RI Distributed Generation

Seminar

May 10, 2018

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9:00 a.m. Welcome Message, Introductions, Presentation Overview – John Kennedy

9:10 a.m. Interconnection Process – Pam Palumbo

9:45 a.m. DG Legislation Updates – John Kennedy

10:00 a.m. Portal Demo – Sean Diamond and Adam Markopoulos

10:45 a.m. Question and Answer Session

11:00 a.m. Conclude

Agenda

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Outdoor digging projects?

Call 811 first.

Thinking about putting in a fence, a pool or planting shrubs or trees?

The first thing to do is call 811 before your dig – it’s a free service. And it’s the law!!!

When you call 811, they’ll mark existing water lines, electric lines cables and natural gas line running underground.

When you make the free call to 811 a few days before you dig, you’ll help prevent unintended consequences such as injury to you or your family, damage to your property, utility service outages to the entire neighborhood and potential fines and repair costs.

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DG Activity Trends - NE

Received 3,413 interconnection applications representing about 868 MW

January 2018 – April 2018, compared to 2,976 applications / 346 MW in same

time period CY2017.

Small (<100kW) Interconnection application are triggering large studies because

of the aggregate generation on the circuit.

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DG Activity Trends - RI

Received 659 applications representing 273 MW January 2018 – April 2018

Compared to 787 applications representing 158 MW same time period CY2017

and 771 apps representing 44 MW same time period CY2016

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DG Activity Trends - RI

Interconnected 446 applications representing 8 MW January 2018 – April 2018

Compared to 494 applications representing 7 MW same time period in CY2017

and 304 applications representing 3 MW same time period CY2016

DG Activity Trends RI – Cancelled Applications

DG Interconnection Process

Pam Palumbo

Energy Integration Consultant

Customer Energy Integration

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ERV Basics

Distributed Generation

and the Electric Grid

Two Types of grid-connected DG:

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Behind Meter:

DG system partially or fully supplies an on-site load.

Unused electricity exported back to the distribution system

Direct Connect / Stand-alone:

DG system does not supply an on-site load

Is connected directly to the distribution system

RI PUC Interconnection

Tariffs

The most recent RI PUC Interconnection tariff is titled “RIPUC #2163, Standards for Connecting Distributed Generation”.

Includes interconnection standards and renewable energy interconnection process.

Current version of “Standards for Connecting Distributed Generation” can be found at:

http://www9.nationalgridus.com/non_html/RI_DG_Interconnection_Tariff.pdf

The RI PUC recently adopted a revised net metering tariff titled “RIPUC #2169, Net Metering Provision".

Includes Eligible Net Metering Rate Classes and Technologies

Current version of the “Net Metering Provision“ can be found at:

http://www9.nationalgridus.com/non_html/Net%20Metering%20Tarrif%202169.pdf

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Importance of the

Interconnection Process

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Safety of utility workers and general public

No adverse impact to power quality, in terms of:

Islanding

Transient Voltage Conditions

Noise and Harmonics

Frequency

Voltage Level

Machine Reactive Capability

Per tariff: customers cannot interconnect without an

interconnection agreement and approval. You proceed at your own

risk if you don’t have utility approval

Billing implications

Interconnection Process

Steps

Pre-Application

Simplified and Expedited Application

Standard Application

Impact Study and Detailed Study

Conditional Approval

Construction

Witness Test

Authorization to Interconnect

http://ngridustest/narragansett/home/energyeff/4_interconnection-process.asp

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Pre-Application Report

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Customer provides:

Contact and alternative contact Information

Facility Location (street address with cross

streets, including town, and a Google Map

still picture and GPS coordinates):

Generation type, size (AC kW), single or

three phase, service configuration:

Stand-alone (no on-site load, not including

parasitic load)?

If there is existing service at the Proposed

Facility site, provide: Interconnecting

Customer Account Number

Site minimum and maximum (if available)

current or proposed electric loads:

Is new service or service upgrade needed?

Utility provides:

Circuit voltage, circuit number

Whether single or three phase is

available near site; If single phase –

distance from three phase service;

Aggregate of connected Facilities (kW)

on circuit;

Aggregate of not yet connected (kW)

on circuit

Whether the Interconnecting Customer

is served by an area network, a spot

network, or radial system;

Identification of feeders within ¼ mile

Other potential system constraints or

critical items

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Everything starts with

the Application

A complete complex application package includes:

Complete application, signed and dated, with generator info

Pre-application (optional; required for projects over 500kW)

Application Fee ($3 / kW – $300 minimum, $2,500 maximum)

Standard Renewable DG: Feasibility fee in lieu of application fee

PE-Stamped 1-line diagram preferably showing relay controls

Site Diagram showing electric service location, generator location, AC Utility Disconnect, metering,

access to metering and disconnect, assessor’s plat map, survey plan. Google Earth shots are not

acceptable.

Supplemental Information including tech sheets, inverter islanding info, etc.

Schedule B if planning to Net Meter.

Site Control – proof of site control is required where applicable.

Documentation problems “stop the clock” (Reference ESB756 as a guide to avoid customer/contractor

holds in the process).

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Everything starts with

the Application: Site Plan A complete complex application package includes:

ESB 756D Section 5.1.1.3 Site Plan

A site plan shall be submitted showing the location of major customer equipment, the Company equipment to be

installed on site, and site details that will be helpful to define accessibility of the site. The site plan shall show the

following equipment at minimum:

1. Interfacing transformer

2. Interrupting devices

3. Isolation device(s) (e.g. Generator Disconnect)

4. Point of Common Coupling (PCC)

5. Company pole number nearest the proposed PCC

6. Company line extension to site and from nearest Point of Interconnection

7. Restricted accesses, fences, gates and access controls

8. Existing and proposed Access road(s) including, at a minimum, road material, surface loading criteria, and

dimensions to confirm Company personnel and equipment access requirements are met.

9. Generator location

10. Existing service(s) Site plans shall be to scale with approximate distances indicated. In addition to site plan, the

Company may request an assessor map to determine property lines, wetlands and easements.

Interconnection Review

Paths

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There are three different interconnection review paths a project can

follow based on generation type, size, customer load and the

characteristics of the grid where the system is to be located.

Simplified Review Path

Expedited Review Path

Standard Review Path

Non-Renewable DG

Renewable DG

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Simplified Review Path

Less than 15 kW single phase, or less than 25 kW three phase

Review Process Simplified Process

Acknowledge Receipt of

Application (3 days)

Review Application for

Completeness 10 days

Complete Review of All

Screens 10 days

Send Executable

Agreement (Note 4) Done

Total Maximum Days 20 days

Notice/ Witness Test < 1 day with 10 day notice

or by mutual agreement

Simplified Process

Application Fee (covers

screens) 0 (Note 1)

Supplemental Review or

Additional Review (if

applicable)

N/A

Standard Interconnection

Initial Review N/A

Feasibility Study N/A

Impact Study or ISRDG N/A

Detailed Study (if required) N/A

Facility Upgrades N/A (Note 5)

Witness Test 0

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Expedited Review Path Greater than 15 kW single phase, or greater than 25 kW three phase

Maximum size based on review of screens

Does not apply to non-listed inverters or other generators

Review Process Expedited Process

Acknowledge Receipt of

Application (3 days)

Review Application for

Completeness 10 days

Complete Review of All

Screens 25 days

Complete Supplemental

Review (if needed) 20 days

Send Executable

Agreement (Note 3) 10 days

Total Maximum Days 45/65 days (Note 4)

Notice/ Witness Test 1-2 days with 10 day notice

or by mutual agreement

Expedited Process

Application Fee (covers

screens)

$3/kW, minimum $300,

maximum $2500

Supplemental Review or

Additional Review (if

applicable)

Up to 10 engineering hours

at $125/hr ($1,250

maximum) (Note 2)

Standard Interconnection

Initial Review N/A

Feasibility Study N/A

Impact Study or ISRDG N/A

Detailed Study (if required) N/A

Facility Upgrades Actual Cost

O&M (Note 6) TBD

Witness Test Actual cost, up to $300

+ travel time (Note 7)

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Standard Review Path

Non-Renewable DG Non-listed inverters or other generators (induction, synchronous, asynchronous)

Most Combined Heat and Power (CHP) systems

Review Process Standard Process

Acknowledge Receipt of Application (3 days)

Review Application for Completeness 10 days

Complete Standard Process Initial

Review 20 days

Send Follow-on Studies

Cost/Agreement 5 days

Complete Impact Study or ISRDG (if

requested) 55 days

Complete Detailed Study (if requested) 30 days

Send Executable Agreement (Note 3) 15 days

Total Maximum Days 135/155 days

(Note 5)

Notice/ Witness Test By mutual

agreement

Standard Process

Application Fee (covers

screens)

$3/kW, minimum $300,

maximum $2500

Supplemental Review or

Additional Review (if

applicable)

N/A

Standard Interconnection

Initial Review

Included in application fee

(if applicable)

Feasibility Study N/A

Impact Study or ISRDG Actual Cost (Note 3)

Detailed Study (if required) Actual Cost (Note 3)

Facility Upgrades Actual Cost

O&M (Note 6) TBD

Witness Test Actual Cost

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Standard Review Path

Renewable DG Large-scale PV (500 kW or greater), large-scale wind turbines (500 kW or

greater), hydro facilities, anaerobic digestion, etc.

Review Process Standard Process

Acknowledge Receipt of Application (3 days)

Review Application for Completeness 10 days

Complete Standard Process Initial

Review

20 days if

feasibility study

not requested

Send Follow-on Studies

Cost/Agreements 5 days

Feasibility Study (if requested) 30 calendar days

Complete Impact Study or ISRDG (if

requested)

The shorter of 55

days or 90

calendar days

Complete Detailed Study (if requested) 30 days

Send Executable Agreement (Note 3) 15 days

Total Maximum Days Varies depending

on studies done

Notice/ Witness Test By mutual

agreement

Standard Process

Application Fee (covers

screens)

Feasibility Study Fee in lieu of

Application Fee

Feasibility Study Residential:

≤ 25 kW: $0, > 25 kW: $50

Non-residential:

≤100 kW: $100, ≤250 kW:

$300, 250 kW-1MW: $1,000,

> 1MW: $2,500

Impact Study or ISRDG Residential:

≤ 25 kW: $0, > 25 kW: $100

Non-residential:

≤100 kW: $500, ≤250 kW:

$1,000, 250 kW-1MW:

$5,000, > 1MW: $10,000

Detailed Study (if

required) Actual Cost (Note 3)

Facility Upgrades Actual Cost

O&M (Note 6) TBD

Witness Test Actual Cost

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Interconnection Process:

Summary and Recommendations

Submit your interconnection application with National Grid early, during

conception phase before committing to buy no matter how simple or small

the DG might be.

You can always request general utility information about a specific location

from your utility by requesting a Pre-application Report

Large interconnection applications take longer to study

The Interconnection Tariff is a wealth of information

Interconnection timeframes do not apply to Electric Power System

construction if required.

Time frames are standard working days and do not include delays due to

missing information or force majeure events

ISO-NE notification not included in time frame.

Interconnection applications have increased significantly in the past few

years – APPLY EARLY!

National Grid Contacts &

Tariff Links

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Director Kevin Kelly | (978) 725-1325

Managers - NE John Kennedy

(401) 784-7221

Will Kern

(781) 907-3023 Screening Team

Vishal Ahirrao

(781) 907-3002

MA Melissa Drury

508-897-5544

Andrea Agra

(781) 907-3040

Joshua Dibia

(516) 545-4778

Business Support Team

Jeffrey Crompton

(781) 907-1436

Jennifer Chalifoux

(978) 725-1029

Nicholae Gari

(781) 907-2018

Eric Munzert

(781) 907-3833

Ariella Cohen

(781) 907-1445

Andy Garsils

(516) 545-4682

Joseph Vuto

(781) 907-1435

John Gatti

(781) 907-3522

RI Patricia Matulaitis

(401) 267-6671

Bassey Iro

(781) 907-2522

Hannah Ferris

(401) 267-6619

Timothy Kounlavouth

(781) 907-3454

Brandon Lopes

(401) 267-6626

Sahir Shakir

(781) 907-3687

Evan Magno

tbd

Pamela Palumbo

(401) 267-6625

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DG Legislation Update Discussion

John Kennedy

Manager

Customer Energy Integration

DG Legislation Update Discussion

Interconnection Applications received as of July 1, 2017 will be included in the new timelines resulting from DG Legislation passed last year.

The revised Standards for Interconnecting Distributed Generation tariff is pending RI PUC approval.

Highlights:

An executable interconnection service agreement must be delivered to the interconnecting renewable energy customer within 175

calendar days of a completed application, or 200 calendar days if a detailed study is required.

The electric distribution company must complete all system modifications by the later of the following dates: (i) 270 calendar days, or

360 calendar days if substation work is necessary, from the date of the electric distribution company's receipt of the executed

interconnection service agreement, or (ii) the interconnecting renewable energy customer's agreed upon extension of the time between

the execution of the interconnection services agreement and interconnection as set forth in writing.

System modification deadlines may not be extended due to customer delays in providing required information. The electric distribution

company must request and obtain all information prior to completion of the impact study.

Deadlines for completed system modifications will only be extended for events not within the control of the electric distribution company,

and include the following: (i) extended prohibitive weather, (ii) union work stoppage or force majeure, or (iii) third party delays, including,

without limitation, delays due to ISO-NE requirements. Such events must not be attributable to electric distribution company actions, and

cannot be resolved despite commercially reasonable efforts.

The electric distribution company must notify the interconnecting renewable energy customer in writing of the start of any claimed

deadline extension “as soon as practicable,” its cause, and when it concludes.

If a court of competent jurisdiction orders the electric distribution company to pay damages to the interconnecting renewable energy

customer, such damages are limited to actual damages arising directly from the electric distribution company’s failure to comply with the

requirements of this subsection. Such damages will be paid by the shareholders and are not recoverable from customers.

The electric distribution company is not liable for indirect, incidental, special, consequential, or punitive damages of any kind whatsoever

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DG Legislation Update Discussion

Highlights continued:

Ways of Working Update

To serve the entire DG development community equitably, National Grid is required to efficiently facilitate the advancement of

interconnection applications through the interconnection process and adhere to the established timelines. This include s the cancellation

of applications that are not progressing in a timely manner.

DG Data Portal coming soon.

Customer Energy Integration “Job Owners” will now review applications for completeness as opposed to Screening Team members.

This allows them to be primary point of contact at the beginning of process and limit handoffs. Complete application packages are

required at time of application including proof of site control where applicable.

At time of application: complete application package is required – Google Earth shots are no longer accepted as site plan documents.

System Impact Study:

At day 50 of Impact Study a draft will be provided outlining any final customer requirements, e.g., one-line update, technical

information, site readiness information. These requirements must be completed prior to an Interconnection Service Agreement

being provided.

Once an Impact Study is delivered any changes to the Customer’s facility may result in a new interconnection application and

Impact Study being required along with associated fees.

Transmission Planning Studies

Transmission Planning Studies must be completed prior to Interconnection Service Agreements being provided. Agreements to

conduct the study will be provided once an Impact Study has reached the 20 business day mark.

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Break

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Rhode Island Application

Portal Demo

Sean Diamond - Process Excellence

and Adam Markopoulos - Customer Energy

Integration

Question and Answer

Contact for Follow-Up Questions:

Email: Distributed.Generation@nationalgrid.com

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Thank you for Participating!

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Other Information Resources

Commerce RI: http://www.commerceri.com

RI OER Website: http://www.energy.ri.gov/index.php

RI PUC Website: http://www.ripuc.org/utilityinfo/electric.html