pollutant were compared to the DEC’s short-term

guideline concentration (SGC) and annual guideline concentration (AGC), respectively.

The DEC SGCs and AGCs used in the analysis are listed in the DAR-1 (formerly Air Guide-

1) tables that were published by the DEC in February 2014.

Unit concentrations (ug/m3 per 1.0 g/s emitted) for the 1-hour and annual averaging

periods were calculated for the combustion turbines using AERMOD. The maximum

toxic air pollutant-specific emission rate was multiplied by the modeled unit

concentration to determine the maximum pollutant-specific concentration. Note that

summing the individual maximum source concentrations, regardless of time and location,

provides a conservative estimate of the actual toxic air pollutant concentrations resulting

from the facility. Presented in Table 3-8 are the NYSDEC SGCs and AGCs and the facility

maximum modeled concentrations for each toxic air pollutant. As shown in the table, all

of the maximum modeled toxic air pollutants are well below their corresponding NYSDEC

SGC and AGC.


Table 3-8: Facility Maximum Modeled Concentrations Compared to SGCs and AGCs

Solar Titan 130E Solar Mars 100 Facility Total SGC AGC % of SGC

% of AGC

1-Hour Annual 1-Hour Annual 1-Hour Annual 1-Hour Annual Hazardous Air Pollutants (HAPs) (ug/m3) (ug/m3) (ug/m3) (ug/m3) (ug/m3) (ug/m3) (ug/m3) (ug/m3) % %

Acetaldehyde 2.89E-02 3.01E-04 2.65E-02 3.35E-04 5.54E-02 6.36E-04 470 0.45 0.01% 0.14%

Acrolein 4.63E-03 4.82E-05 4.25E-03 5.37E-05 8.88E-03 1.02E-04 2.5 0.35 0.36% 0.03%

Benzene 8.67E-03 9.04E-05 7.96E-03 1.01E-04 1.66E-02 1.91E-04 1300 0.13 0.00% 0.15%

1,3-Butadiene 3.11E-04 3.24E-06 2.93E-04 3.70E-06 6.04E-04 6.94E-06 --- 0.033 --- 0.02%

Ethylbenzene 2.31E-02 2.41E-04 2.12E-02 2.68E-04 4.43E-02 5.09E-04 --- 1000 --- 0.00%

Formaldehyde 5.13E-01 5.35E-03 4.70E-01 5.94E-03 9.84E-01 1.13E-02 30 0.06 3.28% 18.82%

Naphthalene 9.39E-04 9.80E-06 8.80E-04 1.11E-05 1.82E-03 2.09E-05 7900 3 0.00% 0.00%

PAH 1.59E-03 1.66E-05 1.47E-03 1.85E-05 3.06E-03 3.51E-05 --- 0.02 --- 0.18%

Propylene Oxide 2.10E-02 2.19E-04 1.92E-02 2.43E-04 4.02E-02 4.61E-04 3100 0.27 0.00% 0.17%

Toluene 9.39E-02 9.80E-04 8.61E-02 1.09E-03 1.80E-01 2.07E-03 37000 5000 0.00% 0.00%

Xylenes 4.63E-02 4.82E-04 4.24E-02 5.36E-04 8.87E-02 1.02E-03 22000 100 0.00% 0.00%

Polycyclic Organic Compounds (POM)

Anthracene 5.76E-07 6.01E-09 1.53E-06 1.93E-08 2.10E-06 2.53E-08 --- 0.02 --- 0.00%

Benz(a)anthracene 4.32E-07 4.50E-09 1.14E-06 1.45E-08 1.58E-06 1.90E-08 --- 0.02 --- 0.00%

Chrysene 4.32E-07 4.50E-09 1.14E-06 1.45E-08 1.58E-06 1.90E-08 --- 0.02 --- 0.00% Dibenzo(a,h)anthracen

e 2.88E-07 3.00E-09 7.63E-07 9.64E-09 1.05E-06 1.26E-08 --- 0.02 --- 0.00%

Fluorene 6.72E-07 7.01E-09 1.78E-06 2.25E-08 2.45E-06 2.95E-08 5.3 0.067 0.00% 0.00%

2-Methylnaphthalene 5.76E-06 6.01E-08 1.53E-05 1.93E-07 2.10E-05 2.53E-07 --- 7.1 --- 0.00%

Phenanthrene 4.08E-06 4.25E-08 1.08E-05 1.36E-07 1.49E-05 1.79E-07 --- 0.02 --- 0.00%

Pyrene 1.20E-06 1.25E-08 3.18E-06 4.01E-08 4.38E-06 5.27E-08 --- 0.02 --- 0.00%


3.6 References

NYSDEC, 2006. NYSDEC Guidelines on Dispersion Modeling Procedures for Air Quality

Impact Analysis – DAR 10. Impact Assessment and Meteorology Section, Bureau

of Stationary Sources. May 9, 2006.

USEPA, 2015. AERMOD Implementation Guide. AERMOD Implementation

Workgroup, Office of Air Quality Planning and Standards, Air Quality Assessment

Division, Research Triangle Park, North Carolina. August 3, 2015.

USEPA, 2014. Clarification on the Use of AERMOD Dispersion Modeling for

Demonstrating Compliance with the NO2 National Ambient Air Quality Standard.

USEPA. September 30, 2014.

USEPA, 2011. Additional Clarification Regarding Application of Appendix W Modeling

Guidance for the 1-Hour NO2 NAAQS. USEPA. March 1, 2011.

USEPA, 2005. Guideline on Air Quality Models (Revised). Appendix W to Title 40 U.S.

Code of Federal Regulations (CFR) Parts 51 and 52, Office of Air Quality Planning

and Standards, U.S. Environmental Protection Agency. Research Triangle Park,

North Carolina. November 6, 2005.

USEPA, 1992. "Screening Procedures for Estimating the Air Quality Impact of Stationary

Sources, Revised". EPA Document 454/R-92-019, Office of Air Quality Planning

and Standards, Research Triangle Park, North Carolina.

USEPA, 1990. "New Source Review Workshop Manual, Draft". Office of Air Quality

Planning and Standards, U.S. Environmental Protection Agency. Research

Triangle Park, North Carolina.

USEPA, 1985. Guidelines for Determination of Good Engineering Practice Stack Height

(Technical Support Document for the Stack Height Regulations-Revised). EPA-

450/4-80-023R. U.S. Environmental Protection Agency.

Resource Report 9 – Air and Noise Quality 9E-i Eastern System Upgrade

APPENDIX 9E

HDD Construction Noise Assessment


HOOVER & KEITH INC.

Acoustics & Noise Control Engineering

11391 MEADOWGLEN, SUITE I HOUSTON, TEXAS 77082 281-496-9876

Subject: HDD Construction Noise Assessment (Eastern System Upgrade)

Prepared for: Millennium Pipeline Company, L.L.C.

H&K Report No. 3356 / H&K Job No. 4982

Date of Report: July 27, 2016

Submitted by: Brian R. Hellebuyck, P.E., Hoover & Keith Inc. (“H&K”)

1.0 INTRODUCTION

The following report provides the results of an acoustical assessment of four1 horizontal directional

drilling (“HDD”) sites associated with the Millennium Pipeline Company, L.L.C. (Millennium) Eastern

System Upgrade (Project). The HDD construction technique is an alternative to traditional "open cut"

construction and is itself an "environmental mitigative measure" for avoiding foreign pipelines, utilities

and water bodies. The purpose of the acoustical assessment is to estimate the sound contribution of

drilling operations at the closest noise-sensitive areas (“NSAs”), such as residences, schools or

hospitals, and present noise mitigation measures to minimize the noise impact of HDD activities if

warranted.

2.0 SOUND CRITERIA and WORK SCHEDULE

A 55 dBA Ldn sound level contribution, resulting from HDD drilling operations, at nearby NSAs is

typically utilized by the Federal Energy Regulatory Commission (“FERC”) as a guideline and/or criteria

when HDD operations could be employed for a 24-hour workday. For 24-hour HDD drilling activities,

FERC also requires mitigation measures to minimize the noise impact of 24-hour HDD activities.

State and Local Noise Standards

There are no State of New York2 noise regulations for the HDD construction noise. We are

unaware of any Orange County construction noise regulations. The Town of Deerpark has a

noise ordinance. The text from Section 230-19 is included on page D-1. The Town of Deerpark has a

noise ordinance. The text from Article VIII is included on page D-1.

1 HDD #3A and HDD #3B may also be denoted as HDD #3 in other documents, as Millennium may choose to perform HDD #3A and HDD #3B as a single longer HDD, which would be denoted as HDD #3. 2 The NYSDEC has a Policy Document (i.e., Program Policy DEP-00-1; Revised Feb. 2, 2001, “Assessing and Mitigating Noise Impacts”) to provide guidance and clarify program issues for NYSDEC staff to ensure compliance with statutory and regulatory requirements for facility operations regulated under New York State Environmental Quality Reviews or “SEQR”.

Millennium Pipeline Company, L.L.C. Hoover & Keith Inc. Eastern System Upgrade H&K Job No. 4982 HDD Construction Noise Assessment H&K Report No. 3356 (07/15/16)

-2-

Work Schedule

Millennium intends to employ a 24-hour per day HDD construction schedule for the Project HDDs.

For the reader’s information, a summary of applicable acoustical terminology in this report and

description of typical metrics used to measure/regulate environmental noise is provided on page E-1.

3.0 DESCRIPTION OF HDD SITES

Figures 1-3 (pp. A-1 to A-3) provide an area layout around the HDD crossings with the HDD entry and

exit points and the closest NSAs. The following Table A summarizes the observed nearby NSAs to

each HDD entry/exit point, the distance/direction of the nearby (closest) NSAs and observed

obstructions between the HDD site and the respective NSA that could provide additional attenuation of

the HDD noise.

Fig. 1

(p. A-1)

Fig. 1

(p. A-1)

Fig. 2

(p. A-2)

Fig. 2

(p. A-2)

Fig. 3

(p. A-3)

Fig. 3

(p. A-3)

Fig. 3

(p. A-3)

Fig. 3

(p. A-3)450 ft. W to N

Some shielding by

foliage

HDD #3B

Entry

1,750 ft.

NSA #3

(Residence)

ExitNSA #2

(Residences)

NSA #3

(Residence)170 ft. NE Clear line of sight

HDD #3A

Entry/Exit

3,400 ft.

NSA #1

(Residences)500 ft. E to SE

Partially shielded by

foliage& terrain

Entry

Approx.

Distance

from

Entry to

Exit Sites

NSA #2

(Residences)

NSA #2

(Residences)950 ft. NW

Some shielding by

foliage

Ref.

Figure in

Report

1,100 ft. SE Shielded by terrain

Shielded by foliage

and terrain

Entry/Exit 600 ft. SWMinimal shielding

from foliage

4,100 ft.

HDD No. Distance &

Direction of

Closest NSA

Obstructions

between NSA &

HDD

Entry/ExitNSA #1

(Residences)

Entry or

Exit Point

NSA and

Type of NSA

2,000 ft.

1,000 ft. SW

150 ft. NE Clear line of sight

HDD #1

HDD #2

NSA #1

(Residence)

Entry/Exit

Entry/Exit

Table A: Eastern System Upgrade HDDs - Distance/Direction of the Closest NSA(s) within ½ mile

to each Respective HDD Entry/Exit Site and Other Related Information

4.0 AMBIENT SOUND SURVEYS AND MEASUREMENT METHODOLOGY

Ambient sound measurements and verification of the NSAs around the HDD site were performed by

Hoover & Keith on December 16, 2015 and April 27, 2016. Ambient sound levels were measured

near the closest NSA(s) to each respective HDD site. Ambient sound level data, for each HDD site is

provided on pp. C-1 to C-6.


-3-

5.0 ACOUSTICAL ASSESSMENT AND HDD EQUIPMENT

The spreadsheet analyses (i.e., acoustical calculations) of the estimated A-wt. sound level contributed

by the HDD operations during peak operating conditions associated with the HDD sites at the closest

NSA are provided in Tables 1 – 8 (pp. B-1 to B-4). For those HDD sites (i.e., entry or exit location) in

closer proximity to residences, the acoustical assessment predicts the noise contribution of HDD

operations if additional noise mitigation measures are employed. For reference, a description of the

acoustical analysis methodology and the source of sound data are provided on pages B-5 & B-6.

The following denotes the typical equipment at the HDD or direct pipe entry site and most of the listed

equipment are considered noise sources associated with drilling operations:

Drilling rig and engine-driven hydraulic power unit (i.e., most significant noise source); for the

direct pipe method, the :drilling rig” is defined as a “tunneling machine”, which also includes a

hydraulic power unit powered by an enclosed generator;

Engine-driven mud pump(s) and other engine-driven generator set(s);

Mud mixing/cleaning equipment and associated fluid systems shale shakers;

Crane, backhoe, front loader, forklift and/or truck(s); and

Frac tanks (i.e., water & drilling mud storage); and

Engine-driven light plants (nighttime operation).

The following denotes the typical equipment at the HDD exit side and most of the listed equipment are

considered noise sources, noting that the noise generated at the HDD exit side is significantly lower

than the noise generated at the entry side:

Backhoe, side boom, backhoe and/or trucks;

Possibly one (1) engine-driven generator set and one (1) “small” engine-driven pump;

Engine-driven light plants (used for nighttime operation).

The following Table B summarizes the estimated sound level (Ldn) of drilling operations at the closest

NSA(s) to each respective HDD site. The Site Specific Noise Mitigation Plans in Section 7.0

summarizes each HDD and depicts where added noise mitigation measures and/or administrative

actions are to be employed by Millennium.


-4-

Meas'd

Ambient Ldn

(dBA) (dBA) (dBA) (dB)

Tab. 1

(p. B-1)

Tab. 2

(p. B-1)

Tab. 3

(p. B-2)

Tab. 4

(p. B-2)

Tab. 5

(p. B-3)

Tab. 6

(p. B-3)

Tab. 7

(p. B-4)

Tab. 8

(p. B-4)

65.9 21.3

Exit 450 ft. W to N 52.5 --- 44.6 53.2 8.6

Entry 150 ft. NE 79.9 65.9 44.6

HDD #3B

HDD #1

78.8 64.7 44.6

50.1 48.5

64.8

63.2

20.2

HDD #3A

Entry/Exit

Entry 170 ft. NE

52.4 3.8500 ft. E to SE

Entry/Exit

2.3

2.747.3

HDD #2

Entry/Exit ---52.2

56.8

1,100 ft. SE

43.9950 ft. NW

Entry/Exit

Entry/Exit

1,000 ft. SW 43.540.1

62.4600 ft. SW

56.0

3.453.2

56.2

40.8

49.3 57.0 0.8

Entry or

Exit

Point

Ref. Table

in Report

Increase

above

Ambient Ldn

HDD No. Distance &

Direction of

Closest NSA

Calc'd Peak

Ldn due to

HDD (w/

added

noise

control

measures)

Calc'd Peak

Ldn due to

HDD (w/o

added

noise

control

measures)

53.7

44.6

Total Ldn of

HDD +

Ambient

Table B: Eastern System Upgrade HDDs - Summary of Est’d Sound Level Contribution (Leq) of the

HDD Sites within ½ mile, including the assessment of Added Noise Mitigation Measures

for HDD Sites in closer proximity to adjacent NSAs

6.0 GENERAL NOISE MITIGATION MEASURES / OPTIONS

The following summarizes some potential noise mitigation measures/options that could be employed

at the HDD entry and/or exit site. Note that employing full temporary enclosures for primary

equipment (e.g., hydraulic power unit) may not be feasible due to equipment cooling requirements and

associated costs.

Employ a temporary noise barrier around the workspace associated with the HDD entry site,

which could be constructed of ½ -in. thick plywood panels (e.g., 14-16-ft. high), or equal sound

barrier system, installed around 2 or 3 sides of the HDD workspace; as an alternative to a

workspace barrier, mud tanks, equipment trailers, etc. could be strategically arranged with an

additional barrier system as required;

Employ hospital–grade exhaust silencers on all engines in conjunction with any of the site HDD

equipment (e.g., generators, pumps & hydraulic power unit);

Partial noise barrier or enclosure around the hydraulic power unit and engine-driven pumps (e.g.,

cover sides and roof of equipment with an acoustically-lined plywood barrier system);

Employ a partial noise barrier around any engine jacket-water (“JW”) coolers;


-5-

Install a partial barrier or partial enclosure around the mud mixing/cleaning system;

Relocation of specific equipment (e.g., remotely relocate mud rig);

Employ “low-noise” generators (i.e., designed with a factory acoustical enclosure);

For an HDD exit site, the most practical noise mitigation method is to employ a temporary noise

barrier at the workspace (i.e., between the site equipment and the closest NSAs), since HDD exit

sites include mostly “mobile” operating equipment;

As a possible alternative to noise mitigation to achieve the sound criterion at NSA(s) that are

relatively close to the HDD sites (e.g., residences 100 to 300 feet of an HDD entry site), prior to

operation of HDD activities, temporary housing or equivalent monetary compensation could be

discussed and/or offered to the nearby land owner(s).

7.0 SITE SPECIFIC NOISE MITIGATION PLANS

The following section summarizes each HDD and discusses “specific” noise mitigation measures for

each respective HDD that Millennium intends to implement, and Millennium intends to implement the

listed mitigation measures that were assumed for the noise model. Note that for all HDD sites, a

residential–grade exhaust silencer shall be employed on all engines associated with the site

equipment (e.g., generators, pumps & hydraulic power unit).

Work Schedule

Millennium intends to employ a 24-hour per day HDD construction schedule for the Project HDDs.

7.1 HDD #1

The HDD #1 pilot hole may be constructed with the intersect method (i.e., drill rigs on both sides until

the pilot hole is established). Upon installation of the pilot hole, the HDD will then be reamed and

pulled back from the HDD #1 Site that is SE of the Neversink River. Therefore, the construction noise

assessment assumes that Entry Site equipment may be utilized on both sides of the HDD crossing.

Entry / Exit Side (SE of Neversink River)

The closest NSA (NSA #1) is a single house that is 1,000 ft. SW of the entry / exit point and there is

foliage and trees between the entry / exit point and NSA #1. The next closest NSAs are residences

approximately 1,400 ft. W to 1,500 ft. SW.

The results of the construction noise assessment indicate that the estimated peak sound levels at

NSA #1 will not exceed the 55 dBA Ldn criterion; however the potential increase of 13.3 dB above

ambient exceeds the 10 dB secondary criterion that is sometimes requested by FERC. Therefore, the

estimated peak HDD sound levels at NSA #1, have been estimated with and without the following

additional mitigation measures, for information purposes:


-6-

Assumed Noise Mitigation Measures

• No additional noise mitigation measures, or:

• 16 ft. high barrier on 2 sides of the entry site equipment (i.e., south-south west and west-

northwest sides).

Estimated Peak Sound Levels

• 24-hour Operation: 53.2 dBA Ldn (without additional mitigation measures)

40.8 dBA Ldn (with additional noise mitigation measures)

• Daytime Only Operation: 46.8 dBA (without additional mitigation measures)

34.4 dBA (with additional noise mitigation measures)

The results of the construction noise assessment indicates that the estimated peak sound levels at

NSA #1 will not exceed the 55 dBA Ldn criterion; however the potential increase of 13.3 dB above

ambient exceeds the 10 dB secondary criterion that is sometimes requested by FERC. The

construction noise assessment indicates that the estimated peak sound levels at NSA #1, with

additional noise mitigation measures, results in a potential 3.4 dB increase above ambient, which does

not exceed the 10 dB secondary criterion that is sometimes requested by FERC.

With respect to 24-hour or daytime only Operations, Millennium will determine with the selected HDD

contractor what hours will be worked at a later date upon receipt of HDD contractor proposals.

Entry / Exit Side (NW of Neversink River)

The closest NSA (NSA #2) are 3 houses that are 600 to 800 ft. SW of the entry / exit point and there is

minimal shielding from foliage between the entry / exit point and NSA #2. Additional residences are

located approximately 1,000 ft. in the SW to NW direction. A soccer field is located approximately 500

ft. NW of the entry / exit point. The estimated peak HDD sound levels at NSA #2, with the following

additional mitigation measures are as follows:


• 16 ft. high barrier on 2 sides of the entry site equipment (i.e., south-south west and west-

northwest sides).


• 24-hour Operation: 49.3 dBA Ldn

• Daytime Only Operation: 42.9 dBA


-7-

The results of the analysis indicates that the estimated Ldn sound level for 24-hour Operation meets

the FERC guideline of 55 dBA Ldn for a 24 hour drilling schedule at the entry / exit site NW of the

Neversink River.

7.2 HDD #2

The HDD #2 pilot hole may be constructed with the intersect method (i.e., drill rigs on both sides until


pulled back from the HDD #2 Site that is SE of I-84. Therefore, the construction noise assessment

assumes that Entry Site equipment may be utilized on both sides of the HDD crossing.

Entry / Exit Side (SE of I-84)

The closest NSA (NSA #1) is a single residence 1,100 ft. SW of the entry / exit point and there is

shielding by terrain between the entry / exit point and NSA #1. The next closest residences are 1,300

to 1,600 ft. SW of the entry / exit point. The estimated peak HDD sound levels at NSA #1, with no






the FERC guideline of 55 dBA Ldn for a 24 hour drilling schedule at the entry /exit site.

Entry / Exit Side (NW of I-84)

The closest NSA (NSA #2) are 4 residences 950 ft. NW of the entry / exit point and there is some

shielding from foliage between the entry / exit point and NSA #2. The next closest NSAs are 2

residences approximately 1,000 ft. E and 2 residences approximately 1,100 ft. W of the entry / exit

point, and these next closest residences are directly adjacent to I-84. The estimated peak HDD sound

levels at NSA #2, with the following additional mitigation measures are as follows:


• 16 ft. high barrier on 1 side of the entry / exit site equipment (i.e., northwest side).





-8-


the FERC guideline of 55 dBA Ldn for a 24 hour drilling schedule at the entry / exit site.

7.3 HDD #3A

The HDD #3A pilot hole may be constructed with the intersect method (i.e., drill rigs on both sides until


pulled back from the HDD #3A Site that is immediately NW of Bedell Drive. Therefore, the

construction noise assessment assumes that Entry Site equipment may be utilized on both sides of

the HDD crossing.

Entry / Exit Side (NW of Mountain Road)

The closest NSA (NSA #1) are two residences 500 ft. E to SE of the entry / exit point and there is

partial shielding by foliage and terrain between the entry / exit point and NSA #1. The next closest

residences are 900 ft. SE and NE of the entry / exit point. The estimated peak HDD sound levels at

NSA #1, with the following additional mitigation measures are as follows:


• 16 ft. high barrier on 2 sides of the entry / exit site equipment (i.e., southeast and east sides).





the FERC guideline of 55 dBA Ldn for a 24 hour drilling schedule at the entry /exit site.

Entry Side (NW of Bedell Drive)

The closest NSA (NSA #3) is a single residence 170 ft. NE of the entry point and there is a clear line

of site between the entry point and NSA #3. The next closest NSAs are 2 residences approximately

425 ft. NE of the entry point. The estimated peak HDD sound levels at NSA #3, with the following



• 16 ft. high barrier on 3 side of the entry site equipment (i.e., northeast, east and southeast

sides).




-9-


The results of the analysis indicates that the estimated Ldn sound level for 24-hour Operation exceeds

the FERC guideline of 55 dBA Ldn for a 24 hour drilling schedule at the entry point.



Additional noise control measures and noise control strategies will continue to be developed for the

HDD #3A entry side.

7.4 HDD #3B

Entry Side (NW of Bedell Drive)

The closest NSA (NSA #3) is a single residence 150 ft. NE of the entry point and there is a clear line

of site between the entry point and NSA #3. The next closest NSAs are 2 residences approximately

375 to 400 ft. NE of the entry point. The estimated peak HDD sound levels at NSA #3, with the

following additional mitigation measures are as follows:


• 16 ft. high barrier on 3 side of the entry site equipment (i.e., northeast, east and southeast

sides).




The results of the analysis indicates that the estimated Ldn sound level for 24-hour Operation exceeds

the FERC guideline of 55 dBA Ldn for a 24 hour drilling schedule at the entry point.



Additional noise control measures and noise control strategies will continue to be developed for the

HDD #3B entry side.

Exit Side (SE of Bedell Drive)

The closest NSA (NSA #2) are four residences 450 ft. W to N of the exit point and there is some

shielding by foliage between the exit point and NSA #2. The next closest residences are 650 to 725 ft.

W to N exit point. The estimated peak HDD sound levels at NSA #2, with no additional mitigation

measures are as follows:


-10-





the FERC guideline of 55 dBA Ldn for a 24 hour drilling schedule at the exit site.


A-1

HDD #1

ENTRY / EXIT

POINT

SHWY

209

NSA#2

600'

NSA#1

1000'

POS.1

POS.2NEVERSINK

RIVER

The Neversink HDD will be anintersect with drill rigs on bothsides until the pilot hole isestablished. The HDD will then bereamed and pulled back from theHDD Site SE of the Neversink River.

APPROXIMATE SCALE IN FEET

0 900450 1800

N

- HOUSE OR MOBILE HOME

LEGEND

- NONRESIDENTIAL BUILDING

- TREES OR HEAVY FOLIAGE

- MEASUREMENT POSITION

- NOISE SENSITIVE AREANSA

HDD #1

ENTRY / EXIT

POINT

NEVERSINK DR

(SR 80)

Figure 1: HDD #1 (Neversink River): Area Layout Showing the location of HDD Crossing, HDD

Entry/Exit Location and nearby NSAs


A-2

- MEASUREMENT POSITION- NOISE SENSITIVE AREANSA

HDD #2

ENTRY / EXIT

POINTI-84

950'

NSA#2

1100'

NSA#1

ORIOLE

WAY

BEDELL

DR

US 6

HDD #2

ENTRY / EXIT

POINT

POS.1

POS.2

I-84

The I-84 HDD may be an intersectwith drill rigs on both sides until thepilot hole is established. The HDDwill then be reamed and pulledback from the HDD Site, SE of theI-84

HDD #3A & 3B

ENTRY / EXIT

POINTS

HDD #3B

EXIT POINT


0 900450 1800

N


LEGEND



Figure 2: HDD #2 (I-84): Area Layout Showing the location of HDD Crossing, HDD Entry/Exit

Location and nearby NSAs


A-3


0 1200600 2400

N


LEGEND



- MEASUREMENT POSITION- NOISE SENSITIVE AREANSA

HDD #3B

EXIT POINT

450'

NSA#2

500'NSA#1

ORIOLE

WAY

BEDELL

DR

MOUNTAIN

RD

POS.1

POS.2

I-84

HDD #3A

ENTRY/EXIT

POINTSCHOOLHOUSE

RD

HDD #3A

& #3B

ENTRY

POINTS

NSA#3

(150' FROM 3B

170' FROM 3A)

The Mountain Road HDD (HDD#3A) will be an intersect with drillrigs on both sides until the pilothole is established. The HDD willthen be reamed and pulled backfrom the HDD Site NW ofMountain Road.

HDD #2

ENTRY/EXIT

POINT

Figure 3: HDD #3A & #3B (Mountain Road & Bedell Drive): Area Layout Showing the location of

HDD Crossing, HDD Entry/Exit Location and nearby NSAs


B-1

Dist. (Ft) or Noise Source and Other Conditions/Factors SPL or PWL in dB Per Octave-Band Center Freq. (Hz) A-Wt.

Calculation associated with Acoustical Analysis 31.5 63 125 250 500 1000 2000 4000 8000 Level

Peak PWL of HDD Operation at an Entry Point 118 115 112 114 112 109 108 106 98 115

Attenuation by Foliage and/or Land Contour -3 -4 -5 -6 -8 -10 -10 -10 -10

1000Hemispherical Radiation -58 -58 -58 -58 -58 -58 -58 -58 -58 Calc'd

1000Atm. Absorption (70% R.H., 60 deg F) 0 0 0 -1 -1 -2 -4 -8 -14 Ldn

Est'd Total Sound Contribution with No Additional NC 57 53 49 50 46 39 36 30 16 46.8 53.2

Ambient Sound Level 40.1

Sound Contribution of HDD plus Ambient Level 53.4

Potential Increase above the Ambient Sound Level (dB) 13.3

Attenuation due to Added Noise Mitigation Measures -4 -6 -8 -10 -14 -16 -16 -16 -16

Est'd Sound Level of HDD + Added Mitigation Measures 53 47 41 40 32 23 20 14 0 34.4 40.8




Table 1: HDD #1: Est'd Contribution of the HDD Operations at Closest NSA (NSA #1; Residence 1,000 ft. SW of Entry / Exit Point)

including Sound Level with Additional Noise Mitigation Measures Employed (i.e., Noise Barrier around HDD Site)




Attenuation by Foliage and/or Land Contour 0 -1 -2 -3 -4 -5 -5 -5 -5

600 Hemispherical Radiation -53 -53 -53 -53 -53 -53 -53 -53 -53 Calc'd

600 Atm. Absorption (70% R.H., 60 deg F) 0 0 0 0 0 -1 -2 -5 -8 Ldn










Table 2: HDD #1: Est'd Contribution of the HDD Operations at Closest NSA (NSA #2; Residences 600 ft. SW of Entry / Exit Point),



B-2




Attenuation by Foliage and/or Land Contour -3 -4 -5 -6 -8 -10 -10 -10 -10


1100Atm. Absorption (70% R.H., 60 deg F) 0 0 0 -1 -1 -2 -4 -9 -15 Ldn





Table 3: HDD #2: Est'd Contribution of the HDD Operations at Closest NSA (NSA #1; Residence 1,100 ft. SW of Entry / Exit Point)

with no Additional Noise Mitigation Measures Employed






950 Atm. Absorption (70% R.H., 60 deg F) 0 0 0 0 -1 -2 -4 -8 -13 Ldn



Sound Contribution of HDD plus Ambient Level (dBA) 57.1







Table 4: HDD #2: Est'd Contribution of the HDD Operations at Closest NSA (NSA #2; Residences 950 ft. NW of Entry / Exit Point),



B-3
















Table 5: HDD #3A: Est'd Contribution of the HDD Operations at Closest NSA (NSA #1; Residences 500 ft. E to SE of

Entry/Exit Point) including Sound Level with Additional Noise Mitigation Measures Employed (i.e., Noise Barrier

around HDD Site)



Peak PWL of HDD Operation at an Exit Point 118 115 112 114 112 109 108 106 98 115

Attenuation by Foliage and/or Land Contour 0 0 0 0 0 0 0 0 0


170Atm. Absorption (70% R.H., 60 deg F) 0 0 0 0 0 0 -1 -1 -2 Ldn










Table 6: HDD #3A: Est'd Contribution of the HDD Operations at Closest NSA (NSA #3; Residences 170 ft. NE of

Entry/Exit Point), including Sound Level with Additional Noise Mitigation Measures Employed (i.e., Noise Barrier

around HDD Site)


B-4




Attenuation by Foliage and/or Land Contour 0 0 0 0 0 0 0 0 0


150Atm. Absorption (70% R.H., 60 deg F) 0 0 0 0 0 0 -1 -1 -2 Ldn










Table 7: HDD #3B: Est'd Contribution of the HDD Operations at Closest NSA (NSA #3; Residences 150 ft. NE of

Entry/Exit Point), including Sound Level with Additional Noise Mitigation Measures Employed (i.e., Noise Barrier

around HDD Site)



Peak PWL of HDD Operation at an Exit Point 110 108 105 102 100 98 95 92 88 103








Table 8: HDD #3B: Est'd Contribution of the HDD Operations at Closest NSA (NSA #2; Residences 450 ft. W to N of Exit Point),

with no Additional Noise Mitigation Measures Employed


B-5

Description of Acoustical Assessment Methodology and Source of Sound Data

In general, the predicted A-wt. sound level contributed by drilling operations at HDD operations at the

nearby NSAs was calculated as a function of frequency from estimated unweighted octave-band (“O.B.”)

sound power levels (“PWLs”) during “peak” operations of HDD stationary equipment at either the HDD

entry site or HDD exit site. The following summarizes the acoustical analysis procedure:

Initially, unweighted O.B. PWLs of the HDD operations were determined from actual sound level

measurements by H&K on similar type of HDD operations and equipment expected for this project.

Estimated PWL values of the HDD operations were calculated from sound measurements at different

distances/directions from HDD operations (e.g., sound measurements at 100 feet, 200 feet, 400 feet

and 800 feet from typical HDD equipment operations).*

Then, expected attenuation in dB per O.B. frequency due to hemispherical sound propagation

(discussed in more detail below**), atmospheric sound absorption (discussed in more detail below***)

and other factors (e.g., attenuation due to foliage and topography**) were subtracted from the

unweighted O.B. PWLs to obtain unweighted O.B. sound pressure levels (SPLs) of HDD operations.

Finally, the resulting estimated total unweighted O.B. SPLs for the HDD operations, including sound

attenuation effects, were logarithmically summed and corrected for A-weighting to provide the

estimated overall A-wt. sound level contributed by the drilling operations at the specified distance(s).

*It should be noted that the estimated sound power levels of HDD operations utilized in the H&K acoustical

analyses were based on measured sound level data at different distances from actual HDD construction

sites, and therefore, the PWL values, for the most part, includes the effect of ground effect (e.g., ground

absorption). Consequently, in our opinion, it would not be appropriate to strictly follow international–based

standards, such as ISO 9613-21, when calculating the estimated A-wt. sound level at a respective

receptor (i.e., NSA) via the PWL values utilized in the H&K acoustical analysis methodology.

**Attenuation due to hemispherical sound propagation: Sound propagates outwards in all directions (i.e.,

length, width, height) from a point source, and the sound energy of a noise source decreases with

increasing distance from the source. In the case of hemispherical sound propagation, the source is

located on a flat continuous plane/surface (e.g., ground), and the sound radiates hemispherically (i.e.,

outward, over and above the surface) from the source. The following equation is the theoretical decrease

of sound energy when determining the resulting O.B. SPLs of a noise source at a specific distance (“r”) of

a receiver from a source O.B. PWL values:

Decrease in SPL (“hemispherical propagation”) from a noise source = 20*log(r) – 2.3 dB

where “r” is distance of the receiver from the noise source.

1International Standard Organization (ISO) 9613-2, Dec. 15, 1996 (Publication Date): Acoustics - Attenuation of Sound During Propagation Outdoors - Part 2: General Method of Calculation


B-6

***Attenuation due to air absorption, foliage and topography: Air absorbs sound energy, and the amount of

absorption (“attenuation”) is dependent on the temperature and relative humidity (R.H.) of air and

frequency of sound. For example, the attenuation due to air absorption for 1000 Hz O.B. SPL is

approximately 1.5 dB per 1,000 feet for standard day conditions. Potential attenuation of foliage, based

on our experience and an ISO Standard2, the “medium-frequency” attenuation (i.e., 1000 Hz) due to

forest/trees greater than 500 feet thick is approximately 10 dB. Also, forested areas with plantings more

than 100 feet deep can provide some attenuation of ground level noise sources. In addition, the

topography (i.e., land contour, such as a hill or ridge) between the HDD site and the nearby NSA(s) can

provide some additional attenuation of the HDD noise contribution at the respective NSA(s).

2ISO Standard 9613-1: 1993 (E); Acoustics – Attenuation of sound during propagation outdoors – Part 1: Calculation of the Absorption of Sound by the Atmosphere, and Part 2: General method of calculation


C-1

Measurement Set Day- Avg'd Night Avg'd Calc'd

time of time of Ldn

Meas. Pos. & NSA Date of Test Leq(Ld) Ld Leq(Ln) Ln Notes/Observations

Pos. 1 (NSA #1) 12/16/16 39.9 31.1

Residence 12/16/16 37.5 38.9 32.3 31.5 40.1

1,000 ft. SW of 12/16/16 38.8 31.1

Entry / Exit Site

Pos. 2 (NSA #2) 12/16/16 55.0 31.2

Residences 12/16/16 57.3 57.4 33.6 32.4 56.2

600 ft. SW of 12/16/16 59.0 31.9

Entry / Exit Site

Table A-1: ESU Project: HDD #1 (Deerpark, NY): Summary of Ambient Day/Night Sound Levels

at the NSAs as Meas'd on Dec. 16, 2015, along with Resulting Ldn

Note (1): Ldn calculated by adding 6.4 dB to the measured Ld. If both the Ld and Ln are measured and/or

estimated, the Ldn is calculated using the following formula:

Measurement Set Temp. R.H. Wind Wind Peak

Meas. Pos. Time Frame/Date of Tests (°F) (%) Direction Speed Wind Sky Conditions

Pos. 1 - 2 54 42 from NW 1 mph 3 mph

Pos. 1 - 2 52 68 from W 1 mph 3 mph

Table B-1: ESU Project: HDD #1 (Deerpark, NY): Summary of the Meteorological

Conditions during the Sound Survey on Dec. 16, 2015

Overcast

Overcast1:15 AM to 1:30 AM

1:50 PM to 2:15 PM

Meas'd/Calc'd A-Wt. Levels (dBA)

Primary Daytime noise: Traffic on Hwy. 209, light wind noise and a distant barking dog.

Primary Nighttime noise: Distant traffic on Hwy. 209 and light wind.

Primary Daytime noise: Traffic Hwy. 209, birds, distant trucks and light wind.

Primary Nighttime noise: Distant traffic on Hwy 209 and light wind.

( )

+= + 10/1010/

10dnnd 10

24910

2415log10 LLL


C-2

Measurement Set A-Wt.

Meas. Pos. & NSA Time of Test 31.5 63 125 250 500 1000 2000 4000 8000 Level

Pos. 1 (NSA #1) 1:53 PM 44.9 46.9 36.9 30.3 36.4 37.1 30.8 25.3 22.8 39.9

Residence 1:57 PM 48.0 44.9 34.8 30.4 33.1 34.9 29.0 22.1 12.2 37.5

1,000 ft. SW of 2:01 PM 46.2 45.2 37.3 28.9 33.9 36.6 30.5 18.2 11.5 38.8

Entry / Exit Site Average SPL 46.6 45.8 36.5 29.9 34.7 36.3 30.2 22.8 18.7 38.9

Pos. 2 (NSA #2) 2:05 PM 61.4 61.4 54.0 48.4 47.5 53.4 46.1 33.5 18.9 55.0

Residences 2:10 PM 54.7 57.0 54.6 52.5 51.2 55.2 49.1 39.3 25.3 57.3

600 ft. SW of 2:11 PM 55.8 60.1 58.7 52.6 53.9 57.0 50.0 38.5 25.4 59.0


Table C-1: ESU Project: HDD #1 (Deerpark, NY): Measured Daytime Ambient Ld and

Unweighted Octave-Band ("O.B.") SPLs at the NSAs as Measured on Dec. 16, 2016



Pos. 1 (NSA #1) 1:16 AM 51.0 46.7 34.1 29.5 27.2 26.8 21.6 15.8 12.3 31.1

Residence 1:17 AM 53.5 47.9 35.1 31.1 28.0 28.0 22.9 16.7 13.3 32.3

1,000 ft. SW of 1:18 AM 44.2 42.7 32.4 30.8 27.4 27.3 21.6 14.7 12.2 31.1


Pos. 2 (NSA #2) 1:23 AM 41.5 41.6 32.5 31.2 27.9 26.8 21.8 17.0 12.5 31.2

Residences 1:24 AM 41.2 41.6 34.5 32.1 28.9 28.8 25.4 24.0 20.1 33.6

600 ft. SW of 1:25 AM 38.3 40.2 33.9 30.2 28.5 28.3 23.0 15.5 12.3 31.9


Table D-1: ESU Project: HDD #1 (Deerpark, NY): Measured Nighttime Ambient Ln and

Octave-Band ("O.B.") SPLs at the NSAs as Measured on Dec. 16, 2016

Sound Pressure Level (SPL) in dB per Octave-Band Freq. (in Hz)



C-3


time of time of Ldn


Pos. 1 (NSA #1) 12/16/16 37.2 45.2

Residence 12/16/16 37.6 38.4 45.5 45.2 53.7

1,100 ft. SE of 12/16/16 39.8 44.7

Entry / Exit Site

Pos. 2 (NSA #2) 12/16/16 42.7 36.7

Residences 12/16/16 43.9 44.6 36.0 36.0 44.6

950 ft. NW of 12/16/16 46.4 35.2

Entry / Exit Site

Table A-2: ESU Project: HDD #2 (Greenville, NY): Summary of Ambient Day/Night Sound

Levels as Meas'd on Dec. 16, 2015, along with Resulting Ldn







Table B-2: ESU Project: HDD #2 (Greenville, NY): Summary of the Meteorological



Primary Daytime noise: Traffic on US 6, birds, distant traffic on I-84, light wind and a distant airplane.

Primary Nighttime noise: Distant traffic on I-84, birds, distant plane and light wind.

Primary Daytime noise: Traffic on I-84, birds, a distant plane and light wind.

Primary Nighttime noise: Distant traffic on I-84 and light wind.

1:00 PM to 1:30 PM

1:45 AM to 2:30 AM

Overcast

Overcast

( )

+= + 10/1010/

10dnnd 10

24910

2415log10 LLL


C-4



Pos. 1 (NSA #1) 1:08 PM 50.1 54.4 42.8 31.9 29.4 34.0 28.5 15.3 12.0 37.2

Residence 1:10 PM 48.1 45.7 40.0 31.2 26.8 36.2 28.2 13.2 11.7 37.6

1,100 ft. SE of 1:11 PM 47.7 47.2 40.4 30.0 29.8 38.1 32.0 18.3 11.9 39.8


Pos. 2 (NSA #2) 1:27 PM 55.8 55.5 47.8 37.5 39.6 39.9 29.9 15.6 14.1 42.7

Residences 1:28 PM 60.8 59.4 48.1 37.0 40.0 41.2 31.7 16.4 17.5 43.9

950 ft. NW of 1:29 PM 62.8 59.6 49.9 41.2 42.8 43.8 33.6 20.8 16.8 46.4


Table C-2: ESU Project: HDD #2 (Greenville, NY): Measured Daytime Ambient Ld and




Pos. 1 (NSA #1) 1:47 AM 57.8 49.6 46.1 41.8 43.1 42.8 27.1 18.8 18.2 45.2

Residence 1:48 AM 53.9 53.7 45.7 41.9 43.2 43.1 28.1 18.7 18.0 45.5

1,100 ft. SE of 1:49 AM 54.8 49.8 45.3 41.5 42.6 42.2 28.2 19.8 18.5 44.7


Pos. 2 (NSA #2) 2:27 AM 48.7 46.8 40.9 32.2 34.6 32.8 25.5 21.1 16.5 36.7

Residences 2:28 AM 48.1 43.9 37.9 30.9 32.4 33.2 25.7 20.5 15.5 36.0

950 ft. NW of 2:29 AM 45.9 44.0 39.2 33.3 32.0 30.8 25.6 22.8 17.5 35.2


Table D-2: ESU Project: HDD #2 (Greenville, NY): Measured Nighttime Ambient Ld and





C-5


time of time of Ldn


Pos. 1 (NSA #1) (04/27/16) 48.1 38.1

Residences (04/27/16) 50.9 49.7 35.1 36.3 48.5

500 ft. E to SE of (04/27/16) 49.8 34.6

HDD #3A Entry/Exit Site

Pos. 2 (NSA #3) (12/16/15) 42.7 36.7

Residence (12/16/15) 43.9 44.6 36.0 36.0 44.6

170 ft. NE / 150 ft. NE of (12/16/15) 46.4 35.2

HDD #3A / #3B Entry Sites

Pos. 2 (NSA #2) (12/16/15) 42.7 36.7

Residences (12/16/15) 43.9 44.6 36.0 36.0 44.6

450 ft. W to N of (12/16/15) 46.4 35.2

HDD #3B Exit Site

Table A-3: ESU Project: HDD #3A & #3B (Greenville, NY): Summary of Ambient Day/Night Sound

Levels as Meas'd on Dec. 16, 2015 and April 27, 2016, along with Resulting Ldn





Pos. 1 59 50 from NW 1 mph 3 mph




Table B-3: ESU Project: HDD #3A & #3B (Greenville, NY): Summary of the Meteorological

Conditions during the Sound Surveys on Dec. 16, 2015 and April 27, 2016

11:30 PM to 11:45 PM Clear Skies

1:15 PM to 1:30 PM Overcast

2:15 AM to 2:30 AM Overcast


Primary Daytime noise: Traffic on I-84, birds, distant local traffic and light wind.




11:45 PM to 12:15 PM Clear Skies



( )

+= + 10/1010/

10dnnd 10

24910

2415log10 LLL


C-6



Pos. 1 (NSA #1) 11:52 AM 55.5 53.1 50.2 47.3 44.9 45.0 36.5 30.8 23.8 48.1

Residences 12:01 PM 55.8 54.7 50.0 47.0 48.7 48.1 38.6 30.0 29.1 50.9

500 ft. E to SE of 12:07 PM 56.0 53.6 49.2 47.1 47.0 47.1 38.0 31.0 22.0 49.8

HDD #3A Entry/Exit Site Average SPL 55.8 53.9 49.8 47.1 47.1 46.9 37.8 30.6 26.1 49.7

Pos. 2 (NSA #3) 1:27 PM 55.8 55.5 47.8 37.5 39.6 39.9 29.9 15.6 14.1 42.7

Residence 1:28 PM 60.8 59.4 48.1 37.0 40.0 41.2 31.7 16.4 17.5 43.9

170 ft. NE / 150 ft. NE of 1:29 PM 62.8 59.6 49.9 41.2 42.8 43.8 33.6 20.8 16.8 46.4

HDD #3A / #3B Entry Sites Average SPL 60.7 58.5 48.7 39.0 41.0 41.9 32.0 18.2 16.4 44.6

Pos. 2 (NSA #2) 1:27 PM 55.8 55.5 47.8 37.5 39.6 39.9 29.9 15.6 14.1 42.7

Residences 1:28 PM 60.8 59.4 48.1 37.0 40.0 41.2 31.7 16.4 17.5 43.9

450 ft. W to N of 1:29 PM 62.8 59.6 49.9 41.2 42.8 43.8 33.6 20.8 16.8 46.4

HDD #3B Exit Site Average SPL 60.7 58.5 48.7 39.0 41.0 41.9 32.0 18.2 16.4 44.6

Table C-3: ESU Project: HDD #3A & #3B (Greenville, NY): Measured Daytime Ambient Ld and


and April 27, 2016



Pos. 1 (NSA #1) 11:34 PM 40.2 41.6 39.3 36.6 34.9 35.3 26.5 20.4 14.2 38.1

Residences 11:37 PM 40.9 41.5 38.0 33.7 33.0 31.5 22.8 19.5 13.2 35.1

500 ft. E to SE of 11:38 PM 42.6 40.9 35.8 32.8 31.3 31.7 23.3 18.4 12.7 34.6

HDD #3A Entry/Exit Site Average SPL 41.4 41.3 37.9 34.7 33.3 33.2 24.5 19.5 13.4 36.3

Pos. 2 (NSA #3) 2:27 AM 48.7 46.8 40.9 32.2 34.6 32.8 25.5 21.1 16.5 36.7

Residence 2:28 AM 48.1 43.9 37.9 30.9 32.4 33.2 25.7 20.5 15.5 36.0

170 ft. NE / 150 ft. NE of 2:29 AM 45.9 44.0 39.2 33.3 32.0 30.8 25.6 22.8 17.5 35.2

HDD #3A / #3B Entry Sites Average SPL 47.7 45.1 39.5 32.2 33.2 32.4 25.6 21.6 16.6 36.0

Pos. 2 (NSA #2) 2:27 AM 48.7 46.8 40.9 32.2 34.6 32.8 25.5 21.1 16.5 36.7

Residences 2:28 AM 48.1 43.9 37.9 30.9 32.4 33.2 25.7 20.5 15.5 36.0

450 ft. W to N of 2:29 AM 45.9 44.0 39.2 33.3 32.0 30.8 25.6 22.8 17.5 35.2

HDD #3B Exit Site Average SPL 47.7 45.1 39.5 32.2 33.2 32.4 25.6 21.6 16.6 36.0

Table D-3: ESU Project: HDD #3A & #3B (Greenville, NY): Measured Nighttime Ambient Ld and


and April 27, 2016




D-1

Local Noise Ordinance Information

Town of Deerpark • Section 230-19 – General Commercial and Industrial

Standards (relevant text from Town of Deerpark Zoning Law) follows. (page 38-39)

Town of Greenville • Article VIII – Special Business Development District

(relevant text from Town of Greenville Zoning Law) follows. (page 21-23)

Town of Deerpark Zoning Law

Town of Deerpark, Orange County, New York Article 4 – General Supplementary Regulations

Page 38

the Institute of Transportation Engineers. However, based on the characteristics of a

specific neighborhood, these amounts may be lowered or raised, at the discretion of

the Planning Board. The factors which shall be used for such a determination

include, but are not limited to, pertinent characteristics of the neighborhood such as

width of properties, width of the streets, hills, curves, and the number of children present.

b. Parking – whether or not parking problems could result from the business use.

Factors which shall be used to evaluate this criteria include, but are not limited to the

following: (i) parking required for the business shall be provided on-site; (ii) parking

on the property shall be on a surface equal in quality to the paving surface of any

existing driveway unless there is no surface other than the ground, in which case a

gravel surface shall be provided at a minimum; and (iii) no home occupation shall be

permitted which requires parking of tractor-trailer combinations along the street on a

continuing basis.

3. Nuisance – whether or not the business activity is causing a nuisance to surrounding property owners or is deviating from the residential character or

appearance of the neighborhood.

B. No home occupation, having once been permitted or established, shall be added to, expanded, e

nlarged or otherwise increased or changed substantially in character without complying with is

law and such permission or establishment shall not be a basis for a later application to establish a

principal commercial use. Moreover, the conversion o f a residence with a home occupation to a

commercial use by the abandonment of the residence or sale, rent or transfer of the business to a

party which does not reside on-site is strictly prohibited unless the business in then moved off-site.

§ 230-19 General Commercial and Industrial Standards

Wherever commercial, manufacturing or other non-residential uses, with the exception of agricultural activities and

home occupations, are proposed the following performance standards will apply. The Building Inspector shall

ensure these standards are met prior to issuing Certificates of Occupancy for such uses and may require the

applicant(s) to provide documentation of compliance.

A. Commercial/Residential Buffers: Where a commercial or manufacturing use is contiguous to an

existing residential use in any RS District (including those situated on the opposite side of a highway) or any approved residential lot in an RR or NR District, the Planning Board may require that the

minimum front, side, and rear yards be increased up to fifty percent (50%). The Board may also

require, for purposes of separating incompatible activities or shielding the residence from negative

impacts, that a buffer consisting of a solid fence of wood and/or twenty (20) feet wide dense evergreen

planting not less than six (6) feet high be maintained, unless the properties are in the same ownership

of the full width of the yard is already wooded (see also § 230-55).

B. Inflammables: All activities involving the manufacturing, production, storage, transfer or disposal of

inflammable and explosive materials shall be provided with adequate safety devices against the hazard

of fire and explosion. Firefighting and fire suppression equipment and devices shall be provided

pursuant to National Fire Protection Association guidelines. Burning of waste materials in open fires

is prohibited. Details of the potential hazards and planned safety and accident response actions shall be provided by the applicant and the Planning Board may require greater front, side, and rear yards

and/or fencing.

C. Electric Disturbances: No activities shall be permitted which emit dangerous radioactivity or electrical

disturbance adversely affecting the operation of any equipment other than that of the creator of such

disturbance.



Page 39

D. Noise: The maximum sound pressure level radiated by any non-transportation use or facility at the

property line shall not exceed the values given in Table 1 below after applying adjustments as provided

in Table 2 below. The sound pressure shall be measured with a sound level meter and associated with

Octave Band Analyzer conforming to standards prescribed by the American National Standards

Institute.

TABLE 1

OCTAVE BAND RANGE MAXIMUM SOUND PRESSURE LEVEL

CYCLES PER SECOND DECIBLES (0.002 DYNE/2CM)

20-300 60

300-2,400 40

2,400+ 30

If the noise is not smooth and continuous and is not radiated between the hours of 10:00 PM and 7:00 AM, the adjustments in Table 2 shall be applied to the decibels levels given in Table 1.

Where more than one adjustment is applicable, the largest adjustment only shall apply.

TABLE 2

TYPE OF LOCATION OR ADJUSTMENT IN

NOISE CHARACTER DECIBELS PERMITTED

1. Daytime operation only +5

2. Noise source operates <20% of any given hour +5

3. Property is located in HM-U District at least 500 feet from any Residential District boundary +10

4. Noise of impulsive character (hammering, etc.) -5

5. Noise of periodic character (hum, screech, etc.) -5

Motor vehicle racetracks shall employ noise control suppression mechanisms as provided in the

Town of Deerpark Local Regulating Motor Vehicle Racetracks (Local Law No. 1 of 1991,

as amended).

E. Vibration: No vibration shall be permitted on a regular or continuing basis which is detectable without

instruments at the property line.

F. Lighting: All lighting shall be designed so as to avoid unnecessary or unsafe spillover of light and

glare onto operators of motor vehicles, pedestrians, and land uses in proximity to the light source.

Light sources shall comply with the following standards:

TYPE OF MAXIMUM ILLUMINATION MAXIMUM PERMITTED

LIGHT SOURCE PERMITTED AT PROPERTY LINE HEIGHT OF LIGHT

Globe Light 0.20 Foot-candles 15 feet

>90% Cutoff 0.75 Foot-candles 25 feet <90% Cutoff 2.00 Foot-candles 30 feet

No direct or sky-reflected glare, whether from floodlights or from high-temperature processes

such as combustion or welding or other sources, so as to be visible at the property line on a regulat

or continuing basis, shall be permitted.

ARTICLE VIII

SPECLAL BUSINESS DEVELOPMENT DISTRICTFLOATING ZONE

A Purooses and Objectives

The purpose of this Special Business Development District BDD article is to

Encourage flexibility to promote the most appropriate use ofland and to result in smaller more efficient

networks ofutilities and streets

2 Provide sufficient space in appropriate locations to meet the Towns needs for manufacturingcommercial and related activities with due allowance for the need for a choice of sites

3 Protect residences by separating them from business activities and to prohibit the use of such space for

new residential development

4 Encourage development which is free from danger of fire explosions toxic and noxious matter

radiation and other hazards and from offensive noise vibration smoke dust and other particulatematter odorous matter heat humidity glaze and other objectionable influences

5 Encourage developments which preserve the Towns rural chazacter outstanding natural topography and

geologic features scenic vistas trees and prevent the disruption ofnatural drainage patterns

6 Encourage compatibility with the Comprehensive Plan

B General Requirements

Minimum Area

The minimum azea for aBDD is ten 10 configuous acres

2 Ownership

The project land maybe owned leased or controlled either by asingle person or corporation or by a

group of individuals or corporations Such ownership may be apublic or private corporation The approvedproject plan shall be binding on the project land and owners Only the owner or an agent designated in writingshall be allowed to file an application for a BDD

Permitted Uses

The following land uses are permitted in BDDs

1 Shopping Centers

2 Offices

3 Research laboratories4 Newspaper offices printing shops5 Wholesale businesses services

6 Equipment rental or sales yards7 Public utilities

8 Light industry9 Storage facilities

10 Accessory uses

21

4 Location

Business Development Districts are allowed to be located only in areas currently zoned as Rural

ResidentiaUOpen Space General Commercial and Highway Commercial Districts as long as such proposeddistricts have direct access onto aNew York State highway by means ofapaved two lane road that meets alltown requirements

5 Road Adequacy and Traffic Hazards Prevention

Proposed BDDs must be located adjacent to a public road that is adequate to handle the expected traffic

generated by the district The proposed use and layout shall be of such a nature that it makes vehicular or

pedestrian traffic no more hazardous than is normal for the area involved Factors to consider in this

determination are the turning movements in relafion to traffic flow proximity to and relationship to

intersections adequacy of sight distances location and access ofoffstreet parking provisions for pedestriantraffic and minimization ofpedestrianvehicular contacts

6 Adjacent Lands

The proposed location and height of buildings or structures walls and fences parking loading and

landscaping shall be such that they do not interfere with or discourage the allowed development in the use of

land adjacent to the proposed site or unreasonably affects its value

7 Signs

Proposed signs shall be in accordance with the requirements ofArticle IX B and shall be so designed and

located as not to present ahazard glare or unattractive appearance to either adjacent property orto motorists

8 Landscaping

Adequate landscaping and lighting shall be provided

9 Sewer and Water Facilities

Every BDD must be served by public or private communal sewer and water systems that have been

approved by the NYS Department of Health and the NYS Department of Environmental Conservation and have

been properly shown to meet every requirement of the Town of Greenville and the County of Greene Sewagetreatment must be provided by a governmental agency a municipality or a sewage disposal corporation formed

and regulated pursuant to Article 10 of the NYS Transportation Corporation Law

10 Height

No structure in aBDD shall exceedthirtyfive35 feet in height

22

11 Performance Standards

Uses are not permitted which exceed New York State regulations or any ofthe following standards

measured at the individual property line

a Emit noise in excess of70 decibels

b Emit any odor which is considered offensive

c Emit dust or dirt which is considered offensive

d Emit any smoke in excess of Ringlemann Chart No 2

e Emit any noxious gases which endanger the health comfort safety or welfare of any person or

which have a tendency to cause injury or damage to property business or vegetationf Cause as aresult of normal operations a vibration which creates displacement of0003 of one inch

g Lighting or signs which create glare which could impair the

vision of adriver of any motor vehicle

h Cause afire explosion or safety hazard

i Cause harmful wastes to be discharged into the sewer system streams or other bodies of water

C Sketch Plan Application and Review

Whenever any Business Development District is proposed before any contract is made for the sale of any

part therof before any zoning and building permit shall be granted and before any subdivisionplat may be filed

in the office ofthe Greene County Clerk the prospective developer or his authorized agent shall apply for and

secure approval of such Business Development District in accordance with the following procedures

Application for Sketch Plan Approval

a In order to allow the Planning Board and the developer to reach an understanding on basic designrequirements prior to detailed design investment the developer shall submit a sketch plan ofhis proposal to the

Planning Board The sketch plan shall be approximately to scale and it shall clearly show the followinginformation

1 Location and size in acres ofproposed land uses location proposed use and height of all

structures

2 The general outlines ofthe interior roadway system and all existing rightsofway and

easements whether public or private

3 The overall drainage system

4 Principal relationships to the community at large with respect to highways water supply and

sewerage disposal

5 A location map showing uses and ownership ofabutting lands

6 Existing natural features such as watercourses water bodies wetlands wooded areas individual

lazge trees and flood hazard areas Features to be retained in the development should be

indicated

23


E-1

Summary of Typical Metrics and Acoustical Terminology

(1) Daytime Sound Level (Ld) & Nighttime Sound Level (Ln): Ld is the equivalent A-weighted sound

level, in decibels, for a 15 hour time period, between 07:00 to 22:00 Hours (7:00 a.m. to 10:00

p.m.). Ln is the equivalent A-weighted sound level, in decibels, for a 9 hour time period, between

22:00 to 07:00 Hours (10:00 p.m. to 7:00 a.m.).

(2) Equivalent Sound Level (Leq): The equivalent sound level (Leq) can be considered an average

sound level measured during a period of time, including any fluctuating sound levels during that

period. In this report, the Leq is equal to the level of a steady (in time) A-weighted sound level that

would be equivalent to the sampled A-weighted sound level on an energy basis for a specified

measurement interval. The concept of the measuring Leq has been used broadly to relate

individual and community reaction to aircraft and other environmental noises.

(3) Day-Night Average Sound Level (Ldn): The Ldn is an energy average of the measured daytime Leq

(Ld) and the measured nighttime Leq (Ln) plus 10 dB. The 10-dB adjustment to the Ln is intended

to compensate for nighttime sensitivity. As such, the Ldn is not a true measure of the sound level

but represents a skewed average that correlates generally with past sound surveys which

attempted to relate environmental sound levels with physiological reaction and physiological

effects. For a steady sound source that operates continuously over a 24-hour period and controls

the environmental sound level, an Ldn is approximately 6.4 dB above the measured Leq.

Consequently, an Ldn of 55 dBA corresponds to a Leq of 48.6 dBA. If both the Ld and Ln are

measured, then the Ldn is calculated using the following formula:

( )

+= + 10/1010/

10dnnd 10

24910

2415log10 LLL

(4) Sound Power Level (Lw or PWL): Ten times the common logarithm of the ratio of the total

acoustic power radiated by a sound source to a reference power. A reference power of a picowatt

or 10-12 watt is conventionally used.

Resource Report 9 – Air and Noise Quality 9F-i Eastern System Upgrade

APPENDIX 9F

Highland Compressor Station Ambient Sound Survey

and Noise Impact Analysis (Eastern System Upgrade)

HIGHLAND COMPRESSOR STATION

AMBIENT SOUND SURVEY and

NOISE IMPACT ANALYSIS

(associated with the Eastern System Upgrade)

H&K Report No. 3354

H&K Job No. 4982


Prepared for: Millennium Pipeline Company, L.L.C. 109 North Post Oak Lane, Suite 120

Houston, TX 77024

Submitted by: Brian R. Hellebuyck, P.E.

Hoover & Keith Inc. 11391 Meadowglen, Suite I Houston, TX 77082

Hoover & Keith Inc. Consultants in Acoustics and Noise Control Engineering 11391 Meadowglen, Suite I, Houston, TX 77082 Phone: (281) 496-9876

Millennium Pipeline Company, L.L.C. Hoover & Keith, Inc. Highland CS – Eastern System Upgrade H&K Job No. 4982

Ambient Sound Survey and Noise Impact Analysis H&K Report No. 3354 (07/27/16)

-i-

REPORT SUMMARY

In this report, Hoover and Keith, Inc. (H&K) present the results of a December 16, 2015

ambient sound survey and subsequent noise impact analysis associated with the proposed

Highland Compressor Station (“Station”), a new compressor station to be owned by

Millennium Pipeline Company, L.L.C. (Millennium). The purpose of the ambient sound

survey and acoustical analysis is to:

• Document the existing acoustic environment around the proposed site and locate the

noise-sensitive areas (NSAs) surrounding the proposed Station.

• Project the sound level contribution that would result from operating the proposed

Station installation.

• Determine noise control measures and noise specifications for the Station equipment to

insure that the facility meets applicable sound level criteria.

The following table summarizes the measured ambient sound levels and noise quality analysis

for the proposed Highland Compressor Station at the closest NSAs:

NSAs Distance

Center of

Proposed

Comp. Unit

Meas'd Ln Meas'd Ld Calc'd

Ambient

Ldn (1)

Est'd Leq

of Station

at Full

Load

Est'd Ldn

of Station

at Full

Load

Station

Ldn +

Ambient

Ldn

Potential

Increase

Above

Ambient

(dBA) (dBA) (dBA) (dBA) (dBA) (dBA) (dB)

NSA #1 (Houses) 3,300 ft. NW 33.5 38.1 41.0 29.0 35.4 42.0 1.0

NSA #2 (Houses) 3,000 ft. W 33.5 38.1 41.0 29.8 36.2 42.2 1.2

NSA #3 (House) 2,900 ft. SW 33.5 38.1 41.0 30.1 36.5 42.3 1.3

NSA #4 (House) 3,750 ft. N-NW 33.5 38.1 41.0 27.9 34.3 41.8 0.8

(1) Via Measured Ld and Ln. Noise Quality Analysis for the Proposed Highland Station at the Closest NSAs

The results of our measurements, observations and analysis indicate that the estimated full

load station sound level contribution at the nearby NSAs should be significantly less than an Ldn

of 55 dBA. Therefore, assuming the recommended noise control measures are followed and

successfully implemented, it is our opinion that the sound level attributable to the proposed

Station should not exceed the FERC criterion of 55 dBA Ldn at the nearby NSAs and there

should be no perceptible increase in vibration.

The potential increase above the ambient noise level is approximately 1 dB. Regarding the

human perception for change in sound level (i.e., potential increase above ambient), a 0-3 dB

change in sound level is representative of a minimum impact, a 5-6 dB change is a noticeable

impact, and a 10 dB change is perceived as a doubling of sound level or a significant impact.



-ii-

TABLE OF CONTENTS

Page

REPORT SUMMARY. ....................................................................................................i

1.0 INTRODUCTION .......................................................................................................... 1

2.0 SOUND CRITERIA. ...................................................................................................... 1

3.0 DESCRIPTION OF SITE AND PROPOSED COMPRESSOR STATION ...................... 2

3.1 Description of the Site. ...................................................................................... 2

3.2 Description of the Station Equipment ................................................................ 2

4.0 MEASUREMENT METHODOLOGY. ........................................................................... 2

4.1 Sound Measurement Locations ........................................................................ 2

4.2 Data Acquisition and Sound Measurement Equipment. .................................... 3

5.0 MEASUREMENT RESULTS ........................................................................................ 3

5.1 Measured Sound Level Data ............................................................................. 3

5.2 Observations during the Site Sound Tests ........................................................ 4

6.0 NOISE IMPACT EVALUATION. ................................................................................... 4

6.1 Significant Sound Sources. ............................................................................... 4

6.2 Estimated Sound Contribution. ......................................................................... 4

6.3 Noise Quality Analysis. ..................................................................................... 4

6.4 Estimated Sound Levels for Normal Unit Blowdowns. ....................................... 6

6.5 Construction Noise Impact. ............................................................................... 6

7.0 NOISE CONTROL REQUIREMENTS. ......................................................................... 7

7.1 Compressor Building. ........................................................................................ 7

7.2 Auxiliary Building. .............................................................................................. 9

7.3 Turbine Exhaust System. ................................................................................ 10

7.4 Turbine Air Intake System. .............................................................................. 10

7.5 Turbine Lube Oil Cooler. ................................................................................. 11

7.6 Station Gas Aftercooler. .................................................................................. 11

7.7 Aboveground Gas Piping. ............................................................................... 11

7.8 Unit and Station Control Valves. ..................................................................... 12

7.9 Miscellaneous Equipment. .............................................................................. 12

-continued on next page-



-iii-

TABLE OF CONTENTS (cont’d.)

FIGURES AND TABLES

Figure 1: Proposed Highland Compressor Station and Surrounding Area. ................... A-1

Figure 2: Proposed Highland Compressor Station and Immediate Area. ...................... A-2

Figure 3: Proposed Highland Compressor Station Plot Plan. ........................................ A-3

Table A: Measured and Averaged Daytime and Nighttime Leq and Calculated Ldn. ....... B-1

Table B: Meteorological Conditions during the Daytime Sound Testing ....................... B-1

Table C: Measured and Averaged Octave-Band Daytime SPLs during Testing ........... B-2

Table D: Measured and Averaged Octave-Band Nighttime SPLs during Testing ......... B-3

Table E: Proposed Highland Station: Est'd Sound Contribution at NSA #1. ................. C-1

Table F: Proposed Highland Station: Est'd Sound Contribution at NSA #2. ................. C-2

Table G: Proposed Highland Station: Est'd Sound Contribution at NSA #3. ................. C-3

Table H: Proposed Highland Station: Est'd Sound Contribution at NSA #4. ................. C-4

Table I: Proposed Highland Station: Est'd Construction Noise at Closest NSA. .......... D-1

APPENDIX E: Acoustical Terminology Discussed in This Report.......................................... E-1



-1-

1.0 INTRODUCTION

In this report, Hoover and Keith, Inc. (H&K) present the results of a December 16

ambient sound survey and subsequent noise impact analysis associated with the

proposed Highland Compressor Station (“Station”), a new compressor station to be

owned by Millennium Pipeline Company, L.L.C. (Millennium). The purpose of the

ambient sound survey and acoustical analysis is to:

• Document the existing acoustic environment around the proposed site and locate

the noise-sensitive areas (NSAs) surrounding the proposed Station.

• Project the sound level contribution that would result from operating the

proposed Station installation.

• Determine noise control measures and noise specifications for the Station

equipment to insure that the facility meets applicable sound level criteria.

2.0 SOUND CRITERIA

Typically, certificate conditions set forth by the Federal Energy Regulatory Commission

(FERC) require that the sound level attributable to a new compressor station not exceed

an equivalent day-night sound level (Ldn) of 55 dBA at any nearby NSA, such as

residences, hospitals or schools. The Ldn is an energy average of the daytime Leq (i.e.,

Ld) and nighttime Leq (i.e., Ln) plus 10 dB. For an essentially steady sound source (e.g.,

gas compressor station) that operates continuously over a 24-hour period and controls

the environmental sound level, the Ldn is approximately 6.4 dB above the measured Leq.

Consequently, an Ldn of 55 dBA corresponds to a Leq of 48.6 dBA.

There are no State of New York1 noise regulations for the Station. We are unaware of

any Sullivan County or Town of Highland noise regulations.

For reference, a summary of acoustical terminology and typical metrics used to measure

and regulate environmental noise is provided at the end of this report in Appendix E

(pp. E-1 to E-3).

1 The NYSDEC has a Policy Document (i.e., Program Policy DEP-00-1; Revised Feb. 2, 2001, “Assessing and Mitigating Noise Impacts”) to provide guidance and clarify program issues for NYSDEC staff to ensure compliance with statutory and regulatory requirements for facility operations regulated under New York State Environmental Quality Reviews or “SEQR”.



-2-

3.0 DESCRIPTION OF SITE AND PROPOSED COMPRESSOR STATION

3.1 Description of the Site

Figure 1 (p. A-1) depicts the proposed Station and surrounding area. Figure 2 (p. A-2)

depicts the Station and immediate surrounding area. The Station is located in the Town

of Highland in Sullivan County, New York and the Station is approximately 5 miles N of

Eldred, NY. The surrounding area consists of heavily forested lands, streams and

scattered small lakes, and sparsely scattered residences along SR 55 upon moderately

to steeply sloped terrain. The Station is remotely located from SR 55 near the top of a

hill and it is heavily screened with forested lands.

The closest NSAs are residences along SR 55 that are 2,900 ft. SW to 3,750 ft. N-NW

of the proposed Station. The former Eldred Preserve Resort (now closed) is

approximately 1 mile S of the proposed Station.

3.2 Description of the Station Equipment

Figure 3 (p. A-3) depicts the proposed Station Plot Plan. The noise impact analysis

assumes that the Station will include one (1) Solar Titan 130 Turbine Compressor Unit

that is ISO rated at 22,400 HP. The following describes auxiliary equipment and other

notable items associated with the new station:

• Acoustically designed compressor building.

• High performance turbine exhaust system.

• High performance turbine air inlet system.

• Low noise turbine lube oil cooler.

• Low noise Station gas aftercooler.

• Aboveground gas piping.

• Control / MCC building, station air compressors and standby generator.

4.0 MEASUREMENT METHODOLOGY

4.1 Sound Measurement Locations

One (1) location was chosen to measure the sound levels near the closest NSAs located

around the proposed Station and the measurement location is depicted on Figure 2 (p.

A-2). The following is a description of the NSAs and the selected sound measurement

positions:



-3-

Pos. 1: Adjacent to NSA #1: Three (3) houses located on Kieferle Rd. The closest

house is approximately 3,300 ft. NW of the proposed compressor unit.

Pos. 1: Adjacent to NSA #2: Two (2) houses located on Kieferle Rd. The closest house

is approximately 3,000 ft. W of the proposed compressor unit.

Pos. 1: Adjacent to NSA #3: One (1) house located on SR 55 approximately 2,900 ft.

SW of the proposed compressor unit.

Pos. 1: Adjacent to NSA #4: One (1) house located SR 55 approximately 3,750 ft. N-NW

of the proposed compressor unit.

4.2 Data Acquisition and Sound Measurement Equipment

Ambient sound measurements were performed by Larry Lengyel of H&K during the

nighttime and morning periods on December 16, 2015. At the reported sound

measurement locations, the A-wt. equivalent sound levels (Leq) and unweighted octave-

band sound pressure levels (SPLs) were performed at approximately 5 ft. above ground.

Typically, 3 representative samples of the ambient noise were performed at each sound

measurement position.

The acoustical measurement system consisted of a Rion Model NA-27 Sound Level

Meter (a Type 1 SLM per ANSI S1.4 & S1.11) equipped with a 1/2-inch microphone with

a windscreen, and SLM was calibrated within 1 year of the sound test date.

5.0 MEASUREMENT RESULTS

5.1 Measured Sound Level Data

Table A (p. B-1) shows the measured daytime Leq (i.e., Ld) and the measured nighttime

Leq (i.e., Ln) along with the logarithmic average of the measured Ld and Ln since more

than one (1) sample of the sound level was measured. In addition, Table A includes an

estimated day-night average sound level (i.e., Ldn), as calculated from the measured Ld

and Ln and observations during the measurements.

Meteorological conditions during the tests are summarized in Table B (p. B-1).

The measured daytime and nighttime unweighted octave-band SPLs at the reported

sound measurement positions and the average of the octave-band SPLs are provided in

Table C (p. B-2) and Table D (p. B-2), respectively.



-4-

The following Table 1 summarizes the measured nighttime ambient Ln and measured

daytime ambient Ld and at the NSAs along with the calculated Ldn (as calculated from

the measured Ld and Ln).

NSAs Meas'd Ln Meas'd Ld Calc'd Ambient

Ldn (1)

(dBA) (dBA) (dBA)

Pos. 1, Houses (NSA #1) 3,300 ft. NW 33.5 38.1 41.0

Pos. 1, Houses (NSA #2) 3,000 ft. W 33.5 38.1 41.0

Pos. 1, House (NSA #3) 2,900 ft. SW 33.5 38.1 41.0

Pos. 1, House (NSA #4) 3,750 ft. N-NW 33.5 38.1 41.0

Distance to Center

of Proposed Comp.

Unit

(1) Via Measured Ld and Ln. Table 1: Measured Sound Levels and the Calculated Ldn at the Closest NSAs

The goal of the ambient sound survey is to document the lower range of ambient sound

levels for the meteorological conditions that existed during the sound survey. During the

sound survey, the wind speeds were low (0-3 mph), which resulted in generally still

conditions. The sound measurements were performed at or near the shoulder of public

roads and the measurements were paused to obtain periods of minimum audible traffic

noise, no passby traffic, periods with no direct aircraft flyovers, and other short term

sounds to exclude “extraneous sound” from the sound survey. Our observations during

the sound survey indicate that the area surrounding the proposed Station is a generally

quiet rural area that would be controlled by normal environmental sounds (i.e., birds,

insects, wind noise, distant traffic, passby traffic, aircraft, etc.).

In conclusion, the measured sound level data adequately quantifies the existing ambient

sound levels around the site for the meteorological conditions that occurred during the

sound survey. Throughout a typical year, there may be periods with lower ambient

sound levels than reported in this report, but is our opinion that the long term ambient

sound levels would be greater than the reported sound levels factoring in the total noise

produced by all sources associated with a given environment.

5.2 Observations during the Site Sound Tests

At NSA #1 to #4: Primary Daytime noise: Audible sounds included traffic noise on SR

55, birds, a distant airplane and light wind noise. Primary Nighttime noise: Audible

sounds included a distant barking dog and light wind noise.



-5-

6.0 NOISE IMPACT EVALUATION

6.1 Significant Sound Sources

The noise impact evaluation considers the noise produced by all significant sound

sources associated with the proposed Station that could impact the sound contribution

at the nearby NSAs. A description of the analysis methodology and source of sound

data is provided in Appendix C (p. C-5). The following sound sources are considered

significant:

• Turbine-compressor casing noise that penetrates the compressor building.

• Noise of the turbine unit exhaust system.

• Noise of the turbine air intake system.

• Noise of the electric motor driven lube oil cooler.

• Noise of the electric motor Station gas aftercooler.

• Noise radiated by above ground compressor station piping.

6.2 Estimated Sound Contribution

Tables E - H (pp. C-1 to C-4) show the calculation (i.e., spreadsheet analysis) of the

estimated octave-band SPLs and the A-wt. sound level, at NSAs #1 - #4 contributed by

the significant noise sources associated with the proposed facilities for standard day

propagating conditions (i.e., no wind, 60 deg. F., 70% R.H.) and any shielding from

buildings, terrain or foliage has been conservatively ignored. This spreadsheet analysis

includes the potential noise reduction due to the anticipated and/or recommended noise

control measures for equipment.

6.3 Noise Quality Analysis

Table 2 (p. 6) summarizes the Noise Quality Analysis for the closest NSAs for the

proposed Station:



-6-

NSAs Distance

Center of

Proposed

Comp. Unit

Meas'd Ln Meas'd Ld Calc'd

Ambient

Ldn (1)

Est'd Leq

of Station

at Full

Load

Est'd Ldn

of Station

at Full

Load

Station

Ldn +

Ambient

Ldn

Potential

Increase

Above

Ambient


NSA #1 (Houses) 3,300 ft. NW 33.5 38.1 41.0 29.0 35.4 42.0 1.0

NSA #2 (Houses) 3,000 ft. W 33.5 38.1 41.0 29.8 36.2 42.2 1.2

NSA #3 (House) 2,900 ft. SW 33.5 38.1 41.0 30.1 36.5 42.3 1.3

NSA #4 (House) 3,750 ft. N-NW 33.5 38.1 41.0 27.9 34.3 41.8 0.8

(1) Via Measured Ld and Ln.

Table 2: Proposed Highland Compressor Station - Noise Quality Analysis

As noted above in Table 2, the sound contribution of the proposed Station is estimated

to be significantly less than the 55 dBA Ldn FERC Criteria at the nearby NSAs.

6.4 Estimated Sound Levels for Normal Unit Blowdowns

The sound levels associated with high pressure gas venting are a function of initial

blowdown pressure, the diameter and type of blowdown valve, and the diameter and

arrangement of the downstream vent piping. As expected, blowdown sound levels are

loudest at the beginning of the blowdown event and they decrease as the blowdown

pressure decreases.

The following Table 3 summarizes the expected sound levels for normal blowdown

events (i.e., unit start up and shut down) at the closest NSA:

"Normal" Blowdown

Sound SourceClosest NSA

Distance / Direction to

Blowdown Silencer

Est'd Initial Sound

Level for Blowdown

(dBA)

Unit Blowdown House (NSA #3) 2,900 ft. SW 35

Table 3: Estimated Initial Sound Levels for "Normal" Blowdown Event

6.5 Construction Noise Impact

Table I (p. D-1) shows the calculation (i.e., spreadsheet analysis) of the estimated

construction noise during Station construction activities. The acoustical analysis of the

construction related activities considers the noise produced by any significant sound

sources associated with the primary construction equipment that could impact the sound



-7-

contribution at the nearby NSAs. The predicted sound contribution of construction

activities was performed only for the closest NSA (i.e., NSA #3).

Construction of the Station will consist of earth work (e.g., site grading, clearing &

grubbing) and construction of the site foundations and equipment, and it is assumed

that the highest level of construction noise would occur during site earth work (i.e., time

frame when the largest amount of construction equipment would operate). The analysis

indicates that the maximum A-wt. noise level of construction activities at the closest NSA

would be equal to or less than 41 dBA (i.e., Ldn of approximately 41 dBA, since

construction would only occur during daytime hours.

7.0 NOISE CONTROL REQUIREMENTS

The following section provides recommended noise control measures and equipment

noise specifications along with other assumptions that may affect the noise generated

by the facility.

7.1 Compressor Building Special Note It is extremely important that the recommended compressor building noise control

requirements, including the ventilation system requirements, are followed in detail, due

to the stringent acoustical requirements for the project. Alternate and lighter weight

compressor building designs are not endorsed by H&K if proposed by any Compressor

Building vendor.

Building Structure

As a minimum, walls/roof should be constructed with exterior steel of 18 gauge and

interior layer of 8-inch thick unfaced mineral wool (e.g., 6.0-8.0 pcf uniform density)

covered with a 24 gauge perforated liner. Thermal insulation, such as "R-19",

should not be used as a substitute for the 6.0-8.0 pcf material.

Personnel entry doors should have a minimum STC-38 sound rating and could

include door glazing if a 2' x 2' maximum view port is employed (e.g., 1/2 inch thick

laminated glazing or double pane safety glass). Doors should seal well with the

doorframe and be self-closing.

No windows, skylights or "open" louvers should be installed.



-8-

All voids and openings in the building walls resulting from penetrations should be

patched and well sealed. Building construction details shall be consistent with a high

performance acoustical compressor building.

A double roll up door system shall be utilized for the equipment access opening.

Each overhead sectional roll-up door, as a minimum, should be a 20 gauge

insulated type design (e.g., 20 gauge exterior with a 22 gauge backskin with

insulation core) and should be completely weather-stripped.

Building Ventilation

The building ventilation system should be designed to properly ventilate (and cool)

the building and equipment during maximum outside ambient temperatures with all

personnel and equipment doors closed. Personnel and/or equipment doors will only

be opened during maintenance activities.

The A-wt. sound level for each ventilation inlet should not exceed 45 dBA at 50 feet

from the building penetration (i.e., inlet louver, acoustic inlet hood, etc.). The A-wt.

sound level for each ventilation exhaust outlet should not exceed 45 dBA at 50 feet

from the building penetration (i.e., exhaust louver, exhaust hood, etc.), noting that

this sound source is at or near the compressor building roof. A ridge vent shall not

be utilized. Each ventilation inlet and exhaust outlet shall assume that the following

sound pressure levels exist inside the compressor building at and adjacent to the

ventilation equipment:

SPLs per Octave-Band Center Freq. & A-Wt. Level

31.5 63 125 250 500 1000 2000 4000 8000 dBA

85 90 90 95 95 95 95 95 90 101

As a minimum, air-supply fans used for ventilation should include a metal boot

enclosing the fan; a minimum 36-inch length exterior silencer and a weather hood

lined with acoustical insulation. Assuming separate roof exhaust vents will be

utilized, each roof exhaust vent, as a minimum, should include a 36-inch length

silencer (i.e., baffle-type design) mounted between the building surface and

vent/hood (i.e., in the ventilator throat).



-9-

7.2 Auxiliary Building

Building Structure (for Equipment Areas)





Personnel entry doors should be insulated steel doors with 1/4 inch thick laminated

glass. Doors should seal well with the doorframe and be self-closing.

No windows or "open" louvers should be installed.


patched and well sealed.

Overhead roll-up doors, as a minimum, should be a 22 gauge insulated type design

(e.g., 20 gauge exterior with a 24 gauge backskin with insulation core) and should

be completely weather stripped.

Building Ventilation (for Equipment Areas)



personnel and equipment doors closed. Personnel and/or equipment doors should

only be opened during maintenance activities.




from the building penetration (i.e., exhaust louver, exhaust hood, etc.). Each

ventilation inlet and exhaust outlet shall assume that the following sound pressure

levels exist inside the compressor building at and adjacent to the ventilation

equipment:


31.5 63 125 250 500 1000 2000 4000 8000 dBA

85 85 85 85 90 90 90 85 75 95



-10-

The ventilation system inlet and exhaust systems shall be designed to control interior

building sound that escapes from the inlet and exhaust flow paths, interior building

sound paths across ventilation system components (i.e., ducting break-in noise,

etc.,) and sound that is generated by ventilation equipment (i.e., supply fans,

exhaust fans, louvers, tempering coils, etc.).



lined with acoustical insulation.

Assuming separate roof exhaust vents will be utilized, each roof exhaust vent, as a

minimum, should include a 36-inch length silencer (i.e., baffle-type design) mounted

between the building surface and vent/hood (i.e., in the ventilator throat).

7.3 Turbine Exhaust System

The silenced exhaust system sound level, at 400 ft. and in any direction from the

exhaust stack centerline, shall not exceed the following octave-band sound pressure

levels:

Maximum (i.e., Guaranteed) Sound Pressure Level (SPL)

at 400 ft. from the Exhaust System

31.5 63 125 250 500 1000 2000 4000 8000

63 54 43 37 32 30 30 30 30

The exhaust system acoustical requirement shall include:

• Exhaust stack outlet noise and all exhaust system breakout noise (i.e., for

exterior exhaust system components, including all exterior duct sections,

expansion joints and any oxidation catalyst system).

• Part load to full load turbine unit operation

7.4 Turbine Air Inlet System

The intake system should include two silencers in series (i.e., two stage silencing

system) between the air intake filter and turbine unit. It is recommended that the first

silencer is located inside the building, while the second stage silencer can be located

outside the building, if required. It is also required that the first stage silencer (and

support system) is acoustically isolated from the second stage silencer (and support

structure) with an acoustical vibration break (i.e., 3” flexible fabric joint). The acoustical

break must be located inside the compressor building. The Solar supplied support



-11-

structure for the 1st stage and 2nd stage silencers should be separated (i.e., not span

across the flexible joint).

The first stage silencer should be a 60” "tubular" silencer. The second stage silencer

should be a parallel baffle construction, with an approximately length of 144”. The

combined insertion loss of the 1st and 2nd stage silencers should approximately meet the

following values:

IL Values in dB per Octave-Band Center Freq. for 1st and 2nd Stage Silencers

31.5 63 125 250 500 1000 2000 4000 8000

5 14 27 42 48 58 65 70 55

It is assumed that a pulse style, up-draft, air inlet filter that will be utilized.

7.5 Turbine Unit Lube Oil Cooler

The Solar low noise lube oil cooler (i.e., maximum 83 dBA PWL) with a Moore Class

10000 MAG fan and V-Belt drive is required for this Station.

7.6 Station Gas Aftercooler

It is assumed that each unitized gas cooler will consist of (4) bays with (3) fans per bay.

The A-wt. sound level of each bay should not exceed 53 dBA at a distance of 50 feet

from the unit perimeter at the rated operating conditions (i.e., (3) fans and motors in

operation). Nonetheless, the coolers shall be equipped with V-Belt drive and Moore

Class 10000 MAG style fans (Max. PWL per Fan = 85 dBA) are required, and the

maximum fan tip speed shall not exceed 7,000 fpm.

7.7 Aboveground Gas Piping

The Station high pressure gas piping including the Unit suction, discharge and bypass

valves, and the Station suction and discharge headers should be buried, to the extent

possible. Any remaining aboveground piping can be acoustically lagged with a

minimum 3" thick fiberglass or mineral wool (e.g., 8.0 pcf uniform density) that is

covered with a mass-filled vinyl jacket (e.g., composite of 1.0 psf mass-filled vinyl

laminated to 0.020" thick aluminum) if necessary.

Aboveground valves can be covered with removable and/or reusable acoustic material

and/or blankets, if necessary. The blanket material typically consists of a core of 2-inch

thick needled fiber mat (6.0-8.0 pcf density) and a liner material of mass-loaded vinyl

(1.0-1.25 psf surface weight) that is covered with a coated fiberglass cloth. The inner

layer of insulation should be covered with a stainless steel mesh instead of coated



-12-

fiberglass cloth. It is also recommended that any aboveground gas piping should be

separated from other metal structures such as metal gratings, walkways and stairs

around the piping, to the greatest extent possible to facility acoustical lagging.

Please note that thermal insulation (i.e., calcium silicate and banded metal jacketing) is not suitable for attenuating piping noise. If thermal insulation for any piping systems is required for personnel protection, etc., then consideration to utilize the acoustical system described above should be given.

7.8 Unit and Station Control Valves

Any unit or Station control / recycle valves shall be low noise style valves (i.e., Globe

Style) with Whisperflo or Whisper III noise trim.

7.9 Miscellaneous Equipment

Gas Blowdown Silencer (i.e., unit piping purge/unit blowdown): It is recommended that

this sound source is silenced to 50 dBA at 300 ft. (as measured 5 ft. above the ground).

Fuel Gas Skids: It is recommended that any fuel gas skids be designed with regulators

that can achieve 85 dBA at 3 ft. for the worst case design conditions (i.e., anticipated

maximum pressure drop and flow across the regulator valve).

Standby Generator: It is recommended that the remote standby generator JW/AW

cooler is a horizontal type and that the sound level should not exceed 60 dBA at a

distance of 50 feet from the unit perimeter. The generator shall be equipped with a high

performance exhaust silencer (i.e., hospital grade or better).


APPENDIX A – Vicinity Maps and Station Plot Plan H&K Report No. 3354 (07/27/16)

A-1



KIEFERLE

RDHIGHLAND

COMPRESSOR

STATION

BOARD RD

(SR 55)

POS.1

SUNRISE

LAKE

AREA OF ELDRED

PRESERVE RESORT

(CLOSED)APPROXIMATE SCALE IN FEET

0 1400700 2800

N


LEGEND



Figure 1: Proposed Highland Compressor Station and Surrounding Area



A-2


LEGEND





KIEFERLE RD

HIGHLAND

COMPRESSOR

STATION

BOARD RD

(SR 55)

POS.1

3300'

NSA#1

NSA#2

NSA#3

NSA#4

3750'

3000'

2900'


0 800400 1600

N

Figure 2: Proposed Highland Compressor Station and Immediate Area

NLibby

Text Box

Figure 3: Proposed Highland Compressor Station Plot Plan Provided under Separate Cover in Volume IV-B – CRITICAL ENERGY INFRASTRUCTURE INFORMATION – DO NOT RELEASE


APPENDIX B – Measurement Data H&K Report No. 3354 (07/27/16)

B-1

Meas'd A-Wt. Sound Levels (dBA)

Measurement Set Day- Avg'd Night- Avg'd Calc'd

time of time of Ldn


Pos. 1 (NSA #1) 12/16/15 40.3 34.8

Houses on Kieferle Rd., 12/16/15 34.8 38.1 33.4 33.5 41.0

3,300 ft. NW of 12/16/15 37.3 32.0 Note (1)

Compressor Unit

Pos. 1 (NSA #2) 12/16/15 40.3 34.8

Houses on Kieferle Rd. 12/16/15 34.8 38.1 33.4 33.5 41.0

3,000 ft. W of 12/16/15 37.3 32.0 Note (1)

Compressor Unit

Pos.1 (NSA #3) 12/16/15 40.3 34.8

House on SR 55, 12/16/15 34.8 38.1 33.4 33.5 41.0

2,900 ft. SW of 12/16/15 37.3 32.0 Note (1)

Compressor Unit

Pos. 1 (NSA #4) 12/16/15 40.3 34.8

House on SR 55, 12/16/15 34.8 38.1 33.4 33.5 41.0

3,750 ft. N-NW of 12/16/15 37.3 32.0 Note (1)

Compressor Unit

Table A: Highland CS (NY): Summary of Ambient Day/Night Sound Levels

(i.e., Ld & Ln) at the NSAs as Meas'd on Dec. 16, 2015, along with Resulting Ldn

Note (1): If both Ld and Ln are measured and/or estimated, Ldn is calculated using the following formula:

Temp. R.H. Wind Wind Peak

Meas. Pos. (°F) (%) Direction Speed Wind

Pos. 1 to Pos. 4 50 42 1 mph 3 mph

Pos. 1 to Pos. 4 55 44 1 mph 3 mph

Table B: Highland CS (NY): Summary of the Meteorological Conditions during the

Sound Survey on Dec. 16, 2015

Primary Nighttime noise: Audible sounds included a distant barking dog and light wind noise.

12:01 AM to 12:10 AM

3:00 PM to 3:00 PM

from NW

from NW

Overcast

Overcast

Time of Tests

Measurement SetSky Conditions

Primary Daytime noise: Audible sounds included traffic noise on SR 55, birds, a distant airplane and light wind noise.







( )

+= + 10/1010/

10dnnd 10

24910

2415log10 LLL


APPENDIX B – Measurement Data H&K Report No. 3354 (07/27/16)

B-2



Pos. 1 (NSA #1) 3:07 PM 41.9 41.0 35.8 36.9 36.6 38.3 28.7 16.2 11.6 40.3

Houses on Kieferle Rd., 3:08 PM 41.9 40.1 33.8 28.5 30.6 32.0 27.0 16.1 11.7 34.8

3,300 ft. NW of 3:09 PM 46.9 44.7 39.2 30.9 30.8 35.3 28.4 16.7 11.7 37.3

Compressor Unit Average SPL 44.3 42.4 36.8 33.6 33.6 35.9 28.1 16.3 11.7 38.1

Pos. 1 (NSA #2) 3:07 PM 41.9 41.0 35.8 36.9 36.6 38.3 28.7 16.2 11.6 40.3

Houses on Kieferle Rd. 3:08 PM 41.9 40.1 33.8 28.5 30.6 32.0 27.0 16.1 11.7 34.8

3,000 ft. W of 3:09 PM 46.9 44.7 39.2 30.9 30.8 35.3 28.4 16.7 11.7 37.3


Pos.1 (NSA #3) 3:07 PM 41.9 41.0 35.8 36.9 36.6 38.3 28.7 16.2 11.6 40.3

House on SR 55, 3:08 PM 41.9 40.1 33.8 28.5 30.6 32.0 27.0 16.1 11.7 34.8

2,900 ft. SW of 3:09 PM 46.9 44.7 39.2 30.9 30.8 35.3 28.4 16.7 11.7 37.3


Pos. 1 (NSA #4) 3:07 PM 41.9 41.0 35.8 36.9 36.6 38.3 28.7 16.2 11.6 40.3

House on SR 55, 3:08 PM 41.9 40.1 33.8 28.5 30.6 32.0 27.0 16.1 11.7 34.8

3,750 ft. N-NW of 3:09 PM 46.9 44.7 39.2 30.9 30.8 35.3 28.4 16.7 11.7 37.3


Table C: Highland CS (NY): Measured Daytime Ambient Ld and Unweighted


Sound Pressure Level (SPL) in dB per Octave-Band Frequency (in Hz)



Pos. 1 (NSA #1) 12:01 AM 39.3 38.2 36.2 28.1 29.0 32.7 25.7 16.3 13.6 34.8

Houses on Kieferle Rd., 12:03 AM 38.5 37.1 36.6 29.0 25.7 31.0 25.7 16.0 14.1 33.4

3,300 ft. NW of 12:04 AM 40.9 40.0 36.0 29.1 27.7 28.4 23.5 16.4 14.3 32.0


Pos. 1 (NSA #2) 12:01 AM 39.3 38.2 36.2 28.1 29.0 32.7 25.7 16.3 13.6 34.8

Houses on Kieferle Rd. 12:03 AM 38.5 37.1 36.6 29.0 25.7 31.0 25.7 16.0 14.1 33.4

3,000 ft. W of 12:04 AM 40.9 40.0 36.0 29.1 27.7 28.4 23.5 16.4 14.3 32.0


Pos.1 (NSA #3) 12:01 AM 39.3 38.2 36.2 28.1 29.0 32.7 25.7 16.3 13.6 34.8

House on SR 55, 12:03 AM 38.5 37.1 36.6 29.0 25.7 31.0 25.7 16.0 14.1 33.4

2,900 ft. SW of 12:04 AM 40.9 40.0 36.0 29.1 27.7 28.4 23.5 16.4 14.3 32.0


Pos. 1 (NSA #4) 12:01 AM 39.3 38.2 36.2 28.1 29.0 32.7 25.7 16.3 13.6 34.8

House on SR 55, 12:03 AM 38.5 37.1 36.6 29.0 25.7 31.0 25.7 16.0 14.1 33.4

3,750 ft. N-NW of 12:04 AM 40.9 40.0 36.0 29.1 27.7 28.4 23.5 16.4 14.3 32.0


Table D: Highland CS (NY): Measured Nighttime Ambient Ld and Unweighted


Sound Pressure Level (SPL) in dB per Octave-Band Frequency (in Hz)


APPENDIX C – Analysis Methodology for Station Noise H&K Report No. 3354 (07/27/16)

C-1

Source No. SOURCE PWL/SPL & EST'D. SOUND LEVEL A-Wt.

& Dist (Ft) CONTRIBUTIONS AT SPEC. DISTANCE 31.5 63 125 250 500 1000 2000 4000 8000 Level

1) PWL of Turbine-Comp. Casing Noise 125 124 126 121 117 117 122 126 122 130

PWL for 1 Titan 130 Unit 125 124 126 121 117 117 122 126 122 130

NR of Noise Control -6 -14 -24 -32 -44 -44 -44 -44 -44

Misc. Atten. 0 0 0 0 0 0 0 0 0

3300 Hemispherical Radiation -68 -68 -68 -68 -68 -68 -68 -68 -68

Atm. Absorption (70% R.H., 60 deg F) 0 0 -1 -1 -2 -5 -10 -25 -45

Source Sound Level Contribution 51 42 33 20 3 0 0 0 0 21

2) Silenced Exhaust System SPL at 400 ft. 63 54 43 37 32 30 30 30 30 39

SPL for 1 unit 63 54 43 37 32 30 30 30 30 39

NR of Additional Noise Control 0 0 0 0 0 0 0 0 0

Misc. Atten. 0 0 0 0 0 0 0 0 0




3) PWL of Turbine Intake System 114 120 127 127 128 131 134 169 161 170


Atten of 1st Stage Silencer 0 -2 -3 -4 -18 -38 -47 -54 -50

Atten of 2nd Stage Silencer -5 -12 -24 -38 -30 -20 -10 -10 -5

Atten of Air Inlet Filter 0 -2 -8 -9 -13 -26 -27 -27 -33

Misc. Atten. 0 0 0 0 0 0 0 0 0




4) PWL of Turbine L.O. Cooler 91 89 86 83 81 79 77 76 71 85

PWL for 1 Lube Oil Cooler 91 89 86 83 81 79 77 76 71 85

NR of Noise Control 0 0 0 0 0 0 0 0 0

Ground Level Shielding 0 0 0 0 0 0 0 0 0




5) PWL of Single Gas Cooler Fan 91 89 86 83 81 79 77 76 71 85

PWL of (12) Fans 102 100 97 94 92 90 88 87 82 96NR of Noise Control 0 0 0 0 0 0 0 0 0



Atm. Absorption (70% R.H., 60 deg F) 0 0 0 0 0 0 0 0 0


6) PWL of Aboveground Piping 88 92 92 92 92 102 102 102 92 108

PWL for 1 Unit 88 92 92 92 92 102 102 102 92 108

NR of Noise Control 0 0 -4 -9 -15 -20 -20 -20 -15



Atm. Absorption (70% R.H., 60 deg F) 0 0 -1 -1 -2 -5 -10 -25 -45 Calc'd

Source Sound Level Contribution 20 24 19 14 7 9 4 0 0 13 Ldn

Est'd Total Contribution of Proposed Station 52 44 35 28 24 22 20 19 15 29.0 35.4

General Note: DIL, NR and PWL values on this spreadsheet should not be used as the specified values. Refer to the

"Noise Control Measures" in the report or other company specifications for the actual specified PWL of equip., noise

reduction (NR) of pipe lagging or building construction, and DIL values of silencers assoc. with the prop. equipment.

PWL or SPL in dB Per Octave-Band Center Freq. (Hz)

Table E: Highland CS (NY): Est'd Sound Contribution of Proposed Station at NSA #1



C-2






Misc. Atten. 0 0 0 0 0 0 0 0 0





SPL for 1 unit 63 54 43 37 32 30 30 30 30 39


Misc. Atten. 0 0 0 0 0 0 0 0 0









Misc. Atten. 0 0 0 0 0 0 0 0 0


















PWL for 1 Unit 88 92 92 92 92 102 102 102 92 108











Table F: Highland CS (NY): Est'd Sound Contribution of Proposed Station at NSA #2



C-3






Misc. Atten. 0 0 0 0 0 0 0 0 0





SPL for 1 unit 63 54 43 37 32 30 30 30 30 39


Misc. Atten. 0 0 0 0 0 0 0 0 0









Misc. Atten. 0 0 0 0 0 0 0 0 0


















PWL for 1 Unit 88 92 92 92 92 102 102 102 92 108











Table G: Highland CS (NY): Est'd Sound Contribution of Proposed Station at NSA #3



C-4






Misc. Atten. 0 0 0 0 0 0 0 0 0





SPL for 1 unit 63 54 43 37 32 30 30 30 30 39


Misc. Atten. 0 0 0 0 0 0 0 0 0









Misc. Atten. 0 0 0 0 0 0 0 0 0


















PWL for 1 Unit 88 92 92 92 92 102 102 102 92 108











Table H: Highland CS (NY): Est'd Sound Contribution of Proposed Station at NSA #4



C-5

DESCRIPTION OF THE STATION NOISE ANALYSIS METHODOLOGY AND THE SOURCE

OF SOUND DATA

In general, the predicted sound level contributed by the proposed Station was calculated as a

function of frequency from estimated octave-band sound power levels (PWLs) for each

significant sound source associated with the Station. The following summarizes the analysis

procedure:

Initially, unweighted octave-band PWLs for each noise source (without noise control) were

determined from actual sound measurements performed by H&K on similar equipment

and/or obtained from the equipment manufacturer.

Then, expected noise reductions in dB per octave-band frequency due to any designated

noise control measures for each source were subtracted from the estimated PWL.

Next, octave-band SPLs for each source (with noise control) were determined by

compensating for sound attenuation due to propagation (hemispherical radiation) and

atmospheric sound absorption.

Shielding from buildings, terrain or foliage has been conservatively ignored.

Finally, the estimated octave-band SPLs for each source (with noise control and other

sound attenuation effects) were corrected for A-weighting, and the total SPLs of all sound

sources were logarithmically summed and corrected for A-weighting to provide the

estimated A-wt. sound level contributed at the specified distance(s) by the proposed Station.


APPENDIX D – Analysis Methodology for Construction Noise H&K Report No. 3354 (07/27/16)

D-1

DESCRIPTION OF THE CONSTRUCTION NOISE ANALYSIS METHODOLOGY AND THE

SOURCE OF SOUND DATA

Equipment Est'd A-Wt. Resulting A-Wt. Assumed Max. Est'd Max. A-Wt.

Type of Power Rating Est'd Number Sound Level at PWL of Single No. Operating PWL or Sound

Equipment or Capacity Required 50 Ft.: Note (1) Piece of Equip. at One Time Level of Equip.

Diesel Generator 250 to 400 HP 1 to 2 81 dBA 113 dBA 1 113

Bulldozer 250 to 700 HP 1 to 2 85 dBA 117 dBA 1 117

Grader 450 to 600 HP 1 to 2 85 dBA 117 dBA 1 117

Backhoe 130 to 210 HP 1 to 2 80 dBA 112 dBA 1 112

Front End Loader 150 to 250 HP 1 to 2 85 dBA 117 dBA 1 117

Truck Loaded 40 Ton As needed 82 dBA 115 dBA 1 115

Est'd Total Maximum A-Wt. PWL (dBA) of All Construction Site Equipment 123 Calc'd

Atten. (dB) due to Hemispherical Sound Propagation (2900 Ft.): Note (2) -67 Ldn

Est'd Attenuation (in dB) due to Air Absorption and/or Foliage: Note (3) -15 Note (4)

Est'd Sound Level (dBA) at the Closest NSA Considering a 41 41

Maximum Number of Equipment Operating at One Time dBA dBA

Table I: Highland CS (NY): Est'd Sound Contribution at the Closest NSA (i.e., NSA #3; approximately

2,900 ft. SW of Site Center) during Peak Construction Activity

Note (1): Noise Emission Levels of construction equipment based on an EPA Report (meas'd sound data for a railroad

construction project) and measured sound data in the field by H&K or other published sound data.

Note (2): Noise attenuation due to hemispherical sound propagation: Sound propagates outwards in all directions

(i.e., length, width, height) from a point source, and the sound energy of a noise source decreases with

increasing distance from the source. In the case of hemispherical sound propagation, the source is located

on a flat continuous plane/surface (e.g., ground), and the sound radiates hemispherically from the source.

The following equation is the theoretical decrease of sound energy when determining the resulting SPL of

a noise source at a specific distance (“r”) of a receiver from a source sound power level (PWL):

Decrease in SPL (“hemispherical propagation”) from a noise source = 20*log(r) – 2.3 dB, where “r” is

distance of the receiver from the noise source. For example, if the distance "r" is 2900 feet between the

site and closest NSA, the “hemispherical propagation” = 20*log(2900) – 2.3 dB = 67 dB.

Note (3): Noise attenuation due to air absorption & foliage: Air absorbs sound energy, and the amount of absorption

("attenuation") is dependent on temperature and relative humidity (R.H.) of the air and the frequency of sound.

For standard day conditions (i.e., no wind, 60 deg. F. and 70% R.H.), the attenuation due to air absorption for

the medium frequency” (i.e., 1000 Hz O.B. SPL) is approximately 1.5 dB per 1,000 feet. In addition, foliage

such as forest/trees between the Station site and nearby NSAs can have a sound attenuation effect depending

on the amount/thickness of the foliage.

Note (4): Calc'd Ldn equal to the est'd A-wt. sound level since construction activities will occur only during daytime.


APPENDIX E - Acoustical Terminology H&K Report No. 3354 (07/27/16)

E-1

Summary of Typical Metrics for Regulating Environmental Noise & Acoustical

Terminology Discussed in the Report

(1) Decibel (dB): A unit for expressing the relative power level difference between acoustical

or electrical signals. It is ten times the common logarithm of the ratio of two related

quantities that are proportional to power. When adding dB or dBA values, the values

must be added logarithmically. For example, the logarithmic addition of 35 dB plus 35

dB is 38 dB.

(2) Human Perception of Change in Sound Level

A 3 dB change of sound level is barely perceivable by the human ear

A 5 or 6 dB change of sound level is noticeable

If sound level increases by 10 dB, it appears as if the sound intensity has doubled.

(3) A-Weighted Sound Level (dBA): The A-wt. sound level is a single-figure sound rating,

expressed in decibels, which correlates to the human perception of the loudness of

sound. The dBA level is commonly used to measure industrial and environmental noise

since it is easy to measure and provides a reasonable indication of the human

annoyance value of the noise. The dBA measurement is not a good descriptor of a

noise consisting of strong low-frequency components or for a noise with tonal

components.

(4) Background or Ambient Noise: The total noise produced by all other sources associated

with a given environment in the vicinity of a specific sound source of interest, and

includes any Residual Noise.

(5) Sound Pressure Level (Lp or SPL): Ten times the common logarithm to the base 10 of

the ratio of the mean square sound pressure to the square of a reference pressure.

Therefore, the sound pressure level is equal to 20 times the common logarithm of the

ratio of the sound pressure to a reference pressure (20 micropascals or 0.0002

microbar).

(6) Octave Band Sound Pressure Level (SPL): Sound is typically measured in frequency

ranges (e.g., high-pitched sound, low-pitched sound, etc.) that provides more

meaningful sound data regarding the sound character of the noise. When measuring

two noise sources for comparison, it is better to measure the spectrum of each noise,

such as in octave band SPL frequency ranges. Then, the relative loudness of two

sounds can be compared frequency range by frequency range. As an illustration, two

noise sources can have the same dBA rating and yet sound completely different. For



E-2

example, a high-pitched sound concentrated at a frequency of 2000 Hz could have the

same dBA rating as a much louder low-frequency sound concentrated at 50 Hz.

(7) Daytime Sound Level (Ld) & Nighttime Sound Level (Ln): Ld is the equivalent A-weighted

sound level, in decibels, for a 15 hour time period, between 07:00 to 22:00 Hours (7:00

a.m. to 10:00 p.m.). Ln is the equivalent A-weighted sound level, in decibels, for a 9

hour time period, between 22:00 to 07:00 Hours (10:00 p.m. to 7:00 a.m.).

(8) Equivalent Sound Level (Leq): The equivalent sound level (Leq) can be considered an

average sound level measured during a period of time, including any fluctuating sound

levels during that period. In this report, the Leq is equal to the level of a steady (in time)

A-weighted sound level that would be equivalent to the sampled A-weighted sound level

on an energy basis for a specified measurement interval. The concept of the measuring

Leq has been used broadly to relate individual and community reaction to aircraft and

other environmental noises.

(9) Day-Night Sound Level (Ldn): The Ldn is an energy average of the measured daytime Leq

(Ld) and the measured nighttime Leq (Ln) plus 10 dB. The 10-dB adjustment to the Ln is

intended to compensate for nighttime sensitivity. As such, the Ldn is not a true measure

of the sound level but represents a skewed average that correlates generally with past

sound surveys which attempted to relate environmental sound levels with physiological

reaction and physiological effects. For a steady sound source that operates

continuously over a 24-hour period and controls the environmental sound level, an Ldn is

approx. 6.4 dB above the measured Leq.

(10) Sound Level Meter (SLM): An instrument used to measure sound pressure level, sound

level, octave-band SPL, or peak sound pressure level, separately or in any combinations

thereof. The measured weighted SPL (i.e., A-Wt. Sound Level or dBA) is obtained by

the use of a SLM having a standard frequency-filter for attenuating part of the sound

spectrum.



E-3

SOUND LEVELS FOR TYPICAL ACTIVITIES REFERENCE AND COMMUNITY RESPONSESSubjective Human Home and Industrial dBA Community and Traffic Reference Community

Response and (Indoor Noise) Scale (Outdoor Noise) Loudness Reaction ToConversation (Level) Outdoor Noise

-- 140 -- Aircraft CarrierThreshold of Pain Military Jet Aircraft

-- 130 --Large Siren at 100 Ft.

Jet Takeoff at 200 Ft. 16 TimesRock Band (Max.) -- 120 -- as Loud

Threshold of Thunderstorm ActivityDiscomfort Discotheque (Max.) 8 Times

-- 110 -- Elevated Train as LoudSymphonic Music (Max.)

Maximum Vocal Effort Auto Horn at 5 Ft. 4 TimesIndustrial Plant -- 100 -- as Loud

Very Loud Compacting Trash TruckNewspaper Printing Rm. 2 Times

Shouting in Ear -- 90 -- Heavy Truck at 25 Ft. as Loud Vigorous ActionFood Blender and Law SuitsSymphonic Music (Typ.) Motorcycle at 25 Ft. Reference

Shouting -- 80 -- Loudness Threats ofGarbage Disposal Small Truck at 25 Ft. Legal Action

Very Annoying Alarm Clock Heavy Traffic at 50 Ft. Appeals to Officials-- 70 -- 1/2 as Loud Widespread

Moderately Loud Vacuum Cleaner Avg. Traffic at 100 Ft. ComplaintsElectric Typewriter

Normal Conversation -- 60 -- 1/4 as Loud Sporadic ComplaintsAir Conditioner at 20 Ft.

Light Traffic at 100 Ft. No Reaction,Typical Office -- 50 -- 1/8 as Loud Although Noise

Quiet is NoticeableLiving Room Typical Suburban AreaBedroom -- 40 --

BirdsongVery Quiet Library

-- 30 --Soft Whisper Broadcasting Studio Rural Area

Just Audible-- 20 --

Threshold-- 10 -- of Hearing

Hoover & Keith Inc. (Consultants in Acoustics) 11391 Meadowglen, Suite D Houston, Texas 77082 -- 0 --

-end of report-

Resource Report 9 – Air and Noise Quality 9G-i Eastern System Upgrade

APPENDIX 9G

Hancock Compressor Station Noise Impact Analysis


HANCOCK COMPRESSOR STATION



H&K Report No. 3353

H&K Job No. 4982



Houston, TX 77024

Submitted by: Brian R. Hellebuyck, P.E.

Hoover & Keith Inc. 11391 Meadowglen, Suite I Houston, TX 77082


Millennium Pipeline Company, L.L.C. Hoover & Keith, Inc. Hancock CS – Eastern System Upgrade H&K Job No. 4982

Noise Impact Analysis H&K Report No. 3353 (07/27/16)

-i-

REPORT SUMMARY

In this report, Hoover and Keith, Inc. (H&K) present the results of a noise impact analysis

associated with a proposed compressor unit addition (i.e., Unit 2) at the existing Hancock

Compressor Station (“Station”), which is owned Millennium Pipeline Company, L.L.C.

(Millennium). The purpose of the acoustical analysis is to:


compressor unit addition (i.e., Unit 2).



Tables I and II (p. ii) depict the noise quality analysis for the modified Station with respect to

the existing Station sound levels and with respect to the existing ambient sound levels,

respectively.

The existing ambient sound levels were documented in a 2012 Ambient Sound Survey and

Noise Impact Analysis associated with the installation of Unit 11. The goal of the ambient

sound survey was to document the lower range of ambient sound levels for the meteorological

conditions that existed during the sound survey. During the 2012 sound survey, the wind

speeds were relatively low (0-5 mph), which resulted in generally still conditions. The sound

measurements were performed at or near the shoulder of public roads and the measurements

were paused to obtain periods of minimum audible traffic noise, no passby traffic, periods with

no direct aircraft flyovers, and other short term sounds to exclude “extraneous sound” from the

sound survey. Observations during the 2012 sound survey indicated that the area surrounding

the Station was a generally quiet rural area that would be controlled by normal environmental

sounds (i.e., birds, insects, wind noise, distant traffic, passby traffic, aircraft, etc.).

It was concluded that the measured sound level data adequately quantified the existing ambient

sound levels around the site for the meteorological conditions that occurred during the 2012

sound survey. It was concluded that throughout a typical year, there may be periods with lower

ambient sound levels than reported, but it was also concluded that the long term ambient sound

levels would be greater than the reported sound levels factoring in the total noise produced by

all sources associated with a given environment.

The existing Station sound levels were documented in a 2014 post-construction sound survey

associated with the installation of Unit 12. The measurements and observations, during the

1 FERC Docket CP13-14-000. Hancock Compressor Station, Ambient Sound Survey and Noise Impact Analysis (associated with the Hancock Compressor Project). H&K RN 2725, August 31, 2012. 2 FERC Docket CP13-14-000. Hancock Compressor Station, Post-Construction Sound Survey. H&K RN 3022, May 22, 2014.



-ii-

NSAs Distance

Center of

Proposed

Unit 2

Leq of

Existing

Station at

Full Load (1)

Ldn of

Existing

Station at

Full Load (1)

Est'd Leq

of

Proposed

Unit 2

Est'd Ldn

of

Proposed

Unit 2

Estimated

Total Leq

(Existing

Station +

Proposed

Unit 2)

Estimated

Total Ldn

(Existing

Station +

Proposed

Unit 2)

Potential

Increase

Above

Existing

Station

(dBA) (dBA) (dBA) (dBA) (dBA) (dB)

NSA #1

(House)675 ft. E 34.4 40.8 38.3 44.7 39.8 46.2 5.4

NSA #2

(House)

1,550 ft. W-

SW28.7 35.1 31.5 37.9 33.3 39.7 4.6

NSA #3

(House)2,175 ft. NE 24.0 30.4 27.2 33.6 28.9 35.3 4.9

NSA #4

(House)

3,775 ft. S-

SE18.5 24.9 22.6 29.0 24.0 30.4 5.5

NSA #5

(Houses)

3,475 ft. E-

NE19.1 25.5 23.0 29.4 24.5 30.9 5.4

(1) H&K RN 3022. Hancock Compressor Station, Post-Construction Sound Survey. May 22, 2014. Table I: Noise Quality Analysis of Modified Station for Existing Station Sound Levels

NSAs Distance

Center of

Proposed

Unit 2

Meas'd Ln (1)

Meas'd Ld (1) Calc'd

Ambient Ldn

(1)

Estimated

Total Leq

(Existing

Station +

Proposed

Unit 2)

Estimated

Total Ldn

(Existing

Station +

Proposed

Unit 2)

Estimated

Total Ldn

(Existing

Station +

Proposed

Unit 2 +

Ambient)

Potential

Increase

Above

Existing

Ambient

(dBA) (dBA) (dBA) (dBA) (dBA) (dB) (dB)

NSA #1

(House)675 ft. E 31.7 43.1 42.6 39.8 46.2 47.8 5.2

NSA #2

(House)

1,550 ft. W-

SW33.7 39.3 41.5 33.3 39.7 43.7 2.2

NSA #3

(House)2,175 ft. NE 31.7 40.7 41.1 28.9 35.3 42.1 1.0

NSA #4

(House)

3,775 ft. S-

SE32.4 41.1 41.6 24.0 30.4 42.0 0.4

NSA #5

(Houses)

3,475 ft. E-

NE33.5 39.5 41.4 24.5 30.9 41.8 0.4

(1) H&K RN 2725. Hancock Compressor Station, Ambient Sound Survey and Noise Impact Analylsis (associated with the

Hancock Compressor Project). August 31, 2012. Table II: Noise Quality Analysis of Modified Station for Existing Ambient Sound Levels



-iii-

2014 sound survey, indicated that the noise of the existing Station did not control the measured

sound levels at any NSA measurement position. In addition, the Station was not audible at

NSA #2 thru NSA #5. Therefore, the existing Station sound levels had to be estimated from a

position inside the Station, where the sound of the Station was dominant.

Table III below summarizes the existing Ambient sound levels, the sound level contribution of

the existing Station, the sound level contribution of the modified Station, and the potential

increase above the existing Station sound levels and the existing Ambient sound levels:

NSAs Distance Center

of Proposed

Unit 2

Existing

Ambient Ldn

(1)

Ldn of

Existing

Station at Full

Load (2)

Ldn of

Modified

Station (i.e.,

Existing Unit

1 + Proposed

Unit 2) at Full

Load

Ldn of

Modified

Station +

Ambient

Potential

Increase

Above

Existing

Station

Sound

Level

Potential

Increase

Above

Existing

Ambient

Sound

Level

(dBA) (dBA) (dBA) (dBA) (dB) (dB)

NSA #1 (House) 675 ft. E 42.6 40.8 46.2 47.8 5.4 5.2

NSA #2 (House) 1,550 ft. W-SW 41.5 35.1 39.7 43.7 4.6 2.2

NSA #3 (House) 2,175 ft. NE 41.1 30.4 35.3 42.1 4.9 1.0

NSA #4 (House) 3,775 ft. S-SE 41.6 24.9 30.4 42.0 5.5 0.4

NSA #5 (Houses) 3,475 ft. E-NE 41.4 25.5 30.9 41.8 5.4 0.4

(1) H&K RN 3022. Hancock Compressor Station, Post-Construction Sound Survey. May 22, 2014.

(1) H&K RN 2725. Hancock Compressor Station, Ambient Sound Survey and Noise Impact Analylsis (associated with the

Hancock Compressor Project). August 31, 2012. Table III: Noise Quality Analysis of Modified Station for the Existing Station Sound Level

Contribution and the Existing Ambient Sound Levels

The results of our 2012 ambient sound survey, 2014 post-construction sound survey,

observations and analysis of the existing Station and proposed Station modifications indicate

that the estimated full load sound level of the modified Station should be significantly less than

an Ldn of 55 dBA.

The potential increase above existing Station sound levels ranges from 4.6 to 5.4 dB, and it

should be noted that this potential increase is relative to the very low sound levels for the

existing Station.

The potential increase above the existing Ambient sound level at NSA #1 is 5.2 dB, which is

primarily due to the close proximity to NSA #1. However, the potential increase above the

existing Ambient sound levels at NSA #2 thru NSA #5 ranges from 0.4 to 2.2 dB, which is



-iv-

representative of a minimum impact. Regarding the human perception for change in sound

level (i.e., potential increase above ambient), a 0-3 dB change in sound level is representative

of a minimum impact, a 5-6 dB change is a noticeable impact, and a 10 dB change is perceived

as a doubling of sound level or a significant impact.

As with the original Hancock Compressor Station project, Millennium intends to implement very

significant noise control measures for the proposed compressor unit addition. In conclusion,

assuming the recommended noise control measures are followed and successfully

implemented, it is our opinion that the sound level attributable to the modified Station should not

exceed the FERC criterion of 55 dBA Ldn at the nearby NSAs and there should be no

perceptible increase in vibration.



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TABLE OF CONTENTS

Page

REPORT SUMMARY. ....................................................................................................i

1.0 INTRODUCTION .......................................................................................................... 1

2.0 SOUND CRITERIA. ...................................................................................................... 1

3.0 DESCRIPTION OF SITE AND PROPOSED COMPRESSOR STATION ...................... 1



4.0 EXISTING STATION SOUND LEVELS. ....................................................................... 3



5.2 Estimated Sound Contribution. ......................................................................... 4


5.4 Estimated Sound Levels for Normal Unit Blowdowns. ....................................... 5


6.0 NOISE CONTROL REQUIREMENTS. ......................................................................... 7

6.1 Compressor Building. ........................................................................................ 7

6.2 Auxiliary Building. .............................................................................................. 8

6.3 Turbine Exhaust System. ................................................................................ 10

6.4 Turbine Air Intake System. .............................................................................. 10

6.5 Turbine Lube Oil Cooler. ................................................................................. 11

6.6 Station Gas Aftercooler. .................................................................................. 11

6.6 Aboveground Gas Piping. ............................................................................... 11

6.7 Unit and Station Control Valves. ..................................................................... 12

6.8 Miscellaneous Equipment. .............................................................................. 12

Figure 1: Hancock Compressor Station and Surrounding Area. .................................... A-1

Figure 2: Hancock Compressor Station and Immediate Area. ...................................... A-2

Figure 3: Hancock Compressor Station Plot Plan. ........................................................ A-3

Tables A-E: Hancock CS: Est'd Sound Contribution of Unit 2 at NSA #1 thru #5. .. B-1 to B-5

Table F: Hancock Station: Est'd Construction Noise at Closest NSA. .......................... C-1

APPENDIX D: Acoustical Terminology Discussed in This Report.......................................... D-1



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1.0 INTRODUCTION

In this report, Hoover and Keith, Inc. (H&K) present the results of a noise impact

analysis associated with a proposed compressor unit addition (i.e., Unit 2) at the existing

Hancock Compressor Station (“Station”), which is owned Millennium Pipeline

Company, L.L.C. (Millennium). The purpose of the acoustical analysis is to:

• Project the sound level contribution that would result from operating the

proposed compressor unit addition (i.e., Unit 2).



2.0 SOUND CRITERIA


(FERC) require that the sound level attributable to a compressor unit addition not

exceed an equivalent day-night sound level (Ldn) of 55 dBA at any nearby NSA, such as

residences, hospitals or schools. The Ldn is an energy average of the daytime Leq (i.e.,

Ld) and nighttime Leq (i.e., Ln) plus 10 dB. For an essentially steady sound source (e.g.,

gas compressor station) that operates continuously over a 24-hour period and controls

the environmental sound level, the Ldn is approximately 6.4 dB above the measured Leq.

Consequently, an Ldn of 55 dBA corresponds to a Leq of 48.6 dBA.

There are no State of New York1, Delaware County2 or Town of Hancock noise

regulations.


and regulate environmental noise is provided at the end of this report in Appendix D

(pp. D-1 to D-3).

3.0 DESCRIPTION OF SITE AND PROPOSED COMPRESSOR UNIT ADDITION


Figure 1 (p. A-1) depicts the Station and surrounding area. Figure 2 (p. A-2) depicts

the Station and immediate surrounding area. The Station is located in the Town of

1 The NYSDEC has a Policy Document (i.e., Program Policy DEP-00-1; Revised Feb. 2, 2001, “Assessing and Mitigating Noise Impacts”) to provide guidance and clarify program issues for NYSDEC staff to ensure compliance with statutory and regulatory requirements for facility operations regulated under New York State Environmental Quality Reviews or “SEQR”. 2 Per Dale R. Downin, Code Enforcement Officer, Delaware County. H&K RN 2725. August 31, 2012.



-2-

Hancock in Delaware County, New York and the Station is approximately 8 miles SE of

downtown Hancock. The surrounding area consists of forested lands, agricultural lands

and residences upon moderately to steeply sloped terrain. Table 1 below depicts the

nearby NSAs and their respective distance and direction to existing Unit 1 and proposed

Unit 2:

Existing Unit 1 Proposed Unit 2

NSA #1 (House) 800 ft. E 675 ft. E

NSA #2 (House) 1,425 ft. W-SW 1,550 ft. W-SW

NSA #3 (House) 2,250 ft. NE 2,175 ft. NE

NSA #4 (House) 3,800 ft. S-SE 3,775 ft. S-SE

NSA #5 (Houses) 3,600 ft. E-NE 3,475 ft. E-NE

NSA Distance and Direction to:

Table 1: Distance and Direction to Nearby NSAs from Compressor Units


Figure 3 (p. A-3) depicts the proposed Station plot plan and Table 2 depicts the Station

compressor units for the modified Station:

Comp. Unit No. Status Model No. Rated HP

Unit 1 Existing Solar Mars 100 13,900

Unit 2 Proposed Solar Titan 130 22,400

36,300Total Existing and Proposed Table 2: Existing and Proposed Compressor Units for the Modified Station

Existing Unit 1 is a Solar Mars 100 Turbine Compressor Unit which contains extensive

noise mitigation measures. The following describes auxiliary equipment and other

notable items associated with the existing station:





• Acoustical insulation on the aboveground gas piping.

• Control / MCC building, station air compressors and standby generator.

Proposed Unit 2 is a Solar Titan 130 unit. The following describes auxiliary equipment

and other notable items associated with the proposed compressor unit:



-3-





• Low noise Station gas aftercooler.

• Aboveground and buried gas piping.

• Electrical building and standby generator.

4.0 EXISTING STATION SOUND LEVELS

The existing Station sound levels were documented in a 2014 post-construction sound

survey associated with the installation of Unit 13. The following Table 3 summarizes the

predicted and actual sound levels upon installation of the Station (i.e., Unit 1):

NSAs Distance Center

of Compressor

Unit

Predicted Leq

of Station at

Full Load (1)

Actual Leq of

Station at Full

Load

Predicted Ldn

of Station at

Full Load (1)

Actual Ldn of

Station at Full

Load

(dBA) (dBA) (dBA) (dBA)

Houses (NSA #1) 800 ft. E-NE 39.3 34.4 45.7 40.8

Houses (NSA #2) 1,425 ft. W-SW 33.8 28.7 40.2 35.1

House (NSA #3) 2,250 ft. NE 29.2 24.0 35.6 30.4

House (NSA #4) 3,800 ft. S-SE 24.0 18.5 30.4 24.9

Houses (NSA #5) 3,600 ft. E-NE 24.5 19.1 30.9 25.5

(1) H&K Report No. 2725 - Hancock Compressor Station, Ambient Sound Survey and Updated Noise

Impact Analysis. August 31, 2012.

Table 3: Hancock Compressor Station – “Predicted” and “Actual” Leq and Ldn

Sound Level Contribution of the Station at Full Load Operation (from

H&K RN 3022)




sources associated with the proposed Station modifications that could impact the sound

contribution at the nearby NSAs. A description of the analysis methodology and source

3 FERC Docket CP13-14-000. Hancock Compressor Station, Post-Construction Sound Survey associated with the Hancock Compressor Project. H&K RN 3022, May 22, 2014.



-4-

of sound data is provided in Appendix B (p. B-5). The following sound sources are

considered significant:

Proposed Unit 2

• Turbine-compressor casing noise that penetrates the compressor building.

• Noise of the turbine unit exhaust system.

• Noise of the turbine air intake system.

• Noise of the electric motor driven lube oil cooler.

• Noise of the Station gas aftercooler addition.

• Noise radiated by any above ground piping.


Tables A-E (pp. B-1 to B-5) show the calculation (i.e., spreadsheet analysis) of the

estimated octave-band SPLs and the A-wt. sound level, at NSAs #1 - #5, contributed by

the significant noise sources associated with the proposed facilities for standard day

propagating conditions (i.e., no wind, 60 deg. F., 70% R.H.) and any shielding from

buildings, terrain or foliage has been conservatively ignored or applied. This

spreadsheet analysis includes the potential noise reduction due to the anticipated and/or

recommended noise control measures for equipment.


Table 4 below summarizes the Noise Quality Analysis for the closest NSAs for the

proposed Station:



-5-

NSAs Distance

Center of

Proposed

Unit 2

Leq of

Existing

Station at

Full Load (1)

Ldn of

Existing

Station at

Full Load (1)

Est'd Leq

of

Proposed

Unit 2

Est'd Ldn

of

Proposed

Unit 2

Estimated

Total Leq

(Existing

Station +

Proposed

Unit 2)

Estimated

Total Ldn

(Existing

Station +

Proposed

Unit 2)

Potential

Increase

Above

Existing

Station

(dBA) (dBA) (dBA) (dBA) (dBA) (dB)

NSA #1

(House)675 ft. E 34.4 40.8 38.3 44.7 39.8 46.2 5.4

NSA #2

(House)

1,550 ft. W-

SW28.7 35.1 31.5 37.9 33.3 39.7 4.6

NSA #3

(House)2,175 ft. NE 24.0 30.4 27.2 33.6 28.9 35.3 4.9

NSA #4

(House)

3,775 ft. S-

SE18.5 24.9 22.6 29.0 24.0 30.4 5.5

NSA #5

(Houses)

3,475 ft. E-

NE19.1 25.5 23.0 29.4 24.5 30.9 5.4

(1) H&K RN 3022. Hancock Compressor Station, Post-Construction Sound Survey. May 22, 2014.

Table 4: Hancock CS - Noise Quality Analysis associated with Proposed Unit 2

As noted above in Table 4, the sound contribution of the modified Station is estimated to

be significantly less than the 55 dBA Ldn FERC Criteria at the nearby NSAs.

5.4 Estimated Sound Levels for Normal Unit Blowdowns

The sound levels associated with high pressure gas venting are a function of initial

blowdown pressure, the diameter and type of blowdown valve, and the diameter and

arrangement of the downstream vent piping. As expected, blowdown sound levels are

loudest at the beginning of the blowdown event and they decrease as the blowdown

pressure decreases.

The following Table 5 summarizes the expected sound levels for normal blowdown

events (i.e., unit start up and shut down) at the closest NSA:

Est'd Initial Sound

Level for Blowdown

(dBA)

Unit Blowdown Houses (NSA #1) 675 41

Distance / Direction

to Blowdown

Silencer

Closest NSA"Normal"

Blowdown Sound

Source

Table 5: Estimated Initial Sound Levels for "Normal" Blowdown Event



-6-


Table F (p. C-1) shows the calculation (i.e., spreadsheet analysis) of the estimated

construction noise during Station construction activities. The acoustical analysis of the

construction related activities considers the noise produced by any significant sound

sources associated with the primary construction equipment that could impact the sound

contribution at the nearby NSAs. The predicted sound contribution of construction

activities was performed only for the closest NSA (i.e., NSA #1).

Construction of the Station will consist of earth work (e.g., site grading, clearing &

grubbing) and construction of the site foundations and equipment, and it is assumed

that the highest level of construction noise would occur during site earth work (i.e., time







noise specifications along with other assumptions that may affect the noise generated

by the facility.

6.1 Compressor Building Special Note It is extremely important that the recommended compressor building noise control

requirements, including the ventilation system requirements, are followed in detail, due

to the stringent acoustical requirements for the project. Alternate and lighter weight

compressor building designs are not endorsed by H&K if proposed by any Compressor

Building vendor.

Building Structure





Personnel entry doors should have a minimum STC-38 sound rating and could

include door glazing if a 2' x 2' maximum view port is employed (e.g., 1/2 inch thick



-7-

laminated glazing or double pane safety glass). Doors should seal well with the

doorframe and be self-closing.

No windows, skylights or "open" louvers should be installed.


patched and well sealed. Building construction details shall be consistent with a high

performance acoustical compressor building.

A double roll up door system shall be utilized for the equipment access opening.

Each overhead sectional roll-up door, as a minimum, should be a 20 gauge

insulated type design (e.g., 20 gauge exterior with a 22 gauge backskin with

insulation core) and should be completely weather-stripped.

Building Ventilation



personnel and equipment doors closed. Personnel and/or equipment doors will only

be opened during maintenance activities.




from the building penetration (i.e., exhaust louver, exhaust hood, etc.), noting that

this sound source is at or near the compressor building roof. A ridge vent shall not

be utilized. Each ventilation inlet and exhaust outlet shall assume that the following

sound pressure levels exist inside the compressor building at and adjacent to the

ventilation equipment:


31.5 63 125 250 500 1000 2000 4000 8000 dBA

85 90 90 95 95 95 95 95 90 101



lined with acoustical insulation. Assuming separate roof exhaust vents will be

utilized, each roof exhaust vent, as a minimum, should include a 36-inch length

silencer (i.e., baffle-type design) mounted between the building surface and

vent/hood (i.e., in the ventilator throat).



-8-

6.2 Electrical Building

Building Structure (for Equipment Areas)





Personnel entry doors should be insulated steel doors with 1/4 inch thick laminated

glass. Doors should seal well with the doorframe and be self-closing.

No windows or "open" louvers should be installed.


patched and well sealed.

Overhead roll-up doors, as a minimum, should be a 22 gauge insulated type design

(e.g., 20 gauge exterior with a 24 gauge backskin with insulation core) and should

be completely weather stripped.

Building Ventilation (for Equipment Areas)



personnel and equipment doors closed. Personnel and/or equipment doors should

only be opened during maintenance activities.




from the building penetration (i.e., exhaust louver, exhaust hood, etc.). Each

ventilation inlet and exhaust outlet shall assume that the following sound pressure

levels exist inside the compressor building at and adjacent to the ventilation

equipment:



-9-


31.5 63 125 250 500 1000 2000 4000 8000 dBA

85 85 85 85 90 90 90 85 75 95

The ventilation system inlet and exhaust systems shall be designed to control interior

building sound that escapes from the inlet and exhaust flow paths, interior building

sound paths across ventilation system components (i.e., ducting break-in noise,

etc.,) and sound that is generated by ventilation equipment (i.e., supply fans,

exhaust fans, louvers, tempering coils, etc.).



lined with acoustical insulation.

Assuming separate roof exhaust vents will be utilized, each roof exhaust vent, as a

minimum, should include a 36-inch length silencer (i.e., baffle-type design) mounted

between the building surface and vent/hood (i.e., in the ventilator throat).

6.3 Turbine Exhaust System

The silenced exhaust system sound level, at 400 ft. and in any direction from the

exhaust stack centerline, shall not exceed the following octave-band sound pressure

levels:

Maximum (i.e., Guaranteed) Sound Pressure Level (SPL)

at 400 ft. from the Exhaust System

31.5 63 125 250 500 1000 2000 4000 8000

63 54 43 37 32 30 30 30 30

The exhaust system acoustical requirement shall include:

• Exhaust stack outlet noise and all exhaust system breakout noise (i.e., for

exterior exhaust system components, including all exterior duct sections,

expansion joints and any oxidation catalyst system).

• Part load to full load turbine unit operation

6.4 Turbine Air Inlet System

The intake system should include two silencers in series (i.e., two stage silencing

system) between the air intake filter and turbine unit. It is recommended that the first



-10-

silencer is located inside the building, while the second stage silencer can be located

outside the building, if required. It is also required that the first stage silencer (and

support system) is acoustically isolated from the second stage silencer (and support

structure) with an acoustical vibration break (i.e., 3” flexible fabric joint). The acoustical

break must be located inside the compressor building. The Solar supplied support

structure for the 1st stage and 2nd stage silencers should be separated (i.e., not span

across the flexible joint).

The first stage silencer should be a 60” "tubular" silencer. The second stage silencer

should be a parallel baffle construction, with an approximately length of 144”. The

combined insertion loss of the 1st and 2nd stage silencers should approximately meet the

following values:

IL Values in dB per Octave-Band Center Freq. for 1st and 2nd Stage Silencers

31.5 63 125 250 500 1000 2000 4000 8000

5 14 27 42 48 58 65 70 55

It is assumed that a pulse style, up-draft, air inlet filter that will be utilized.

6.5 Turbine Unit Lube Oil Cooler

The Solar low noise lube oil cooler (i.e., maximum 83 dBA PWL) with a Moore Class

10000 MAG fan and V-Belt drive is required for this Station.

6.6 Station Gas Aftercooler

It is assumed that each unitized gas cooler will consist of (4) bays with (3) fans per bay.

The A-wt. sound level of each bay should not exceed 53 dBA at a distance of 50 feet

from the unit perimeter at the rated operating conditions (i.e., (3) fans and motors in

operation). Nonetheless, the coolers shall be equipped with V-Belt drive and Moore

Class 10000 MAG style fans (Max. PWL per Fan = 85 dBA) are required, and the

maximum fan tip speed shall not exceed 7,000 fpm.


The Station high pressure gas piping including the Unit suction, discharge and bypass

valves, and the Station suction and discharge headers should be buried, to the extent

possible.

Any remaining aboveground piping can be acoustically lagged with a minimum 3" thick

fiberglass or mineral wool (e.g., 8.0 pcf uniform density) that is covered with a mass-



-11-

filled vinyl jacket (e.g., composite of 1.0 psf mass-filled vinyl laminated to 0.020" thick

aluminum) if necessary.






fiberglass cloth. It is also recommended that any aboveground gas piping should be

separated from other metal structures such as metal gratings, walkways and stairs

around the piping, to the greatest extent possible to facility acoustical lagging.

Please note that thermal insulation (i.e., calcium silicate and banded metal jacketing) is not suitable for attenuating piping noise. If thermal insulation for any piping systems is required for personnel protection, etc, then consideration to utilize the acoustical system described above should be given.

6.8 Unit and Station Control Valves

Any unit or Station control / recycle valves shall be low noise style valves (i.e., Globe

Style) with Whisperflo or Whisper III noise trim.

6.9 Miscellaneous Equipment

Gas Blowdown Silencer (i.e., unit piping purge/unit blowdown): It is recommended that

this sound source is silenced to 50 dBA at 300 ft. (as measured 5 ft. above the ground).

Fuel Gas Skids: It is recommended that any fuel gas skids be designed with regulators

that can achieve 85 dBA at 3 ft. for the worst case design conditions (i.e., anticipated

maximum pressure drop and flow across the regulator valve).

Standby Generator: It is recommended that the remote standby generator JW/AW

cooler is a horizontal type and that the sound level should not exceed 60 dBA at a

distance of 50 feet from the unit perimeter. The generator shall be equipped with a high

performance exhaust silencer (i.e., hospital grade or better).



A-1


1600800 3200- HOUSE

LEGEND


0

N

1 MILE

EXISTING

HANCOCK

COMPRESSOR

STATION

EXISTING

MILLENNIUM

GAS PIPELINE

HUNGRY

HILL RD.

DELAWARE

LAKE

DELAWARE

LAKE RD.

RT. 97

TREES

TREES

TREESTREES

TREES

TREES

TREES

TREES

TREES

TREES

Figure 1: Hancock Compressor Station and Surrounding Area



A-2

NSA #5

NSA #5

PROPOSED

COMPRESSOR

UNIT ADDITION

3475'


0 1100550 2200

- HOUSE


LEGEND



N

EXISTING

HANCOCK

COMPRESSOR

STATION

PROPERTY

LINE

POS. 4

POS. 2

POS. 1

POS. 3

POS. 5

675'

1550'

2175

'

3775'NSA #2

NSA #4

NSA #1

NSA #3DELAWARE

LAKE

EXISTING

MILLENNIUM

GAS PIPELINE

PRIVATE

ACCESS RD.

DELAWARE

LAKE RD.

HUNGRY

HILL RD.

RT. 97

TREES

TREES

TREES

TREES

TREES

TREESTREES

TREES

TREES

Figure 2: Hancock Compressor Station and Immediate Area

NLibby

Text Box

NLibby

Text Box

Figure 3: Proposed Hancock Compressor Station (Modifications) Plot Plan Provided under Separate Cover in Volume IV-B – CRITICAL ENERGY INFRASTRUCTURE INFORMATION – DO NOT RELEASE


APPENDIX B – Analysis Methodology for Proposed Unit 2 H&K Report No. 3353 (07/27/16)

B-1






Misc. Atten. 0 0 0 0 0 0 0 0 0


Atm. Absorption (70% R.H., 60 deg F) 0 0 0 0 0 -1 -2 -5 -9



SPL for 1 unit 63 54 43 37 32 30 30 30 30 39


Misc. Atten. 0 0 0 0 0 0 0 0 0


Atm. Absorption (70% R.H., 60 deg F) 0 0 0 0 0 0 -1 -2 -4







Misc. Atten. 0 0 0 0 0 0 0 0 0













Ground Level Shielding -2 -3 -4 -5 -7 -8 -10 -10 -10





PWL for 1 Unit 88 92 92 92 92 102 102 102 92 108




Atm. Absorption (70% R.H., 60 deg F) 0 0 0 0 0 -1 -2 -5 -9 Calc'd


Est'd Total Contribution of Proposed Comp. Unit 2 63 55 46 37 32 31 29 28 23 38.3 44.7





Table A: Hancock CS (NY): Est'd Sound Contribution of Proposed Unit 2 at NSA #1



B-2






Misc. Atten. 0 0 0 0 0 0 0 0 0


Atm. Absorption (70% R.H., 60 deg F) 0 0 0 -1 -1 -2 -5 -12 -21



SPL for 1 unit 63 54 43 37 32 30 30 30 30 39


Misc. Atten. 0 0 0 0 0 0 0 0 0


Atm. Absorption (70% R.H., 60 deg F) 0 0 0 0 -1 -2 -3 -9 -16







Misc. Atten. 0 0 0 0 0 0 0 0 0


















PWL for 1 Unit 88 92 92 92 92 102 102 102 92 108




Atm. Absorption (70% R.H., 60 deg F) 0 0 0 -1 -1 -2 -5 -12 -21 Calc'd







Table B: Hancock CS (NY): Est'd Sound Contribution of Proposed Unit 2 at NSA #2



B-3






Misc. Atten. 0 0 0 0 0 0 0 0 0





SPL for 1 unit 63 54 43 37 32 30 30 30 30 39


Misc. Atten. 0 0 0 0 0 0 0 0 0









Misc. Atten. 0 0 0 0 0 0 0 0 0


















PWL for 1 Unit 88 92 92 92 92 102 102 102 92 108











Table C: Hancock CS (NY): Est'd Sound Contribution of Proposed Unit 2 at NSA #3



B-4






Misc. Atten. 0 0 0 0 0 0 0 0 0





SPL for 1 unit 63 54 43 37 32 30 30 30 30 39


Misc. Atten. 0 0 0 0 0 0 0 0 0









Misc. Atten. 0 0 0 0 0 0 0 0 0


















PWL for 1 Unit 88 92 92 92 92 102 102 102 92 108











Table D: Hancock CS (NY): Est'd Sound Contribution of Proposed Unit 2 at NSA #4



B-5






Misc. Atten. 0 0 0 0 0 0 0 0 0





SPL for 1 unit 63 54 43 37 32 30 30 30 30 39


Misc. Atten. 0 0 0 0 0 0 0 0 0









Misc. Atten. 0 0 0 0 0 0 0 0 0


















PWL for 1 Unit 88 92 92 92 92 102 102 102 92 108











Table E: Hancock CS (NY): Est'd Sound Contribution of Proposed Unit 2 at NSA #5



B-6


OF SOUND DATA

In general, the predicted sound level contributed by the proposed units were calculated as a

function of frequency from estimated octave-band sound power levels (PWLs) for each

significant sound source associated with the proposed compressor unit addition. The following

summarizes the analysis procedure:









Shielding from buildings, terrain or foliage has been conservatively ignored and/or applied.




estimated A-wt. sound level contributed at the specified distance(s) by the proposed

compressor unit addition.


APPENDIX C – Analysis Methodology for Construction Noise H&K Report No. 3353 (07/27/16)

C-1






Diesel Generator 250 to 400 HP 1 to 2 81 dBA 113 dBA 1 113


Grader 450 to 600 HP 1 to 2 85 dBA 117 dBA 1 117


Front End Loader 150 to 250 HP 1 to 2 85 dBA 117 dBA 1 117







Table F: Hancock CS (NY): Est'd Sound Contribution at the Closest NSA (i.e., NSA #1; approximately

675 ft. E of Site Center) during Peak Construction Activity


















Note (4): Calc'd Ldn approx. equal to the est'd A-wt. sound level since construction activities will occur only during daytime.


APPENDIX D - Acoustical Terminology H&K Report No. 3353 (07/27/16)

D-1







dB is 38 dB.











components.








microbar).


ranges (e.g., high-pitched sound, low-pitched sound, etc.) that provides more

meaningful sound data regarding the sound character of the noise. When measuring

two noise sources for comparison, it is better to measure the spectrum of each noise,

such as in octave band SPL frequency ranges. Then, the relative loudness of two

sounds can be compared frequency range by frequency range. As an illustration, two

noise sources can have the same dBA rating and yet sound completely different. For



D-2

example, a high-pitched sound concentrated at a frequency of 2000 Hz could have the

same dBA rating as a much louder low-frequency sound concentrated at 50 Hz.



a.m. to 10:00 p.m.). Ln is the equivalent A-weighted sound level, in decibels, for a 9

hour time period, between 22:00 to 07:00 Hours (10:00 p.m. to 7:00 a.m.).




















spectrum.



D-3






















-end of report-

Resource Report 9 – Air and Noise Quality 9H-i Eastern System Upgrade

APPENDIX 9H

Ramapo Meter Station Pre-Construction Sound Survey

and Noise Impact Analysis (Eastern System Upgrade)

RAMAPO METER STATION

PRE-CONSTRUCTION SOUND SURVEY and



H&K Report No. 3355

H&K Job No. 4982



Houston, TX 77024

Submitted by: Brian R. Hellebuyck, P.E. Hoover & Keith Inc. 11391 Meadowglen, Suite I Houston, TX 77082


Millennium Pipeline Company, L.L.C. Hoover & Keith, Inc. Ramapo MS – Eastern System Upgrade RN 3355 / JN 4982

Pre-Construction Sound Survey and Noise Impact Analysis (07/27/16)

-i-

REPORT SUMMARY

In this report, Hoover and Keith, Inc. (H&K) present the results of a December 16, 2015 pre-

construction sound survey and subsequent noise impact analysis associated with the proposed

M&R addition at the existing Ramapo Meter Station (Station), which is owned by Millennium

Pipeline Company, L.L.C. (Millennium). The purpose of the pre-construction sound survey

and acoustical analysis is to:

• Locate the existing noise-sensitive areas (NSAs) surrounding the Station and document

the existing Station sound levels.

• Project the sound level contribution that would result from operating the proposed M&R

addition.



The following table summarizes the measured sound levels and noise quality analysis for the

proposed M&R addition at the existing Ramapo Meter Station, at the closest NSAs:

Noise Quality Analysis for the Proposed M&R Addition

at the Existing Ramapo Meter Station at the Closest NSAs

The existing Ramapo Meter Station was not audible at any NSA during the December 16, 2015

post-construction sound survey. The results of our measurements, observations and analysis

indicate that the proposed M&R addition sound level contribution at the nearby NSAs should be

significantly below an Ldn of 55 dBA. Therefore, assuming the recommended noise control

measures are followed and successfully implemented, it is our opinion that the sound level

attributable to the modified Ramapo Meter Station (i.e., existing Meter Station + proposed M&R

addition), should not exceed the FERC criterion of 55 dBA Ldn at the nearby NSAs and there

should be no perceptible increase in vibration.

NSAs Meas'd

Ambient

Ld

Meas'd

Ambient

Ln

Calc'd

Ambient

Ldn (1)

Est'd Leq

of M&R

Addition

Est'd Ldn

of M&R

Addition (2)

Total Ldn +

(Ambient

+ M&R

Addition)

Potential

Increase

Above

Ambient


NSA #1

(Residences)975 ft. E to SE 59.9 31.1 58.7 35.9 42.3 58.8 0.1

NSA #2

(Residences)

1,900 ft. N-NE

to NE46.6 31.3 45.4 28.7 35.1 45.8 0.4

NSA #3

(County Park)

1,950 ft. S-

SW44.5 30.3 43.3 28.5 34.9 43.9 0.6


(2) Via Estimated Leq.

Distance to

Proposed

M&R Addition



-ii-

TABLE OF CONTENTS

Page

REPORT SUMMARY. ....................................................................................................i

1.0 INTRODUCTION .......................................................................................................... 1

2.0 SOUND CRITERIA. ...................................................................................................... 1

3.0 DESCRIPTION OF SITE AND STATION ..................................................................... 2




4.1 Sound Measurement Locations ......................................................................... 2

4.2 Data Acquisition and Sound Measurement Equipment...................................... 3






6.2 Estimated Sound Contribution. .......................................................................... 4



7.0 NOISE CONTROL RECOMMENDATIONS. ................................................................. 6

7.1 Control Valves. ................................................................................................. 6

7.2 Water Bath Heater (Gas Heater). ...................................................................... 6

7.3 Aboveground Gas Piping. ................................................................................. 7

FIGURES AND TABLES

Figure 1: Existing Ramapo Meter Station and Surrounding Area. ................................. A-1

Figure 2: Ramapo Meter Station Plot Plan. ................................................................... A-2

Table A: Measured and Averaged Daytime & Nighttime Leq and Calculated Ldn. .......... B-1

Table B: Meteorological Conditions during the Sound Testing ..................................... B-1

Table C: Measured and Averaged Octave-Band Daytime SPLs during Testing ............ B-2

Table D: Measured and Averaged Octave-Band Nighttime SPLs during Testing .......... B-2

Tables E-G: M&R Addition: Est'd Sound Contribution at NSA #1 - #3. .................... C-1 to C-3

Table H: Est'd Construction Noise at Closest NSA. ...................................................... D-1

APPENDIX E: Town of Ramapo Noise Ordinance. ............................................................... E-1

APPENDIX F: Acoustical Terminology. ................................................................................. F-1



-1-

1.0 INTRODUCTION

In this report, Hoover and Keith, Inc. (H&K) present the results of a December 16, 2015

pre-construction sound survey and subsequent noise impact analysis associated with

the proposed M&R addition at the existing Ramapo Meter Station (Station), which is

owned by Millennium Pipeline Company, L.L.C. (Millennium). The purpose of the pre-

construction sound survey and acoustical analysis is to:

• Locate the existing noise-sensitive areas (NSAs) surrounding the Station and

document the existing Station sound levels.


M&R addition.



2.0 SOUND CRITERIA


(FERC) require that the sound level attributable to a new compressor station (or M&R

Station) not exceed an equivalent day-night sound level (Ldn) of 55 dBA at any nearby

NSA, such as residences, hospitals or schools. The Ldn is an energy average of the

daytime Leq (i.e., Ld) and nighttime Leq (i.e., Ln) plus 10 dB. For an essentially steady

sound source (e.g., regulation station) that operates continuously over a 24-hour period

and controls the environmental sound level, the Ldn is approximately 6.4 dB above the

measured Leq. Consequently, an Ldn of 55 dBA corresponds to a Leq of 48.6 dBA.

There are no State of New York1 noise regulations for the Station. We are unaware of

any Rockland County noise regulations.

The Town of Ramapo has a noise ordinance, and the complete text of Chapter 188.

Noise is included in Appendix E.


and regulate environmental noise is provided at the end of this report in Appendix F (pp.

F-1 to F-3).




-2-

3.0 DESCRIPTION OF SITE AND STATION


Figure 1 (p. A-1) depicts the existing Station and surrounding area. The Station is

located in the Town of Ramapo in Rockland County, NY. The area generally south to

east, and east to north, consists of numerous suburban residences. The area to the

west is a large undeveloped natural area with significant foliage. The closest NSAs are

residences 975 ft. E to SE, 1,900 ft. N-NE to NE and 1,950 ft. S-SW of the proposed

M&R addition.


Figure 2 (p. A-2) depicts the proposed Station Plot Plan, which includes existing M&R

Station equipment. The proposed M&R addition includes the following:

• New filter separators

• New ultrasonic meter runs

• (3) replacement meter runs

• Indirect water bath heater

• Buried flow control valve

• Buried pressure control valves



Three (3) locations were chosen to measure the sound levels near the closest NSAs

located around the Station and the measurement locations are depicted on Figure 1 (p.


position:

Pos. 1: Near NSA #1: Houses approximately 975 ft. E to SE of the proposed M&R

addition.

Pos. 2: Near NSA #2: Houses approximately 1,900 ft. N-NE to NE of the proposed M&R

addition.

Pos. 3: Near NSA #3: At the County Park, approximately 1,950 ft. W-SW of the proposed

M&R addition.



-3-


Ambient sound measurements were performed by Larry Lengyel, of H&K during the

daytime and nighttime periods on December 16, 2015. At the reported sound

measurement locations, the A-wt. equivalent sound levels (Leq) and unweighted octave-

band sound pressure levels (SPLs) were performed at approximately 5 ft. above ground.

Typically, 3 representative samples of the ambient noise were performed at each sound

measurement position. The acoustical measurement system consisted of a Rion Model

NA-27 Sound Level Meter (a Type 1 SLM per ANSI S1.4 & S1.11) equipped with a 1/2-

inch microphone with a windscreen, and SLM was calibrated within 1 year of the sound

test date.



Table A (p. C-1) shows the measured daytime Leq (i.e., Ld) and the measured nighttime


than one (1) sample of the sound level was measured. In addition, Table A includes a

calculated day-night average sound level (i.e., Ldn), as calculated from the measured Ld

and Ln and observations during the measurements. Meteorological conditions during the

tests are summarized in Table B (p. C-1). The measured daytime and nighttime

unweighted octave-band SPLs at the reported sound measurement positions and the

average of the octave-band SPLs are provided in Table C (p. C-2) and Table D (p. C-2),

respectively.

The following Table 1 summarizes the measured daytime (Ld) and measured nighttime

(Ln) at the NSAs along with the calculated Ldn (as calculated from the measured Ld and

measured Ln).

Table 1: Meas’d Sound Levels and Calculated Ldn at the Closest NSA on

August 4-5, 2015

NSAs Meas'd Ld Meas'd Ld Calc'd Ldn (1)

(dBA) (dBA) (dBA)

Pos. 1, Residences (NSA #1) 975 ft. E to SE 59.9 31.1 58.7

Pos. 2, Residences (NSA #2) 1,900 ft. N-NE to NE 46.6 31.3 45.4

Pos. 3, County Park (NSA #2) 1,950 ft. S-SW 44.5 30.3 43.3

Distance to Proposed

M&R Addition




-4-


At NSA #1: Primary Daytime noise: Traffic on Hwy. 202, birds, a distant airplane, light

wind and a distant barking dog. The Station was not audible. Primary Nighttime noise:

Distant traffic on I-87 and light wind. The Station was not audible.

At NSA #2: Primary Daytime noise: Traffic on Hwy. 202, birds, a distant airplane and

light wind. The Station was not audible. Primary Nighttime noise: Distant traffic on I-87

and light wind. The Station was not audible.

At NSA #3: Primary Daytime noise: Traffic on Hwy. 202, a distant airplane and light

wind. The Station was not audible. Primary Nighttime noise: Distant traffic on I-87 and

light wind. The Station was not audible.




sources associated with the proposed facilities that could impact the sound contribution



significant:

• Exterior aboveground piping.

• Noise of the meter runs.

• Noise of the water bath heater.


Tables E-G (pp. C-1 to C-3) show the calculation (i.e., spreadsheet analysis) of the

estimated octave-band SPLs and the A-wt. sound level, at NSA #1 thru NSA #3,

contributed by the significant noise sources associated with the proposed facilities for

standard day propagating conditions (i.e., no wind, 60 deg. F., 70% R.H.) and any

shielding from buildings, terrain or foliage has been conservatively ignored.



modified Station:



-5-

Table 2: Ramapo – M&R Addition - Noise Quality Analysis

The existing Meter Station was not audible at any NSA during the December 16, 2016

post-construction sound survey. As noted above in Table 2, the sound contribution of

the proposed M&R Addition is estimated to be significantly less than the 55 dBA Ldn

FERC Criteria at the nearby NSAs. Therefore, the modified Station (i.e., existing Meter

Station + proposed M&R addition) should also be significantly less than the 55 dBA Ldn

FERC Criteria at the nearby NSAs.


Table H (p. D-1) shows the calculation (i.e., spreadsheet analysis) of the estimated

construction noise during M&R addition construction activities. The acoustical analysis

of the construction related activities considers the noise produced by any significant

sound sources associated with the primary construction equipment that could impact the

sound contribution at the nearby NSAs. The predicted sound contribution of

construction activities was performed only for the closest NSA (i.e., NSA #1).

Construction of the M&R addition will consist of earth work (e.g., site grading, clearing &

grubbing) and construction of the site foundations and equipment, and it is assumed that

the highest level of construction noise would occur during site earth work (i.e., time





NSAs Meas'd

Ambient

Ld

Meas'd

Ambient

Ln

Calc'd

Ambient

Ldn (1)

Est'd Leq

of M&R

Addition

Est'd Ldn

of M&R

Addition (2)

Total Ldn +

(Ambient

+ M&R

Addition)

Potential

Increase

Above

Ambient


NSA #1

(Residences)975 ft. E to SE 59.9 31.1 58.7 35.9 42.3 58.8 0.1

NSA #2

(Residences)

1,900 ft. N-NE

to NE46.6 31.3 45.4 28.7 35.1 45.8 0.4

NSA #3

(County Park)

1,950 ft. S-

SW44.5 30.3 43.3 28.5 34.9 43.9 0.6



Distance to

Proposed

M&R Addition



-6-



noise specifications along with other assumptions that may affect the noise generated by

the facility.

7.1 Control Valves

Millennium intends to place all flow control and pressure control valves, and the majority

of associated piping below grade, to mitigate noise.

7.2 Water Bath Heater (Gas Heater)

It is recommended that the water bath heater meet an A-Wt. sound level of 55 dBA at 50

feet from the heater perimeter at the rated maximum operating conditions (includes any

noise radiated from the heater stack opening). A "low noise" box-type burner assembly

shall be utilized. In addition, the near field sound level of the water bath combustion

intake and exhaust noise shall not exceed the following sound level requirements:

Maximum Allowable A-Wt. Sound Level

Combustion Air Intake Noise (1) (per fire tube) Combustion Exhaust Noise (1) (per fire tube)

85 dBA 85 dBA

(1) At Distances and Positions per the following Figure. For part load to full load operation.

Typical Water Bath Heater

- Elevation - - Plan -

3'

3'

3'

3'

Exhaust Stack

3' and 90 degrees

(in any direction)

Fire Box Area

3' from Flame Arrestor

or Burner Tubes

(in any direction)



-7-


The acoustical analysis indicates that acoustical pipe lagging is not required, because

the majority of new gas piping will be buried. In the event any small piping segments

becomes problematic, the aboveground piping can be acoustically lagged with a

minimum 3" thick fiberglass or mineral wool (e.g., 8.0 pcf uniform density) that is covered

with a mass-filled vinyl jacket (e.g., composite of 1.0 psf mass-filled vinyl laminated to

0.020" thick aluminum) if necessary.






fiberglass cloth.


APPENDIX A – Vicinity Maps and Station Plot Plan (07/27/16)

A-1

Figure 1: Existing Ramapo Meter Station and Surrounding Area


0 1000500 2000



LEGEND



N

EXISTING

POWER

LINE

EXISTING

MILLENNIUM

GAS PIPELINE

EXISTING

AGT GAS

PIPELINE

PROPOSED

METER STATION

ADDITIONS

EXISTING

RAMAPO

METER

STATION

POS. 1

975'

NSA #1

POS. 2

GRAND VIEW

AVE.

(CR-80)

HARVERSTRAW

RD.

(SR-202) OLD

HARVERSTRAW

RD.

SPOOK

ROCK

RD.

SKY

MEADOW

RD.

MAHWAH

RIVER

1900

'

NSA #2EXISTING

COLUMBIA

GAS PIPELINE

POS. 3

COUNTY PARK

1950'

NLibby

Text Box

Figure 2: Ramapo Meter Station Plot Plan Provided under Separate Cover in Volume IV-B – CRITICAL ENERGY INFRASTRUCTURE INFORMATION – DO NOT RELEASE


APPENDIX B – Measurement Data (07/27/16)

B-1


time of time of Ldn


Pos. 1 (NSA #1) 12/16/15 62.6 31.3

Residences 12/16/15 57.9 30.6

975 ft. E to SE 12/16/15 57.1 59.9 31.2 31.1 58.7

of Meter Station

Pos. 2 (NSA #2) 12/16/15 46.3 31.2

Residences 12/16/15 45.8 31.3

1,900 ft. N-NE to NE 12/16/15 47.5 46.6 31.3 31.3 45.4

of Meter Station

Pos. 3 (NSA #3) 12/16/15 44.2 31.5

County Park 12/16/15 44.3 29.3

1,950 ft. S-SW 12/16/15 44.9 44.5 29.6 30.3 43.3

of Meter Station

Table A: Existing Ramapo Meter Station (Ramapo, NY): Summary of Day/Night Sound

Levels at the NSAs as Meas'd on Dec. 16, 2015, along with Resulting Ldn




Meas. Pos. (°F) (%) Direction Speed Wind Sky Conditions



Table B: Existing Ramapo Meter Station (Ramapo, NY): Summary of the Meteorological


Primary Daytime noise: Traffic on Hwy. 202, a distant airplane and light wind. The Station was not audible.

Primary Nighttime noise: Distant traffic on I-87 and light wind. The Station was not audible.

Overcast

Overcast


12:00 PM to 12:30 PM

3:00 AM to 3:30 AM

Time of Tests

Primary Daytime noise: Traffic on Hwy. 202, birds, a distant airplane, light wind and a distant barking dog. The Station was not audible.


Primary Daytime noise: Traffic on Hwy. 202, birds, a distant airplane and light wind. The Station was not audible.


( )

+= + 10/1010/

10dnnd 10

24910

2415log10 LLL



B-2



Pos. 1 (NSA #1) 12:15 PM 71.6 66.5 65.2 60.3 56.1 59.9 54.8 43.2 32.7 62.6

Residences 12:16 PM 55.2 55.8 52.3 52.3 52.7 55.4 50.4 40.5 33.7 57.9

975 ft. E to SE 12:17 PM 56.3 56.0 52.5 46.5 49.0 55.2 49.9 38.7 25.2 57.1

of Meter Station Average SPL 67.1 62.4 60.9 56.3 53.5 57.4 52.3 41.2 31.8 59.9

Pos. 2 (NSA #2) 12:05 PM 52.7 51.7 46.2 40.3 37.7 44.3 38.6 27.5 22.0 46.3

Residences 12:06 PM 52.9 52.1 50.3 41.1 36.5 43.3 38.7 25.4 18.4 45.8

1,900 ft. N-NE to NE 12:07 PM 55.4 53.9 60.7 42.8 35.8 41.6 37.0 24.1 21.0 47.5


Pos. 3 (NSA #3) 12:22 PM 52.8 53.8 48.6 35.9 38.4 42.1 34.4 23.9 20.4 44.2

County Park 12:23 PM 53.3 53.3 46.2 36.5 39.4 42.3 33.6 24.5 24.3 44.3

1,950 ft. S-SW 12:25 PM 52.1 53.7 47.3 38.4 37.9 42.7 35.2 30.0 29.4 44.9


Table C: Existing Ramapo Meter Station (Ramapo, NY): Measured Ld and Unweighted





Pos. 1 (NSA #1) 3:21 AM 42.1 35.5 28.0 25.2 27.9 28.2 23.0 14.8 13.8 31.3

Residences 3:22 AM 42.2 35.7 27.8 24.8 26.9 27.3 23.1 14.6 12.6 30.6

975 ft. E to SE 3:23 AM 42.3 35.4 28.0 27.3 28.4 27.5 23.4 14.6 12.6 31.2


Pos. 2 (NSA #2) 3:11 AM 42.2 36.3 28.1 26.7 28.7 27.5 23.0 14.4 12.2 31.2

Residences 3:12 AM 42.6 37.6 29.5 27.6 28.6 27.6 23.0 14.4 12.1 31.3

1,900 ft. N-NE to NE 3:13 AM 42.8 36.6 28.2 26.0 28.2 28.1 23.0 14.4 12.3 31.3


Pos. 3 (NSA #3) 3:02 AM 43.3 37.9 29.9 26.4 29.1 28.3 21.6 14.0 12.8 31.5

County Park 3:03 AM 43.3 39.3 30.5 24.6 28.1 24.4 19.3 14.6 13.1 29.3

1,950 ft. S-SW 3:04 AM 43.1 39.1 30.8 25.3 28.1 24.6 19.9 16.8 15.7 29.6


Table D: Existing Ramapo Meter Station (Ramapo, NY): Measured Ln and Unweighted




APPENDIX C – Analysis Methodology for Station Noise (07/27/16)

C-1

Source No. SOURCE PWL & OTHER CONDITIONS/FACTORS PWL or SPL in dB Per Octave-Band Center Freq. (Hz) A-Wt.

& Dist (Ft) ASSOCIATED WITH THE ACOUSTICAL ANALYSIS 31.5 63 125 250 500 1000 2000 4000 8000 Level

1) PWL of "Low Noise" Natural Gas Heater (1 unit) 102 100 96 92 88 86 84 80 76 92


Misc. Atten. 0 0 0 0 0 0 0 0 0




2) PWL of ReRadiated Noise (Below Ground Regulators) 100 97 100 100 102 106 106 104 100 111


Misc. Atten. 0 0 0 0 0 0 0 0 0




3) PWL of Other Aboveground Piping 71 66 71 71 73 77 77 75 71 82


Misc. Atten. 0 0 0 0 0 0 0 0 0




4) PWL of Meter Runs 80 83 90 90 83 80 80 80 80 88


Misc. Atten. 0 0 0 0 0 0 0 0 0


Atm. Absorption (70% R.H., 60 deg F) 0 0 0 0 -1 -1 -3 -7 -13 Calc'd


Est'd Total Contribution 44 43 39 36 32 31 29 22 13 35.9 42.3

Table E: Ramapo M&R Addition - Est'd Sound Contribution at NSA #1



C-2





Misc. Atten. 0 0 0 0 0 0 0 0 0






Misc. Atten. 0 0 0 0 0 0 0 0 0






Misc. Atten. 0 0 0 0 0 0 0 0 0




4) PWL of Meter Runs 80 83 90 90 83 80 80 80 80 88


Misc. Atten. 0 0 0 0 0 0 0 0 0





Table F: Ramapo M&R Addition - Est'd Sound Contribution at NSA #2



C-3





Misc. Atten. 0 0 0 0 0 0 0 0 0






Misc. Atten. 0 0 0 0 0 0 0 0 0






Misc. Atten. 0 0 0 0 0 0 0 0 0




4) PWL of Meter Runs 80 83 90 90 83 80 80 80 80 88


Misc. Atten. 0 0 0 0 0 0 0 0 0





Table G: Ramapo M&R Addition - Est'd Sound Contribution at NSA #3



C-4


OF SOUND DATA

In general, the predicted sound level contributed by the proposed M&R equipment was

calculated as a function of frequency from estimated octave-band sound power levels (PWLs)

for each significant sound source associated with the proposed facilities. The following

summarizes the analysis procedure:









Shielding from buildings, terrain or foliage has been conservatively ignored.




estimated A-wt. sound level contributed at the specified distance(s) by the proposed

facilities.


APPENDIX D – Analysis Methodology for Construction Noise (07/27/16)

D-1














Table H: Existing Ramapo MS: Est'd Sound Contribution at the Closest NSA (i.e., NSA #1; approx.

975 ft. E to SE of Proposed M&R Addition during Peak Construction Activity




















APPENDIX E – Town of Rockland Noise Ordinance (07/27/16)

E-1

Chapter 188. Noise [HISTORY: Adopted by the Town Board of the Town of Ramapo 8-25-1982 by L.L. No. 7-1982. Amendments noted where applicable.]

GENERAL REFERENCES Alarm systems — See Ch. 86. Animals — See Ch. 93. Blasting and explosives — See Ch. 104. Landscapers — See Ch. 173. Peddling and soliciting — See Ch. 199.

§ 188-1. Title.

This chapter shall be cited and may be referred to hereinafter as the "Noise Pollution Control Law of the Town of Ramapo."

§ 188-2. Legislative intent.

It is the intention of the Town Board of the Town of Ramapo by the adoption of this chapter to establish and impose restrictions upon the creation of excessive, unnecessary or unusually loud noise within the limits of the Town of Ramapo in pursuance of and for the purpose of securing and promoting the public health, comfort, convenience, safety, welfare, prosperity and the peace and quiet of the Town of Ramapo and its inhabitants.

§ 188-3. Definitions.

A. All terminology defined herein which relates to the nature of sound and the mechanical detection and recordation of sound is in conformance with the terminology of the American National Standards Institute or its successor body.

B. As used in this chapter, unless the context otherwise clearly indicates, the words and phrases used in this chapter are defined as follows: A-WEIGHTED SOUND LEVEL [DB(A)]

The sound pressure level in decibels as measured on a sound meter using the A-weighting network slow response. The level so read is designated dB(A).

COMMERCIAL DISTRICT

An area where offices, clinics and the facilities needed to serve them are located; an area with local shopping and service establishments; a tourist-oriented area where hotels, motels and gasoline stations are located; a business strip along a main street containing offices, retail businesses and commercial enterprises; and other commercial enterprises and activities which do not involve the manufacturing, processing or fabrication of any commodity. "Commercial district" shall include but shall not be limited to any parcel of land zoned commercial under Chapter 376, Zoning, of this Code.



E-2

COMMERCIAL PURPOSE Includes the use, operation or maintenance of any sound-amplifying equipment for the purpose of advertising any business, any goods or any services or for the purpose of attracting the attention of the public to or advertising for or soliciting the patronage of customers to or for any performance, show, entertainment, exhibition or event or for the purpose of demonstrating any such sound equipment.

CONSTRUCTION ACTIVITIES

Any and all activity incidental to the erection, demolition, assembling, altering, installing or equipping of buildings, structures, roads or appurtenances thereto, including land clearing, grading, excavating and filling.

CONTINUOUS NOISE

A steady, fluctuating or impulsive noise which exists, essentially without interruption, for a period of 10 minutes or more, with an accumulation of an hour or more over a period of eight hours.

DECIBEL (DB)

A unit of level which denotes the ratio between two quantities which are proportional to power. The number of decibels corresponding to the ratio of two amounts of power is 10 times the logarithm to the base 10 of this ratio.

DEVICE

Any mechanism which is intended to produce or which actually produces sound when operated or handled.

EMERGENCY

Any occurrence or set of circumstances involving actual or imminent physical trauma or property damage which demands immediate action.

EMERGENCY WORK

Any work performed for the purpose of preventing or alleviating the physical trauma or property damage threatened or caused by an emergency.

FLUCTUATING NOISE

The sound pressure level of a fluctuating noise which varies more than six dB(A) during the period of observation when measured with the slow meter characteristic of a sound-level meter.

IMPULSIVE SOUND

A sound of short duration, usually less than one second, with an abrupt onset and rapid decay. Examples of sources of impulsive sound include explosions, drop forge impacts and the discharge of firearms.

INDUSTRIAL DISTRICT

An area in which enterprises and activities which involve the manufacturing, processing or fabrication of any commodity are located. "Industrial district" shall include but shall not be limited to any parcel of land zoned as an industrial district under Chapter 376, Zoning, of this Code.



E-3

MOTOR VEHICLE Any vehicle, such as but not limited to a passenger vehicle, truck, truck-trailer, trailer or semitrailer, propelled or drawn by mechanical power, and shall include motorcycles, snowmobiles, minibikes, go-carts and any other vehicle which is self-propelled.

NOISE

Any sound which annoys or disturbs humans or which causes or tends to cause an adverse psychological or physiological effect on humans.

NOISE DISTURBANCE

Any sound which endangers or injures the safety or health of humans or animals or annoys or disturbs a reasonable person of normal sensitivities or endangers or injures personal or real property.

NOISE SENSITIVE ZONE

Any area designated pursuant to this chapter for the purpose of ensuring exceptional quiet.

NONCOMMERCIAL PURPOSE

The use, operation or maintenance of any sound equipment for other than a commercial purpose. "Noncommercial purpose" shall mean and include but shall not be limited to philanthropic, political, patriotic and charitable purposes.

PERSON

Any individual, association, partnership or corporation, including any officer, employee, department, agency or instrumentality of the state or any political subdivision of a state.

REAL PROPERTY BOUNDARY

A line along the ground surface, and its vertical extension, which separates the real property owned by one person from that owned by another person, but not including intrabuilding real property divisions.

RESIDENTIAL DISTRICT

An area of single- or multiple-family dwellings and shall include areas where multiple-unit dwellings, high-rise apartments and high-density residential districts are located. "Residential district" shall also include but is not limited to hospitals, nursing homes, homes for the aged, schools, courts and similar institutional facilities.

SOUND

An oscillation in pressure, particle displacement, particle velocity or other physical parameter in a medium with internal forces that causes compression and rarefaction of that medium. The description of "sound" may include any characteristics of such sound, including duration, intensity and frequency.

SOUND-LEVEL METER

An instrument, including a microphone, an amplifier, an output meter and frequency weighting networks for the measure of sound levels.



E-4

SOUND REPRODUCTION DEVICE Any device that is designed to be used or is actually used for the production or reproduction of sound, including but not limited to any musical instrument, radio, television, tape recorder, phonograph, loudspeaker, public address system or any other sound-amplifying device.

UNREASONABLE NOISE

Any excessive or unusually loud sound or any sound which either annoys, disturbs, injures or endangers the comfort, repose, health, peace or safety of a reasonable person of normal sensitivities or which causes injury to animal life or damage to property or business. Standards to be considered in determining whether an "unreasonable noise" exists in a given situation include but are not limited to the following:

(1) The volume of the noise.

(2) The intensity of the noise.

(3) Whether the nature of the noise is usual or unusual.

(4) Whether the origin of the noise is usual or unusual.

(5) The volume and intensity of the background noise, if any.

(6) The proximity of the noise to residential sleeping facilities.

(7) The nature and the zoning district of the areas within which the noise emanates.

(8) The time of the day or night the noise occurs.

(9) The time duration of the noise.

(10) Whether the sound source is temporary.

(11) Whether the noise is continuous or impulsive.

§ 188-4. Prohibited acts.

No person shall make, continue or cause or suffer to be made or continued any unreasonable noise as defined in § 188-3B hereof. In particular, without limitation of the foregoing provision of this section, the following enumerated acts are declared to be in violation of this section: A. Animals. No person shall keep, permit or maintain any animal under his control which frequently or for continued duration makes sounds which create an unreasonable noise across a residential real property boundary. This provision shall not apply to veterinarian facilities.

B. Commercial, business and industrial operation. No person shall operate or permit to be operated on a sound source site a commercial business or industrial operation that produces an unreasonable sound level.



E-5

C. Construction. (1) No person shall operate or permit to be operated any tools, machinery or equipment used in construction, drilling or demolition work: (a) Between the hours of 10:00 p.m. and 8:00 a.m. the following day or any time on legal holidays, such that the sound therefrom creates an unreasonable noise across a residential real property boundary. [Amended 2-6-2012 by L.L. No. 2-2012; 3-21-2013 by L.L. No. 1-2013]

(b) At any other time such that the sound level at or across a real property boundary exceeds an L10 of 60 for the daily period of operation.

(2) The provisions of this subsection shall not apply to emergency work.

D. Domestic power tools. No person shall operate or permit the operation of any mechanically powered saw, sander, drill, grinder, lawn or garden tool, snowblower or similar device used outdoors in residential areas between the hours of 10:00 p.m. and 8:00 a.m. of the following day, so as to cause an unreasonable noise across a residential real property boundary.

E. Explosives, firearms and similar devices. No person shall use or fire explosives, firearms or similar devices which create impulsive sounds so as to cause an unreasonable noise across a real property boundary.

F. Horns and signaling devices. No person shall cause or permit to be caused the sounding of any horn or other auditory signaling device on or in any motor vehicle except to serve as a danger warning.

G. Motor vehicle repairs and testing. No person shall repair, rebuild, modify or test any motor vehicle in such a manner as to cause an unreasonable noise across a residential real property boundary or within a noise sensitive zone.

H. Mufflers. No person shall discharge into the open air the exhaust of any steam engine, stationary internal-combustion engine, air-compressor equipment, motor vehicle or other power device which is not equipped with an adequate muffler in constant operation and properly maintained to prevent any unreasonable noise or noise disturbance, and no such muffler or exhaust system shall be modified or used with a cutoff, bypass or similar device which causes said engines, vehicles or other power devices to create an unreasonable noise.

I. Noise sensitive zones. No person shall cause or permit the creation of any sound by means of any device or otherwise on any sidewalk, street or public place adjacent to any hospital, nursing home, school, court, house of worship or public library while such facility is in use at any time, so that such sound disrupts the normal activities conducted at such facilities or disturbs or annoys persons making use of such facilities.



E-6

J. Sound reproduction devices. (1) No person shall operate or cause to be operated a sound reproduction device that produces an unreasonable noise or noise disturbance across a real property boundary between the hours of 11:00 p.m. and 8:00 a.m. the following day or within a noise sensitive zone.

(2) No person shall operate or use or cause to be operated or used any sound reproduction device in any public place in such a manner that the sound emanating therefrom creates an unreasonable noise across a real property boundary.

(3) This section shall not apply to any person participating in a school band or in a parade or sounds emanating from sporting, entertainment or other public events where such devices are used.

K. Trucks. No person shall load any garbage or trash on a compactor truck, or any other truck, whereby the loading, unloading or handling of boxes, crates, equipment or other objects is conducted within a residential district nor within 300 feet of any hotel or motel between the hours of 11:00 p.m. and 6:00 a.m. the following day. [Amended 11-28-1984 by L.L. No. 15-1984]

§ 188-5. Exceptions.

The provisions of this chapter shall not apply to: A. The emission of sound for the purpose of alerting persons to the existence of an emergency.

B. The emission of sound in the performance of emergency work.

§ 188-6. Variances.

A. The Town Board of the Town of Ramapo shall have the authority, consistent with this section, to grant variances to this chapter.

B. Any person seeking a variance pursuant to this section shall file an application with the Town Board. The application shall consist of a letter signed by the applicant and containing a legal form of verification. Such letter shall contain information which demonstrates that bringing the source of sound or activity for which the variance is sought into compliance with this chapter would constitute an unreasonable hardship on the applicant, on the community or on other persons. In addition, the following information shall be provided: (1) The plan, specifications and other information pertinent to such sources.

(2) The characteristics of the sound emitted by the source, including but not limited to the sound levels, the presence of impulsive sounds and the hours during which such sound is generated.



E-7

(3) The noise abatement and control methods used to restrict the emission of sound.

C. The Town Board, upon receipt of such application and upon payment of any fee which shall be required by resolution of the Town Board, shall set the matter down for a public hearing to be held within 30 days from the date the application is submitted. The Town Board shall cause publication of such public hearing to be given in the official newspaper of the Town. The applicant shall give notice of the application by certified mail to all property owners surrounding the sound source site within a radius of 200 feet from the borders of said site.

D. In determining whether to grant or deny the application, the Town Board shall balance the hardship to the applicant, the community and other persons of not granting the variance against the adverse impact on the health, safety and welfare of persons affected, the adverse impact on the property affected and other adverse impacts of granting the special variance.

E. The Town Board shall cause the taking of sound level readings by an agency to be designated by the Town Board in the event that there shall be any dispute as to the sound levels prevailing or to prevail at the sound source site.

F. The Town Board shall have the power to impose restrictions, conditions and the recording of covenants upon any sound source site, including time limits on permitted activity, in the event that it shall grant any variance hereunder.

§ 188-7. Enforcement.

The enforcement of these rules and regulations will be by properly identified Police Department personnel, other duly authorized personnel or by any other special personnel as may be from time to time authorized by the Town Board.

§ 188-8. Penalties for offenses.

Any person, firm or corporation violating any provision of this chapter shall be guilty of a Class 2 violation, as defined in Chapter 1, § 1-15 et seq., of the Revised Code of the Town of Ramapo and shall be fined according to the provisions thereunder. A separate offense shall be deemed committed on each day during or on which a violation occurs or continues.


APPENDIX F - Acoustical Terminology (07/27/16)

F-1







dB is 38 dB.











components.








microbar).


ranges (e.g., high-pitched sound, low-pitched sound, etc.) that provides more meaningful

sound data regarding the sound character of the noise. When measuring two noise

sources for comparison, it is better to measure the spectrum of each noise, such as in

octave band SPL frequency ranges. Then, the relative loudness of two sounds can be

compared frequency range by frequency range. As an illustration, two noise sources

can have the same dBA rating and yet sound completely different. For example, a high-



F-2

pitched sound concentrated at a frequency of 2000 Hz could have the same dBA rating

as a much louder low-frequency sound concentrated at 50 Hz.



a.m. to 10:00 p.m.). Ln is the equivalent A-weighted sound level, in decibels, for a 9 hour

time period, between 22:00 to 07:00 Hours (10:00 p.m. to 7:00 a.m.).




















spectrum.



F-3






















-end of report-

Resource Report 9 – Air and Noise Quality 9I-i Eastern System Upgrade

APPENDIX 9I

Huguenot M&R Station Ambient Sound Survey and

Noise Impact Analysis (Eastern System Upgrade)

HUGUENOT M&R STATION

AMBIENT SOUND SURVEY and



H&K Report No. 3479

H&K Job No. 4982



Houston, TX 77024

Submitted by: Brian R. Hellebuyck, P.E. Hoover & Keith Inc. 11391 Meadowglen, Suite I Houston, TX 77082


Millennium Pipeline Company, L.L.C. Hoover & Keith, Inc. Huguenot RS – Eastern System Upgrade RN 3479 / JN 4982

Ambient Sound Survey and Noise Impact Analysis (07/27/16)

-i-

REPORT SUMMARY

In this report, Hoover and Keith, Inc. (H&K) present the results of a July 6-7, 2016 ambient

sound survey and subsequent noise impact analysis associated with the proposed regulation

equipment at the existing Huguenot M&R Station (Station), which is owned by Millennium

Pipeline Company, L.L.C. (Millennium). The purpose of the ambient sound survey and

acoustical analysis is to:

• Locate the existing noise-sensitive areas (NSAs) surrounding the Station and document

the existing Station sound levels or ambient sound levels.


regulation equipment.

• Determine noise control measures and noise specifications for the Station regulation


The following table summarizes the measured sound levels and noise quality analysis for the

proposed regulation equipment at the existing Huguenot M&R Station, at the closest NSAs:

Noise Quality Analysis for the Proposed Regulation Equipment

at the Existing Huguenot M&R Station at the Closest NSAs

The results of our measurements, observations and analysis indicate that the proposed

regulation equipment sound level contribution at the nearby NSAs will be less than an Ldn of 55

dBA. Therefore, assuming the recommended noise control measures are followed and

successfully implemented, it is our opinion that the sound level attributable to the modified

Huguenot M&R Station, should not exceed the FERC criterion of 55 dBA Ldn at the nearby

NSAs and there should be no perceptible increase in vibration.

NSAs Meas'd

Ambient

Ld

Meas'd

Ambient

Ln

Calc'd

Ambient

Ldn (1)

Est'd Leq

of

Proposed

Regulation

Equipment

Est'd Ldn

of

Proposed

Regulation

Equipment (2)

Total Ldn

(Ambient +

Proposed

Regulation

Equipment)

Potential

Increase

Above

Ambient


NSA #1

(Residences)250 ft. S to NE 50.1 36.6 48.9 42.9 49.3 52.1 3.2

NSA #2

(Residences)

475 ft. NE to

NW44.5 40.3 48.8 36.9 43.3 49.9 1.1

NSA #3

(Residences)

700 ft. NW to

W-NW40.0 37.9 46.5 33.1 39.5 47.3 0.8



Distance to

Proposed

Regulation

Equipment



-ii-

TABLE OF CONTENTS

Page

REPORT SUMMARY. ....................................................................................................i

1.0 INTRODUCTION .......................................................................................................... 1

2.0 SOUND CRITERIA. ...................................................................................................... 1

3.0 DESCRIPTION OF SITE AND STATION ..................................................................... 2




4.1 Sound Measurement Locations ......................................................................... 2

4.2 Data Acquisition and Sound Measurement Equipment...................................... 3






6.2 Estimated Sound Contribution. .......................................................................... 5



7.0 NOISE CONTROL RECOMMENDATIONS. ................................................................. 6

7.1 Control Valves. ................................................................................................. 6

7.2 Water Bath Heater (Gas Heater). ...................................................................... 6

7.3 Aboveground Gas Piping. ................................................................................. 7

FIGURES AND TABLES

Figure 1: Existing Huguenot M&R Station and Surrounding Area.................................. A-1

Figure 2: Existing Huguenot M&R Station and Immediate Area. ................................... A-2

Figure 3: Huguenot M&R Station Plot Plan. .................................................................. A-3

Table A: Measured and Averaged Daytime & Nighttime Leq and Calculated Ldn. .......... B-1

Table B: Meteorological Conditions during the Sound Testing ..................................... B-1

Table C: Measured and Averaged Octave-Band Daytime SPLs during Testing ............ B-2

Table D: Measured and Averaged Octave-Band Nighttime SPLs during Testing .......... B-2

Tables E-G: Est'd Sound Contribution at NSA #1 - #3. ........................................... C-1 to C-2

Table H: Est'd Construction Noise at Closest NSA. ...................................................... D-1

APPENDIX E: Town of Deerpark Noise Ordinance. .............................................................. E-1

APPENDIX F: Acoustical Terminology. ................................................................................. F-1



-1-

1.0 INTRODUCTION

In this report, Hoover and Keith, Inc. (H&K) present the results of a July 6-7, 2016

ambient sound survey and subsequent noise impact analysis associated with the

proposed regulation equipment at the existing Huguenot M&R Station (Station), which

is owned by Millennium Pipeline Company, L.L.C. (Millennium). The purpose of the

ambient sound survey and acoustical analysis is to:

• Locate the existing noise-sensitive areas (NSAs) surrounding the Station and

document the existing Station sound levels or ambient sound levels.




regulation equipment to insure that the facility meets applicable sound level

criteria.

2.0 SOUND CRITERIA


(FERC) require that the sound level attributable to a new compressor station (or M&R

Station) not exceed an equivalent day-night sound level (Ldn) of 55 dBA at any nearby

NSA, such as residences, hospitals or schools. The Ldn is an energy average of the

daytime Leq (i.e., Ld) and nighttime Leq (i.e., Ln) plus 10 dB. For an essentially steady

sound source (e.g., regulation station) that operates continuously over a 24-hour period

and controls the environmental sound level, the Ldn is approximately 6.4 dB above the

measured Leq. Consequently, an Ldn of 55 dBA corresponds to a Leq of 48.6 dBA.

There are no applicable State of New York1 noise regulations for the Station. We are

unaware of any applicable Orange County noise regulations. The Town of Deerpark has

a noise ordinance. The relevant text from Section 230-19 is provided in Appendix E (p.

E-1).


and regulate environmental noise is provided at the end of this report in Appendix F (pp.

F-1 to F-3).




-2-

3.0 DESCRIPTION OF SITE AND STATION


Figure 1 (p. A-1) depicts the existing Station and surrounding area. Figure 2 (p. A-2)

depicts the existing Station and immediate area. The Station is located in the Town of

Deerpark in Orange County, NY. The surrounding area consists of scattered residences

and wooded areas. The closest NSAs are residences 250 ft. E to NE of the proposed

regulation equipment. Additional NSAs are located 475 ft. NE to NW and 700 ft. NW to

W-NW of the proposed regulation equipment.


Figure 3 (p. A-3) depicts the proposed Station Plot Plan. The Station consists of the

following and proposed equipment:

Existing Equipment

• Water bath heater (1 MMBTU/Hr.)

• (2) 2” low noise globe style control valves

Proposed Additional Facilities

• Water bath heater (6 MMBTU/Hr.)

• (2) 8” and (1) 2” regulators that will be placed below grade

• 24” launcher assembly

The operating conditions for the proposed regulation equipment are as follows:

• Normal Inlet Pressure: 1,200 psig

• Normal Outlet Pressure: 920 psig

• Flow Rate: 35 to 130 MM/D



Three (3) locations were chosen to measure the sound levels near the closest NSAs

located around the Station and the measurement locations are depicted on Figure 2 (p.


position:



-3-

Pos. 1: Near NSA #1: Houses approximately 250 ft. S to NE of the proposed regulation

equipment.

Pos. 2: Near NSA #2: Houses approximately 475 ft. NE to NW of the proposed


Pos. 3: Near NSA #3: Houses approximately 700 ft. NW to W-NW of the proposed



Ambient sound measurements were performed by Larry Lengyel, of H&K during the

daytime and nighttime periods on July 6-7, 2016. At the reported sound measurement

locations, the A-wt. equivalent sound levels (Leq) and unweighted octave-band sound

pressure levels (SPLs) were performed at approximately 5 ft. above ground. Typically, 3

representative samples of the ambient noise were performed at each sound

measurement position. The acoustical measurement system consisted of a Rion Model

NA-27 Sound Level Meter (a Type 1 SLM per ANSI S1.4 & S1.11) equipped with a 1/2-

inch microphone with a windscreen, and SLM was calibrated within 1 year of the sound

test date.



Table A (p. C-1) shows the measured daytime Leq (i.e., Ld) and the measured nighttime


than one (1) sample of the sound level was measured. In addition, Table A includes a

calculated day-night average sound level (i.e., Ldn), as calculated from the measured Ld

and Ln and observations during the measurements. Meteorological conditions during the

tests are summarized in Table B (p. C-1). The measured daytime and nighttime

unweighted octave-band SPLs at the reported sound measurement positions and the

average of the octave-band SPLs are provided in Table C (p. C-2) and Table D (p. C-2),

respectively.

The following Table 1 summarizes the measured daytime (Ld) and measured nighttime

(Ln) at the NSAs along with the calculated Ldn (as calculated from the measured Ld and

measured Ln).



-4-

Table 1: Meas’d Sound Levels and Calculated Ldn at the Closest NSA on July

6-7, 2016


At NSA #1: Primary Daytime noise: Distant traffic, birds, wind, insects, and the existing

meter station was faintly audible. Primary Nighttime noise: Distant traffic and a distant

airplane. The existing meter station was not audible.

At NSA #2: Primary Daytime noise: Distant traffic, birds, wind and insects. The existing

Meter Station was not audible. Primary Nighttime noise: Distant traffic and a distant

HVAC unit. The existing meter station was not audible.

At NSA #3: Primary Daytime noise: Distant traffic, birds, wind, and insects. The existing

Meter Station was not audible. Primary Nighttime noise: Distant traffic and a distant

HVAC unit. The existing meter station was not audible.




sources associated with the proposed facilities that could impact the sound contribution



significant:

• Noise of the water bath heater

• Radiated noise of the below grade regulators

• Aboveground piping noise

NSAs Meas'd Ld Meas'd Ld Calc'd Ldn (1)

(dBA) (dBA) (dBA)

Pos. 1, Residences (NSA #1) 250 ft. S to NE 50.1 36.6 48.9

Pos. 2, Residences (NSA #2) 475 ft. NE to NW 44.5 40.3 48.8

Pos. 3, County Park (NSA #2) 700 ft. NW to W-NW 40.0 37.9 46.5

Distance to Proposed

Regulation Equipment




-5-


Tables E-G (pp. C-1 to C-2) show the calculation (i.e., spreadsheet analysis) of the

estimated octave-band SPLs and the A-wt. sound level at NSA #1 thru NSA #3

contributed by the significant noise sources associated with the proposed facilities for

standard day propagating conditions (i.e., no wind, 60 deg. F., 70% R.H.) and any

shielding from buildings, terrain or foliage has been conservatively ignored.



modified Station:

Table 2: Huguenot M&R Station - Noise Quality Analysis

The existing Meter Station was only faintly audible at NSA #1 during the July 6-7, 2016

ambient sound survey. As indicated above, the sound contribution of the proposed

regulation equipment is estimated to be less than the 55 dBA Ldn FERC Criteria at the

nearby NSAs.


Table H (p. D-1) shows the calculation (i.e., spreadsheet analysis) of the estimated

construction noise during construction activities associated with the proposed regulation

equipment. The acoustical analysis of the construction related activities considers the

noise produced by any significant sound sources associated with the primary

construction equipment that could impact the sound contribution at the nearby NSAs.

NSAs Meas'd

Ambient

Ld

Meas'd

Ambient

Ln

Calc'd

Ambient

Ldn (1)

Est'd Leq

of

Proposed

Regulation

Equipment

Est'd Ldn

of

Proposed

Regulation

Equipment (2)

Total Ldn

(Ambient +

Proposed

Regulation

Equipment)

Potential

Increase

Above

Ambient


NSA #1

(Residences)250 ft. S to NE 50.1 36.6 48.9 42.9 49.3 52.1 3.2

NSA #2

(Residences)

475 ft. NE to

NW44.5 40.3 48.8 36.9 43.3 49.9 1.1

NSA #3

(Residences)

700 ft. NW to

W-NW40.0 37.9 46.5 33.1 39.5 47.3 0.8



Distance to

Proposed

Regulation

Equipment



-6-

The predicted sound contribution of construction activities was performed only for the

closest NSA (i.e., NSA #1).

Construction of the proposed regulation equipment will consist of earth work (e.g., site

grading, clearing & grubbing) and construction of the site foundations and equipment,

and it is assumed that the highest level of construction noise would occur during site

earth work (i.e., time frame when the largest amount of construction equipment would

operate). The analysis indicates that the maximum A-wt. noise level of construction

activities at the closest NSA would be equal to or less than 69 dBA (i.e., Ldn of

approximately 69 dBA, since construction would only occur during daytime hours.



noise specifications along with other assumptions that may affect the noise generated by

the facility.

7.1 Control Valves

Millennium intends to place all flow control and pressure control valves, and the majority

of associated piping below grade, to mitigate noise.

7.2 Water Bath Heater (Gas Heater)

It is recommended that the water bath heater meet an A-Wt. sound level of 55 dBA at 50

feet from the heater perimeter at the rated maximum operating conditions (includes any

noise radiated from the heater stack opening). A "low noise" box-type burner assembly

shall be utilized. In addition, the near field sound level of the water bath combustion

intake and exhaust noise shall not exceed the following sound level requirements:

Maximum Allowable A-Wt. Sound Level

Combustion Air Intake Noise (1) (per fire tube) Combustion Exhaust Noise (1) (per fire tube)

85 dBA 85 dBA

(1) At Distances and Positions per the following Figure. For part load to full load operation.



-7-

Typical Water Bath Heater


The acoustical analysis indicates that acoustical pipe lagging is not required, because

the majority of new gas piping will be buried. In the event any small piping segments

becomes problematic, the aboveground piping can be acoustically lagged with a

minimum 3" thick fiberglass or mineral wool (e.g., 8.0 pcf uniform density) that is covered

with a mass-filled vinyl jacket (e.g., composite of 1.0 psf mass-filled vinyl laminated to

0.020" thick aluminum) if necessary.






fiberglass cloth.

- Elevation - - Plan -

3'

3'

3'

3'

Exhaust Stack

3' and 90 degrees

(in any direction)

Fire Box Area

3' from Flame Arrestor

or Burner Tubes

(in any direction)


APPENDIX A – Vicinity Map and Station Plot Plan (07/27/16)

A-1

Figure 1: Existing Huguenot M&R Station and Surrounding Area

NEVERSINK DR

(SR 80)

SHWY 209

NEVERSINK

RIVER

EXISTING

HUGUENOT

M&R STATION

CORA

ROSE LN


0 900450 1800

N


LEGEND




APPENDIX A – Vicinity Map and Station Plot Plan (07/27/16)

A-2

Figure 2: Existing Huguenot M&R Station and Immediate Area


0 200100 400

N


LEGEND





SHWY

209

NSA#1

POS.1

700'

POS.3

POS.2

475'

HUGUENOT

M&R STATION

CORA

ROSE LN

250'

NSA#3

NSA#2

PROPOSED

FACILITIES

NSA#1

NSA#1

NSA#3

NSA#3

NSA#2

NSA#2

NLibby

Text Box

Figure 3: Huguenot Meter Station Plot Plan Provided under Separate Cover in Volume IV-B – CRITICAL ENERGY INFRASTRUCTURE INFORMATION – DO NOT RELEASE



B-1


time of time of Ldn


Pos. 1 (NSA #1) 07/06 - 07/07/16 50.1 38.6

Residences 07/06 - 07/07/16 51.8 33.5

250 ft. S to NE of 07/06 - 07/07/16 47.3 50.1 36.3 36.6 48.9

Proposed Facilities

Pos. 2 (NSA #2) 07/06 - 07/07/16 45.1 39.6

Residences 07/06 - 07/07/16 45.5 39.7

475 ft. NE to NW of 07/06 - 07/07/16 42.1 44.5 41.2 40.3 48.8

Proposed Facilities

Pos. 3 (NSA #3) 07/06 - 07/07/16 39.5 38.3

Residences 07/06 - 07/07/16 40.9 38.3

700 ft. NW to W-NW 07/06 - 07/07/16 39.4 40.0 37.0 37.9 46.5

of Proposed Facilities

Table A: Existing Huguenot M&R Station (Deerpark, NY): Summary of Day/Night Sound

Levels at the NSAs as Meas'd on July 6-7, 2016, along with Resulting Ldn




Meas. Pos. (°F) (%) Direction Speed Wind Sky Conditions

Pos. 1 - 3 87 55 from W 1 mph 3 mph

Pos. 1 - 3 48 44 from W --- ---

Table B: Existing Huguenot M&R Station (Deerpark, NY): Summary of the Meteorological

Conditions during the Sound Survey on July 6-7, 2016


9:30 AM to 10:00 AM

10:15 PM to 10:45 PM

Time of Tests

Primary Daytime noise: Distant traffic, birds, wind, insects, and the existing meter station was faintly audible.

Primary Nighttime noise: Distant traffic and a distant airplane.

Primary Daytime noise: Distant traffic, birds, wind and insects. The existing Meter Station was not audible.

Primary Nighttime noise: Distant traffic and a distant HVAC unit.

Primary Daytime noise: Distant traffic, birds, wind, and insects. The existing Meter Station was not audible.

Primary Nighttime noise: Distant traffic and a distant HVAC unit.

Partly Cloudy

Clear

( )

+= + 10/1010/

10dnnd 10

24910

2415log10 LLL



B-2



Pos. 1 (NSA #1) 9:51 AM 52.8 54.4 51.7 46.8 41.9 46.9 43.9 35.4 27.4 50.1

Residences 9:54 AM 52.0 52.3 55.5 45.8 43.8 48.1 46.3 36.3 27.2 51.8

250 ft. S to NE of 9:55 AM 51.0 55.9 53.9 42.7 37.5 43.9 40.9 30.6 25.8 47.3

Proposed Facilities Average SPL 52.0 54.4 54.0 45.4 41.8 46.6 44.2 34.7 26.9 50.1

Pos. 2 (NSA #2) 9:44 AM 56.7 55.4 54.1 40.8 38.1 41.1 35.9 31.9 29.8 45.1

Residences 9:45 AM 56.4 54.7 50.0 40.0 41.0 41.8 36.3 32.4 34.5 45.5

475 ft. NE to NW of 9:46 AM 56.0 53.5 46.0 38.1 38.2 37.2 31.4 33.0 30.6 42.1


Pos. 3 (NSA #3) 9:37 AM 49.9 50.0 44.7 38.6 32.6 32.2 30.6 31.2 31.9 39.5

Residences 9:38 AM 51.3 50.9 47.3 41.5 35.2 33.3 28.1 30.9 35.5 40.9

700 ft. NW to W-NW 9:39 AM 49.9 49.2 43.1 35.6 33.3 32.4 32.4 31.7 28.7 39.4

of Proposed Facilities Average SPL 50.4 50.1 45.4 39.2 33.8 32.7 30.7 31.3 32.9 40.0

Table C: Existing Huguenot M&R Station (Deerpark, NY): Measured Ld and Unweighted

Octave-Band ("O.B.") SPLs at the NSAs as Measured on July 7, 2016



Pos. 1 (NSA #1) 10:33 PM 43.4 43.0 39.5 36.3 33.5 35.9 29.3 22.9 23.1 38.6

Residences 10:35 PM 41.9 39.8 38.7 35.9 31.0 25.9 21.3 22.3 22.4 33.5

250 ft. S to NE of 10:37 PM 42.8 41.1 39.7 36.7 34.0 30.9 26.1 22.8 23.1 36.3


Pos. 2 (NSA #2) 10:26 PM 49.0 50.6 40.6 34.2 37.3 33.3 27.8 33.0 23.9 39.6

Residences 10:27 PM 48.8 51.1 41.1 34.2 36.5 33.3 27.4 34.1 22.1 39.7

475 ft. NE to NW of 10:28 PM 50.4 51.8 43.6 35.8 38.1 36.0 28.3 34.6 21.2 41.2


Pos. 3 (NSA #3) 10:20 PM 46.7 47.1 44.3 37.9 35.2 32.4 27.3 28.7 22.0 38.3

Residences 10:22 PM 48.6 46.3 42.4 36.6 36.0 32.7 28.1 28.5 21.1 38.3

700 ft. NW to W-NW 10:23 PM 45.2 44.9 40.0 35.3 34.5 31.0 26.6 28.6 21.1 37.0

of Proposed Facilities Average SPL 47.1 46.2 42.6 36.7 35.3 32.1 27.4 28.6 21.4 37.9

Table D: Existing Huguenot M&R Station (Deerpark, NY): Measured Ln and Unweighted

Octave-Band ("O.B.") SPLs at the NSAs as Measured on July 6, 2016





C-1











Misc. Atten. 0 0 0 0 0 0 0 0 0






Misc. Atten. 0 0 0 0 0 0 0 0 0


Atm. Absorption (70% R.H., 60 deg F) 0 0 0 0 0 0 -1 -2 -3 Calc'd


Est'd Total Contribution of Proposed Facilities 55 52 47 42 38 37 36 32 26 42.9 49.3

Table E: Huguenot M&R Station - Est'd Sound Contribution of Proposed Facilities at NSA #1











Misc. Atten. 0 0 0 0 0 0 0 0 0






Misc. Atten. 0 0 0 0 0 0 0 0 0





Table F: Huguenot M&R Station - Est'd Sound Contribution of Proposed Facilities at NSA #2



C-2











Misc. Atten. 0 0 0 0 0 0 0 0 0






Misc. Atten. 0 0 0 0 0 0 0 0 0





Table G: Huguenot M&R Station - Est'd Sound Contribution of Proposed Facilities at NSA #3



C-3


OF SOUND DATA

In general, the predicted sound level contributed by the proposed facilities was calculated as a function of

frequency from estimated unweighted octave-band (O.B.) sound power levels (PWLs) for each significant

sound source associated with the proposed facilities. The following summarizes the analysis procedure

for the analysis:

• Initially, unweighted O.B. PWLs of the significant noise sources associated with the proposed

facilities was determined from actual sound level measurements performed by H&K at similar

type of facilities and/or equipment manufacturer’s sound data;

• Then, expected noise reduction (NR) or attenuation in dB per O.B. frequency due to any noise

control measures, hemispherical sound propagation (discussed in more detail below*) and

atmospheric sound absorption (discussed in more detail below**) were subtracted from the

unweighted O.B. PWLs to obtain the unweighted O.B. SPLs of each noise source. Since sound

shielding by buildings can influence the sound level contributed at the NSAs, we also included the

sound shielding due to buildings, if appropriate. The sound attenuation effect due to vegetation

or land contour were typically not considered in the analyses;

• Finally, the resulting estimated O.B. SPLs for all noise sources (with noise control and other

sound attenuation effects) were logarithmically summed, and the total O.B. SPLs for all noise

sources were corrected for A-weighting to provide the estimated overall A-wt. sound level

contributed by the proposed facilities at the closest NSAs.

*Attenuation due to hemispherical sound propagation: Sound propagates outwards in all directions (i.e.,

length, width, height) from a point source, and the sound energy of a noise source decreases with

increasing distance from the source. In the case of hemispherical sound propagation, the source is

located on a flat continuous plane/surface (e.g., ground), and the sound radiates hemispherically (i.e.,

outward, over and above the surface) from the source. The following equation is the theoretical decrease

of sound energy when determining the resulting SPLs of a noise source at a specific distance (“r”) of a

receiver from a source PWL values:

Decrease in SPL (“hemispherical propagation”) from a noise source = 20*log(r) – 2.3 dB

where “r” is distance of the receiver from the noise source.

**Attenuation due to air absorption: Air absorbs sound energy, and the amount of absorption

(“attenuation”) is dependent on the temperature and relative humidity (R.H.) of air and frequency of

sound. For example, the attenuation due to air absorption for 1000 Hz O.B. SPL is approximately 1.5 dB

per 1,000 feet for standard day conditions (i.e., no wind, 60 deg. F and 70% R.H.).


APPENDIX D – Analysis Methodology for Construction Noise (07/27/16)

D-1














Table H: Existing Huguenot M&R: Est'd Sound Contribution at the Closest NSA (i.e., NSA #1; approx.

250 ft. S to NE of Proposed Facilities during Peak Construction Activity




















APPENDIX E – Town of Deerpark Noise Ordinance (07/27/16)

E-1

Town of Deerpark

• Section 230-19 – General Commercial and Industrial Standards (relevant text from Town

of Deerpark Zoning Law) follows. (page 38-39)



Page 38

the Institute of Transportation Engineers. However, based on the characteristics of a

specific neighborhood, these amounts may be lowered or raised, at the discretion of

the Planning Board. The factors which shall be used for such a determination

include, but are not limited to, pertinent characteristics of the neighborhood such as

width of properties, width of the streets, hills, curves, and the number of children present.

b. Parking – whether or not parking problems could result from the business use.

Factors which shall be used to evaluate this criteria include, but are not limited to the

following: (i) parking required for the business shall be provided on-site; (ii) parking

on the property shall be on a surface equal in quality to the paving surface of any

existing driveway unless there is no surface other than the ground, in which case a

gravel surface shall be provided at a minimum; and (iii) no home occupation shall be

permitted which requires parking of tractor-trailer combinations along the street on a

continuing basis.

3. Nuisance – whether or not the business activity is causing a nuisance to surrounding property owners or is deviating from the residential character or

appearance of the neighborhood.

B. No home occupation, having once been permitted or established, shall be added to, expanded, e

nlarged or otherwise increased or changed substantially in character without complying with is

law and such permission or establishment shall not be a basis for a later application to establish a

principal commercial use. Moreover, the conversion o f a residence with a home occupation to a

commercial use by the abandonment of the residence or sale, rent or transfer of the business to a

party which does not reside on-site is strictly prohibited unless the business in then moved off-site.

§ 230-19 General Commercial and Industrial Standards

Wherever commercial, manufacturing or other non-residential uses, with the exception of agricultural activities and

home occupations, are proposed the following performance standards will apply. The Building Inspector shall

ensure these standards are met prior to issuing Certificates of Occupancy for such uses and may require the

applicant(s) to provide documentation of compliance.

A. Commercial/Residential Buffers: Where a commercial or manufacturing use is contiguous to an

existing residential use in any RS District (including those situated on the opposite side of a highway) or any approved residential lot in an RR or NR District, the Planning Board may require that the

minimum front, side, and rear yards be increased up to fifty percent (50%). The Board may also

require, for purposes of separating incompatible activities or shielding the residence from negative

impacts, that a buffer consisting of a solid fence of wood and/or twenty (20) feet wide dense evergreen

planting not less than six (6) feet high be maintained, unless the properties are in the same ownership

of the full width of the yard is already wooded (see also § 230-55).

B. Inflammables: All activities involving the manufacturing, production, storage, transfer or disposal of

inflammable and explosive materials shall be provided with adequate safety devices against the hazard

of fire and explosion. Firefighting and fire suppression equipment and devices shall be provided

pursuant to National Fire Protection Association guidelines. Burning of waste materials in open fires

is prohibited. Details of the potential hazards and planned safety and accident response actions shall be provided by the applicant and the Planning Board may require greater front, side, and rear yards

and/or fencing.

C. Electric Disturbances: No activities shall be permitted which emit dangerous radioactivity or electrical

disturbance adversely affecting the operation of any equipment other than that of the creator of such

disturbance.



Page 39

D. Noise: The maximum sound pressure level radiated by any non-transportation use or facility at the

property line shall not exceed the values given in Table 1 below after applying adjustments as provided

in Table 2 below. The sound pressure shall be measured with a sound level meter and associated with

Octave Band Analyzer conforming to standards prescribed by the American National Standards

Institute.

TABLE 1

OCTAVE BAND RANGE MAXIMUM SOUND PRESSURE LEVEL

CYCLES PER SECOND DECIBLES (0.002 DYNE/2CM)

20-300 60

300-2,400 40

2,400+ 30

If the noise is not smooth and continuous and is not radiated between the hours of 10:00 PM and 7:00 AM, the adjustments in Table 2 shall be applied to the decibels levels given in Table 1.

Where more than one adjustment is applicable, the largest adjustment only shall apply.

TABLE 2

TYPE OF LOCATION OR ADJUSTMENT IN

NOISE CHARACTER DECIBELS PERMITTED

1. Daytime operation only +5

2. Noise source operates <20% of any given hour +5

3. Property is located in HM-U District at least 500 feet from any Residential District boundary +10

4. Noise of impulsive character (hammering, etc.) -5

5. Noise of periodic character (hum, screech, etc.) -5

Motor vehicle racetracks shall employ noise control suppression mechanisms as provided in the

Town of Deerpark Local Regulating Motor Vehicle Racetracks (Local Law No. 1 of 1991,

as amended).

E. Vibration: No vibration shall be permitted on a regular or continuing basis which is detectable without

instruments at the property line.

F. Lighting: All lighting shall be designed so as to avoid unnecessary or unsafe spillover of light and

glare onto operators of motor vehicles, pedestrians, and land uses in proximity to the light source.

Light sources shall comply with the following standards:

TYPE OF MAXIMUM ILLUMINATION MAXIMUM PERMITTED

LIGHT SOURCE PERMITTED AT PROPERTY LINE HEIGHT OF LIGHT

Globe Light 0.20 Foot-candles 15 feet

>90% Cutoff 0.75 Foot-candles 25 feet <90% Cutoff 2.00 Foot-candles 30 feet

No direct or sky-reflected glare, whether from floodlights or from high-temperature processes

such as combustion or welding or other sources, so as to be visible at the property line on a regulat

or continuing basis, shall be permitted.



F-1







dB is 38 dB.











components.








microbar).


ranges (e.g., high-pitched sound, low-pitched sound, etc.) that provides more meaningful

sound data regarding the sound character of the noise. When measuring two noise

sources for comparison, it is better to measure the spectrum of each noise, such as in

octave band SPL frequency ranges. Then, the relative loudness of two sounds can be

compared frequency range by frequency range. As an illustration, two noise sources

can have the same dBA rating and yet sound completely different. For example, a high-



F-2

pitched sound concentrated at a frequency of 2000 Hz could have the same dBA rating

as a much louder low-frequency sound concentrated at 50 Hz.



a.m. to 10:00 p.m.). Ln is the equivalent A-weighted sound level, in decibels, for a 9 hour

time period, between 22:00 to 07:00 Hours (10:00 p.m. to 7:00 a.m.).




















spectrum.



F-3






















-end of report-

Resource Report 9 – Air and Noise Quality 9J-i Eastern System Upgrade

APPENDIX 9J

Noise Analysis Plot Plans

Provided under Separate Cover in Volume IV-B –

CRITICAL ENERGY INFRASTRUCTURE

INFORMATION – DO NOT RELEASE

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