State Activity Report

May 13, 2014

AGA State Affairs Committee Meeting

NGVS: Kilogram/DGE Issue

NARUC-NASEO-NACAA Principles on EE and 111(d)

Updates from the States

State Legislative Updates

Events

AGA State Affairs Committee Meeting Registration is now open for AGA’s State Affairs Committee Fall Meeting. This year’s event will be held October 5-8 at the

Omni Austin Downtown Hotel in Austin, TX. As in years past, the meeting will feature presentations from commissioners,

state legislators, utility representatives and other notable speakers, and will cover legislative and regulatory topics as well

as rate issues of interest.

Participants in this year’s meeting can look forward to:

• Sharing strategies on how legislators, regulators, utilities and industry can cooperate on utility initiatives • Reviewing how companies are strategizing on issues such as growth and expansion, energy efficiency, NGVs,

customer service, etc. • Discussing and reviewing rate case issues—sharing information on recent rate cases, ROEs, trends and emerging

issues.

Participation is open to all employees of AGA member companies, including pipeline members and Canadian members, and is not limited to members of the State Affairs Committee. The Committee’s associate members are also welcome to attend this event. A preliminary draft agenda for this event will be available in the coming weeks.

To register and for information concerning hotel accommodations, please click here.

Please note: Due to a special event occurring in Austin in the days prior to the meeting, the hotel cut-off date is

Thursday, August 21st at 5pm CDT or until the rooms are sold out, whichever occurs first. The room rate is $229 + tax

per night. We encourage you to make your hotel reservations sooner rather than later.

If you have further questions or need assistance, please contact Ashley Duckman at aduckman@aga.org or (202) 824-

7212.

NGVs: NCWM Kilogram/Diesel Gallon Equivalent Proposal As you may already be aware, the National Conference of Weights & Measures (NCWM), a nonprofit association of

weights and measures officials, is presently considering a requirement that retail natural gas dispensers use kilograms as

the primary unit of sale for LNG.

By way of background, since 1994, standards adopted by NCWM have directed that CNG be dispensed in gasoline gallon

equivalent (GGE) units when sold at retail fueling stations. However, there is currently no national standard for dispensing

LNG as a motor fuel. The natural gas industry has proposed that NCWM amend its rules to allow LNG to be sold in diesel

gallon equivalent (DGE) units because LNG primarily competes with diesel fuel. The purpose of using GGE and DGE is to

provide consumers with units that they can easily compare to the two dominant, traditional transportation fuels.

Presently, NCWM, in conjunction with the National Institute of Standards and Technology (NIST), is considering a proposal

that would adopt kilograms as the standard unit for dispensing LNG. As well, the same regulators and officials advocating

for that approach are encouraging that CNG no longer be sold in GGE. At NCWM meetings held in January 2014, officials

advocated for a proposal that included doing away with the GGE standard by 2016 and replacing it with a requirement that

CNG be sold in kilograms. The GGE/DGE standard will be discussed at regional NCWM meetings this spring, and will be

voted on at the group’s Annual Meeting to be held in Detroit in July.

Clearly, this approach would be a drastic departure from the current system that allows consumers to make easy

comparisons across fuel types. As well, it stands to lead to unnecessary infrastructure costs associated with dispensing

equipment and other issues.

AGA, in conjunction with other stakeholder groups like NGVA and ANGA, is presently engaged in an effort to raise

awareness on this issue and to encourage policymakers to reject proposals for methods of sale for LNG & CNG other than

DGE and GGE. Recently, pro-NGV members in the House of Representatives, Representatives Lee Terry (R-NE) and

John Larson (D-CT), circulated a Dear Colleague letter encouraging NIST to work closely with the natural gas industry and

the NCWM to pursue a dispensing standard that makes sense to both the industry and NGV customers. The final version

of that letter garnered 50 bipartisan signatures. A Senate equivalent to this letter is expected in the near future.

NCWM is made up of state officials, most of whom reside in their respective states’ department of agriculture. Accordingly,

efforts are underway to encourage state policymakers to weigh in on this issue. Governor’s Corbett (PA), Herbert (UT),

Hickenlooper (CO) and Fallin (OK) have sent letters encouraging NCWM to reject the kilogram proposal. An effort is

underway via the Western Governors Association to encourage additional governors to do the same.

For more information, please see below links.

NGVA Call to Action Fact Sheet

NGVA Conversion One-Pager

Terry-Larson Dear Colleague

Corbett Letter

Herbert Letter

Hickenlooper & Fallin Letter

As well, a number of state legislatures have taken up this issue during their 2014 sessions. Please see below for

descriptions of relevant state bills on this topic.

Bill Number Description Action

AL S 237 Defined DGE as it relates to calculating excise tax for CNG/LNG Died

IA S 2338 Revises the method of calculating the excise tax on CNG and LNG used as a special fuel and defines the term gallon as a diesel gallon equivalent with respect to LNG; also relates

to a licensed dispenser and dealer

Enacted

IL S 3369 Provides for the rate of tax imposed on the privilege of operating motor vehicles that use LNG or propane and the tax imposed on CNG; Defines “gallon” as a DGE

Pending

IN H 1380 Relating to various tax and administrative issues which defines gallon as DGE (as defined in 1C 6-6-4. 1-1 (f)) in the case of a special fuel that is LNG

Enacted

MO S 970 Modifies measurement standards and tax rates for CNG and LNG as a motor fuel; defines LNG in DGE

Pending

MO H 2184 Changes laws relating to alternative fuels; Defines LNG in terms of DGE Pending

MS H 1590 Defines the term DGE for the purpose of the tax on LNG and provides that the tax levied on LNG shall be levied on each DGE of LNG

Enacted

NJ S 1084 Relates to a natural gas school bus pilot program but defines costs in DGE Pending

OH H 59 Appropriations bill; It includes the following section:

Sec. 5735.013. For the purposes of this chapter, if the national conference on weights

and measures has adopted a diesel gallon equivalent standard for liquid natural gas,

that standard shall be the equivalent of one gallon of motor fuel. If the national conference on weights and measures has not adopted such a standard, six and six one-

hundredths pounds of liquid

Enacted

OK S 322 Relates to gross production tax and defines LNG on DGE Died

OK S 519 Relates to motor fuel taxation; Provides for a levy of tax on LNG and defines that in DGE Enacted

SC S 832 Relates to definitions concerning the motor fuel user fee; Adds LNG to the definition of alternative fuel and to add DGE to the list of definitions for the chapter

Pending

TN S 1746 Establishes a DGE for purpose of determining the tax on LNG To Gov.

VA S 505 Relates to incentives for expanded use of natural gas as a transportation fuel and defines LNG in terms of DGE

Pending

WY S 69 Relates to fuel tax and specifies the amount of LNG that is equivalent to gasoline and diesel fuel for taxation purposes

Enacted

NARUC, NACAA, NASEO Principles for Including EE in 111 (d) Last week, three state policymaker organizations agreed upon and released a set of principles relating to energy efficiency

that the groups hope EPA will consider and follow in its upcoming regulation requiring carbon dioxide cuts from existing

power plants under Section 111 (d) of the Clean Air Act, commonly referred to as 111 (d).

The National Association of Regulatory Utility Commissioners (NARUC), National Association of State Energy Officials

(NASEO) and National Association of Clean Air Agencies (NACAA) agreed upon a set of ten principles meant to show how

energy efficiency programs can be used as a means of complying with the pending regulations set forth in 111 (d), The

principles provide strategies for EPA to utilize when considering energy efficiency as an option that States can incorporate

in their compliance plans under proposed 111 (d) guidelines. All three groups have long encouraged EPA to maintain

flexibility for the States in their compliance of the regulations, and it is their hope that these principles will serve in that

effort.

The principles are summarized as follows:

Guidance on inclusion of energy efficiency; EPA should provide guidance to States no later than June 2015

setting forth a non-exhaustive list of approvable approaches/provisions that may be included in State compliance

plans;

State energy program recognition; EPA should afford deference to State energy efficiency programs and

policies and allow States to credit programs that utilize the EM&V protocols and standards as described in the

principles document;

Non-utility delivered efficiency; EPA should encourage States to develop a clear path for inclusion, crediting and

administrative review and oversight of non-utility-delivered energy efficiency activities providing emissions

reductions;

Recommended EM&V protocols and approaches; EPA, in consultation with DOE and the States, should

recommend protocols and approaches, and provide technical assistance for EM&V of State, utility and non-utility

provided energy efficiency projects and programs;

Translating electricity savings to avoided emissions; EPA may recommend tools, such as the Avoided

Emissions and Generation Tool, dispatch modeling, and independent system operator/regional transmission

organization (ISO/RTO) forecasting approaches, to calculate the emissions impacts of energy efficiency programs,

projects and policies;

Avoiding double counting; EPA should offer guidance on options for avoiding double counting of emissions

reductions from public investment, utility programs, and non-utility delivered efficiency efforts. Double counting

could occur if an entity funds an efficiency project within a utility’s service territory and transfers the credit to

another regulated party or another State;

Transmission and distribution efficiency; EPA should encourage and credit energy efficiency in the electrical

transmission and distribution system;

Multi-state or regional efficiency programs; EPA should recognize and encourage multi-state and regional

efficiency efforts and compliance strategies, particularly where those programs use harmonized, consistent and

transparent efficiency EM&V protocols and approaches and accounting standards for quantifying electricity savings

and CO2 reductions;

Energy efficiency registry; EPA should recognize that States or private entities may choose to develop or

participate in a voluntary “registry” to establish a transparent data repository for energy efficiency projects or

activities;

Accountability for energy efficiency in state 111(d) plans; NARUC-NASEO-NACAA acknowledge that EPA and

many States believe that Section 111(d) requires that State plans generate reliable, verifiable and enforceable

GHG reductions. Energy efficiency efforts can meet these requirements, and in many cases at lower costs than

other options. Because energy efficiency programs and policies may vary significantly, EPA should invite multiple

approaches to achieving quantifiable and reliable reductions while avoiding imposing onerous and potentially

expensive requirements on the States.

EPA’s existing plant rule is due out by June 1, and is presently under review at OMB. Under Section 111 (d) of the Clean

Air Act, EPA will establish regulatory guidelines for meeting targeted cuts and approve various state-written plans.

Of note, the upcoming regulation would allow power generators to offset their GHG emissions by investing in ‘outside of the

fence’ emissions reductions, which could include investment in combined heat and power (CHP) systems.

Updates from the States IN: IURC Approves Distribution Rider for NIPSCO On April 30, the Indiana Utility Regulatory Commission (URC) approved Northern Indiana Public Service Company’s

(NIPSCO) seven-year gas infrastructure improvement plan and a related request to establish a transmission, distribution,

and storage system improvement charge (TDSIC) rider to facilitate recovery of costs associated with the plan.

As you know, last year, Governor Mike Pence signed SB 560, legislation that sought to provide more regulatory flexibility

as it pertains to cost recovery for necessary utility system improvements. Under the law, the IURC may authorize utilities to

establish a “transmission, distribution and storage system improvement charge,” or TDSIC rider, to facilitate the recovery of

costs associated with infrastructure upgrades including expansion and those intended to improve safety or reliability,

modernize the utility’s system or improve an area’s economic development prospects. Utilities are required to file a seven-

year plan with the IURC and, if approved, the TDSIC rider is to be adjusted semi-annually to provide for recovery of 80% of

all eligible depreciation expenses, operation and maintenance costs, property taxes and a return to be calculated using the

utility’s weighted average cost of capital. The remaining 20% of eligible costs are to be deferred for inclusion in a utility’s

next base rate case.

NIPSCO, a NiSource subsidiary, initially filed for approval of its TDISC rider in October 2013 The company initially did not

seek a TDSIC-related rate increase, but estimates that the cumulative revenue requirement associated with its plan is

roughly $65 million. In its April 30 order, IURC found that that the record demonstrated that NIPSCO’s plan provides a

reasonably detailed overview of what types of projects need to be undertaken and why they are necessary. In its order, the

IURC directed the company to make its TDSIC filings every six months beginning in September 2014.

Notably, earlier this year, the Indiana Office of Utility Customer Council (OUCC) filed testimony in support of the TDSIC

rider, with a few proposed modifications. As we noted in a previous newsletter:

In its March 21 testimony, the IOUCC states that the IURC should approve the companies’ proposed infrastructure

expansion plans based on the following:

Process and criteria used to evaluate asset replacement priority

Reasonableness of project cost estimates

Incremental benefits to ratepayers

The IOUCC also recommends the following:

Companies be required to supply additional project cost and scope details to allow the parties to analyze the

upcoming projects’ eligibility and cost estimate reasonableness

IURC approve the companies’ request to merge their existing pipeline safety adjustment (PSA) mechanisms with

the component of the compliance and system improvement adjustment (CSIA) that addresses cost recovery of the

plans’ federally mandated pipeline compliance initiatives

Implementation of the CSIA mechanism be taken into account when the IURC is considering the appropriate

authorized equity return in future base rate cases

MI: Natural Gas Infrastructure Expansion Legislation State Representative Aric Nesbitt (R-MI) has introduced an infrastructure expansion bill meant to facilitate natural gas

service to underserved and unserved areas in the state of Michigan.

Specifically, HB 5555 would allow a natural gas utility to file an Infrastructure Expansion Investment Plan with the Michigan

Public Service Commission in order to provide the natural gas infrastructure necessary to serve unserved or underserved

areas in the state. Proposed expansion plans must include each of the following: (a) a 1-year plan that projects

investment related to expansion (b) a proposed recovery mechanism that provides for the recovery of the incremental

revenue requirement associated with expansion investments (c) all expected costs and benefits associated with the

proposed investments (d) an investment projection up to 5 years in duration proposed to be recovered in future expansion

recovery mechanisms. The legislation authorizes the PSC to review and approve or amend propose plans within 180

days.

As well, Representative Nesbitt has introduced two additional pieces of legislation relating to pipeline safety. According to

his press release, HBs 5556 and 5557 “propose common sense reforms to strengthen pipeline maintenance, while

encouraging greater communication between natural gas utilities and local emergency management officials on an annual

basis to review the public education safety procedures.” The measures are also intended to enhance transparency in

assessing fines and penalties for violation of the law, which are increased in the legislation, and prohibit the use of

ratepayer funds toward the payment of fines assessed on a natural gas facility.

NJ: Settlement in PSE&G’s Energy Strong Proceeding On May 1, PSE&G’s CEO announced that a settlement relating to the company’s Energy Strong proceeding had been

reached with the New Jersey Board of Public Utilities (BPU), the New Jersey Division of Rate Council and the AARP.

As you may recall, in February 2013 PSE&G filed a proposal with the BPU to establish an Energy Strong infrastructure

improvement program and surcharge mechanisms for cost recovery of associated investments. Under the terms of the

initial filing, PSE&G proposed to invest $3.9 billion over a 10-year period to proactively protect and strengthen its systems

against increasingly frequent severe weather. As part of that proposal, the company conveyed its intent to invest $1.1

billion of that amount into gas service system upgrades.

Though not yet finalized, under the proposed settlement, over the next three years PSE&G would invest the

following: $620 million to raise, relocate or protect switching and substations damaged by recent storms, $100 million to

create redundancy in the system to reduce outages when damage occurs, $100 million to deploy smart grid technologies.

Notably, the proposed settlement also provides for $350 million to replace and modernize 250 miles of low pressure cast

ion gas mains in or near flood areas and $50 million to protect five natural gas metering stations and an LNG station

affected by Superstorm Sandy or located in flood zones. The agreement authorizes a 9.75% ROE for the first $1 billion of

investment through an accelerated recovery mechanism, with the remaining amount to be recovered in a base rate case to

be filed no later than November 2017.

Without exception, a final decision is expected later this month.

NY: Cuomo Announces “Reforming Energy Vision” Initiative On April 24, New York Governor Andrew Cuomo announced an energy modernization initiative that is meant to

fundamentally transform the way electricity is distributed and used in the state.

Known as the “Reforming Energy Vision (REV)” initiative, the effort is meant to result in the development of new policies

and to encourage and reward customers to use new technologies to control energy usage. Under the initiative, utilities will

actively manage and coordinate a wide range of distributed resources, or generate electricity from small energy sources

and link them together, according to the Governor’s press release.

The initiative will be largely guided and driven by the New York Public Service Commission (PSC), which has initiated a

proceeding to lead the regulatory changes necessary to promote more efficient use of energy, increased use of renewable

energy and wider deployment of distributed generation. The initiative is also intended to promote greater use of advanced

energy management products. As part of this effort, the PSC recently released a report which identifies six core policy

outcomes relating to customer knowledge, market animation, system-wide efficiency, fuels and resource diversity, system

reliability and resiliency and carbon reduction. The report also describes the benefits of customer-side resources and

further explains how reforms in ratemaking will be necessary to provide for the correct incentives for utilities and markets.

In the coming months, public proceedings will examine and evaluate the regulatory reforms necessary to shape the roles

and responsibilities of the regulated utilities and retail markets. The effort involves two tracks—the first includes a

collaborative process to examine the role of distribution utilities in enabling market-based deployment of distributed energy

resources and the second will include an examination of changes to current regulatory, tariff and market designs and

incentive structures to better align utility interests and policy objectives. The PSC expects to release policy decisions on

both tracks no later than the first quarter of 2015.

WA: Inslee Signs Executive Order Targeting Climate Change On April 29, Washington Governor Jay Inslee announced his plan to cap the state’s GHG emissions while eliminating the

use of coal and expanding cleaner cars and energy efficiency programs.

In a continuing effort to reduce carbon pollution in the state and to promote energy independence through the use of clean

energy, Inslee signed Executive Order 14-0, which establishes the Carbon Emissions Reduction Task Force and tasks it

with designing a “cap and market” program to help the state cut its emissions by 2020, 2035 and 2050. The panel, which

consists of 21 people, is instructed to provide recommendations in seven key areas and report them to the Governor by

November 2014. Those areas include: carbon emission, coal-fired electricity imported from other states (“coal by wire”),

clean transportation, clean technology, energy efficiency, state government operations and carbon pollution limits.

Notably, the state Legislature would have to approve the carbon program while also funding other climate efforts that the

EO requires of state agencies.

US: States First Initiative to Address Seismicity Issue Late last month, the Interstate Oil and Gas Compact Commission (IOGCC) and the Ground Water Protection Council

(GWPC) announced that they have formed a partnership to address the issue of whether or not oil and gas drilling activities

can be linked to earthquakes.

Formed under the umbrella of the States First Initiative, the effort is being touted as a “State Oil and Gas Regulatory

Exchange (SOGRE)” and will bring together representatives from state oil and gas regulatory agencies and geological

surveys to discuss the possible association between recent seismic events that have occurred in several states and

injection wells. Representatives participating in the Induced Seismicity by Injection Work Group will collaborate and share

science, research and practical experience to equip the states with the best decision making tools, according to the press

release.

As of April 29, representatives from ten states including Arkansas, California, Colorado, Illinois, Kansas, Ohio, Oklahoma,

Pennsylvania, Texas and West Virginia have expressed interest in participating in the SOGRE effort. The move comes

several years after federal and state authorities began drawing a link between the increase in earthquakes and the nation’s

natural gas drilling boom. Several of the states currently participating in the SOGRE effort, most notably Oklahoma, have

had bursts of quakes linked by researchers to deep injection.

State Legislative Updates As we approach 2014’s halfway mark, and as many state legislative sessions have either ended or else are winding down,

AGA’s State Affairs team has begun the process of surveying introduced legislation in order to identify and analyze

relevant state legislative and political trends. In the coming weeks, we will be aggregating information on bills in each of

several issue areas including supply, pipeline safety, pipeline expansion, energy efficiency, natural gas vehicles, etc. We

will then analyze that information in order to provide you with a high-level overview on identified trends from among the

states.

To that end, we wanted to provide you with a snapshot of pipeline safety bills presently being considered in the states so

that you might get a sense of how we intend to catalog and analyze relevant state legislation.

Please let us know if you are aware of any state pipeline safety related legislation that needs to be added to this list or if

you have any questions.

State Pipeline Safety Legislation (as of 5/1/2014)

Bill number Description Action Subcategory

AL H 301 Increases the penalties for violations of gas pipeline systems and hazardous liquid pipeline facilities.

Died Fines

AL S 148 Relates to the "One-Call Notification System," established for the purpose of receiving notifications by persons conducting excavations or demolitions on or near certain property where underground facilities may be located

Enacted Excavation Damage Prevention

CA A 1937 Requires a gas corporation to provide a specified notice to the administration of a school or hospital prior to undertaking nonemergency gas pipeline maintenance

Pending Reporting Requirements

CA S 1371 Requires the Public Utilities Commission to adopt rules and procedures governing the operation, maintenance, repair, and replacement of commission-regulated gas pipeline facilities to minimize leaks as a hazard to be mitigated pursuant to the Natural Gas Pipeline Safety Act of 2011

Pending Leak Mitigation & Repair

CA S 1389 Requires the Public Utilities Commission to adopt rules for gas corporation to follow when determining the maximum allowable operating pressure for an intrastate transmission line

Pending Operations

CT H 5410 Provides that the Public Utilities Regulatory Authority may initiate a docket to investigate the lost and unaccounted for gas of a gas company

Pending Lost and Unaccounted for

Gas

DE SCR 31 Requests that natural gas be monitored for radioactive constituents and reported to the Department of Health and Social Services

Pending Radon

GA S 117 Relates to blasting or excavating near utility facilities; provides for responses by facility owners and operators regarding design locate requests

Enacted Excavation Damage Prevention

IN S 303 Makes the following changes to the Indiana pipeline safety statute: (1) Increases the amount of the civil penalty for a violation from $25,000 to $200,000 per violation per day that the violation persists. (2) Increases the maximum civil penalty from $1,000,000 to $2,000,000

Died Fines

MA H 2148 Relates to natural gas alarms in buildings containing methane or propane emitting equipment. Pending Leak Mitigation & Repair

MA H 2922 Relates to requiring the investigation of gas leak explosions by the Department of Public Utilities Pending Leak Mitigation & Repair

MA H 2934 Relates to the detection and repair of natural gas leaks and reimbursement for damages to trees as determined by a qualified arborist

Pending Leak Mitigation & Repair

MA H 2950 Establishes winter patrol cast iron survey protocols for utility company inspections of gas pipelines. Pending Operations

MA H 3765 Relates to natural gas leaks Substituted for by MA H 3873

Leak Mitigation & Repair; Lost &

Unaccounted for Gas

MA H 3873 Relates to natural gas leaks Pending Leak Mitigation & Repair

MD S 361 Requires a gas transmission company operating within the State to comply with certain federal laws and regulations with respect to gas pipeline safety inspections

Pending Fines; Reporting Requirements

MD S 362 Requires a gas transmission company operating within the State to comply with certain federal laws and regulations with respect to gas pipeline safety inspections

Pending Fines

ME H 1192 Increases the maximum gas safety administrative penalty amounts to be consistent with federal law

Enacted Fines

MN S 1040 Relates to energy; regulates the recovery of certain gas utility infrastructure costs Pending Cost Recovery

MO H 1867 Changes the laws regarding utilities; relates to excavations Pending Excavation Damage Prevention

MS H 576 Revises the term excavate or excavation to exclude routine road or railroad maintenance activities under the law which regulates excavations near underground utility facilities

Died Excavation Damage Prevention

MS S 2396 Revises the definition of the term capital improvements for purposes of the local government capital improvements revolving loan program to include repair, renovation and improvement of municipal natural gas facilities.

Died Cost Recovery

NE L 1045 Redefines the term underground facility for purposes of the One-Call Notification System Act Died Excavation Damage Prevention

NE L 404 Changes State Natural Gas Regulation Act provisions relating to infrastructure system replacement cost recovery charges

Died Cost Recovery

NE L 930 Provides that no excavation shall be performed within twenty-five feet of an underground natural gas transmission line unless a representative of the operator of the underground natural gas transmission line is present at the planned excavation area

Enacted Excavation Damage Prevention

NH H 1224 Requires the Public Utilities Commission to apply annually to the federal PHMSA for authorization to conduct pipeline inspections on its behalf

Pending Fines

NJ A 1161 Directs public utilities and pipeline operators to reimburse municipalities for certain emergency services

Pending Emergency Services

NM H 240 Relates to the natural gas emergency investigation task force; repeals laws 2011, chapter 2, which created the natural gas emergency investigation task force

Pending Emergency Services

NY A 6863 Relates to the protection of public health from exposure to radon in natural gas Pending Radon

NY A 8143 Requires certain information to be filed with the department of public service including details of what is being transported in a gas gathering line or pipeline facility

Pending Reporting Requirements

NY A 9336 Relates to requiring liquid petroleum pipeline facilities to accelerate the repair, rehabilitation, and replacement of equipment or pipelines that are leaking or at a high-risk of leaking

Pending Leak Mitigation & Repair

NY S 1616 Amends the Public Authorities Law; directs the New York state energy research and development authority to conduct a study related to the state's natural gas infrastructure

Pending Leak Mitigation & Repair

NY S 4921 Requires the establishment of a monitoring system for use by local gas distribution corporations for determining and designating, delivery points where gas from a pipeline is transferred to a local gas corporation's distribution system that are appropriate and practicable for monitoring levels of radon and its radioactive progeny

Pending Radon

NY S 5323 Relates to exempting certain out-of-state businesses doing work in the state from certain taxes, fees and requirements when temporarily providing services during declared emergencies

Pending Emergency Services

NY S 7010 Relates to requiring liquid petroleum pipeline facilities to accelerate the repair, rehabilitation, and replacement of equipment or pipelines that are leaking or at a high-risk of leaking

Pending Leak Mitigation & Repair

OK H 2426 Relates to pipelines; grants the Corporation Commission the power and duty to enforce maintenance and operation standards for certain pipelines

Pending Operations

OK S 948 Creates procedures for the prevention of damage to certain pipelines from excavation or demolition activities

Pending Excavation Damage Prevention

OK S 969 Creates the Pipeline Safety Task Force to assess pipeline safety and the prevention of excavation in connection with the Pipeline Inspection, Protection, Enforcement and Safety Act of 2006, the Pipeline Safety, Regulatory Certainty and Job Creation Act of 2011

Pending Excavation Damage Prevention

PA H 1607 Amends the Underground Utility Line Protection Law; relates to excavation or demolition work near well sites under the control of oil or natural gas companies

Pending Excavation Damage Prevention

PA S 506 Amends the act of December 22, 2011 (P.L.586, No.127), known as the Gas and Hazardous Liquids Pipelines Act; further provides for definitions; provides for recreational use and for storm water runoff

Pending Misc.

RI H 5615 Would require that all natural gas emergencies be reported to a central dispatch office staffed by professionally trained gas dispatchers.

Pending Reporting Requirements

TN S 851 Creates the Underground Utility Damage Prevention Advisory Committee to review the Underground Utility Damage Prevention Program in order to evaluate its compliance with applicable federal requirements and to make recommendations to the general assembly.

Enacted Excavation Damage Prevention

UT H 395 Enacts the Oil or Hazardous Liquids Release Act; addresses unlawful activities, fines, and penalties related to natural gas, oil, pollutants, and hazardous materials;

Died Leak Mitigation & Repair

VT H 612 Relates to Gas Pipeline Safety Program penalties; proposes to increase the civil penalties for violations of the Gas Pipeline Safety Program

Pending Fines

WV H 2304 Adds oil and gas facilities, wells, pipelines and tanks to the coordinated statewide program of air pollution prevention

Died Leak Mitigation & Repair

WV H 4152 Requires all operators of the underground facilities in this state to participate in the one-call system

Died Reporting

WV H 4258 Creates a source water protection program and an industrial above ground storage tank program to protect source water supplies and systems

Died Misc.

WV H 4382 Establishes the Legislative Oversight Commission on Energy Workers Safety Died Misc.

2014 Events A preliminary list of 2014 events can be found below. We will continue to update this list throughout the year as meetings

and events are added and/or changed.

May 2014

GOPAC Emerging Leaders Summit

May 12-15 | New York, NY

RGA Policy Summit

May 20-21 | New York, NY

RLCC Southern Regional Meeting

May 21-22 | The Cloister, Sea Island, GA

June 2014

NARUC: 2014 Western Conference

June 1-4 | Seattle, WA

NARUC: Mid-American Regulatory Commissioners (MARC) Meeting

June 1-4 | Indianapolis, IN

DGA Northeastern Policy Conference

June 3-4 | Stamford, CT

WGA Annual Meeting

June 9-11 | Colorado Springs, CO

NARUC: 2014 NECPUC Symposium

June 15-17 | Stowe, VT

CSG 2014 Leadership Forum

June 20-22 | Washington, DC

RAGA Summer National Meeting

June 21-24 | San Diego, CA

NARUC: MACRUC Annual Education Conference

June 22-25 | Hershey, PA

DGA Regional Policy Conference

June 24-25 | Chicago, IL

July 2014

NGA Summer Meeting

July 11-13 | Nashville, TN

CSG: Midwestern Legislative Conference Annual Meeting

July 13-16 | Omaha, NE

NARUC Summer Committee Meetings

July 13-16 | Dallas, TX

RLCC National Meeting

July 17-19 | The Broadmoor, Colorado Springs, CO

GOPAC State Legislative Leaders Summit

July 20-23 | Charlotte, NC

CSG: Southern Legislative Conference Annual Meeting

July 26-30 | Little Rock, AR

ALEC 41st Annual Meeting

July 30-Aug 1| Dallas, TX

August 2014

DGA Summer Policy Conference

August 1-3 | Aspen, CO

CSG: Eastern Regional Conference Annual Meeting

August 3-6 | Baltimore, MD

CSG National and CSG West Annual Meeting

August 9-13 | Anchorage, AK

NCSL Legislative Summit

August 19-22 | Minneapolis, MN

September 2014

NASEO 2014 Annual Meeting

September 8-11 | Savannah, GA

2014 ECOS Annual Meeting

September 15-17 | Santa Fe, NM

CSG: Natural Gas Policy Academy

September 25-27 | Denver, CO

RSLC Annual Retreat

September 28-30 | Amelia Island, FL

October 2014

AGA State Affairs Committee Meeting October 5-8 | Austin, TX

November 2014

RLCC Policy Retreat

Nov. 12-13 | Washington, DC

RAGA Fall National Meeting

November 15-18 | Miami, FL

NARUC 125th Annual Meeting

November 16-19 | San Francisco, CA

RGA Annual Meeting

November 19-21 | Boca Raton, FL

December 2014

NCSL Fall Forum

December 10-12| Washington, DC

Kyle Rogers | Vice President, Government Relations Ashley Duckman | Director, State Affairs

202.824.7218 | krogers@aga.org 202.824.7212 | asmith@aga.org

American Gas Association | 400 N. Capitol St., NW | Washington, DC 20001 | www.aga.org | www.truebluenaturalgas.org