THIS FILING LETTER DOES NOT CONTAIN ANY PRIVILEGED OR CONFIDENTIAL

INFORMATION. REPORT SECTIONS II AND III DO NOT CONTAIN ANY PRIVILEGED OR CONFIDENTIAL INFORMATION. THE BODY OF REPORT SECTION I AND
ATTACHMENT II, AND ATTACHMENTS V THROUGH VII DO NOT CONTAIN ANY PRIVILEGED OR CONFIDENTIAL INFORMATION. ATTACHMENT I, ATTACHMENT III AND ATTACHMENT IV CONTAIN PRIVILEGED AND CONFIDENTIAL
INFORMATION, AND ARE CLEARLY MARKED.

December 15, 2017

Kimberly D. Bose, Secretary

Federal Energy Regulatory Commission 888 First Street, N.E.

Washington, D.C. 20426

Re: Annual Report in Docket Nos. ER01-3001-000, ER03-647-000 and
Request for Privileged Treatment of Attachments I, III, and IV

Dear Ms. Bose:

Enclosed for filing in the above-referenced dockets is the New York Independent System

Operator, Inc.’s (“NYISO’s”) Annual Installed Capacity Report on the NYISO’s Capacity Market,

Possible Withholding, New Generation Projects, and Net Revenue Analysis (the “Report”).1 By Order dated February 3, 2010, the Commission directed the NYISO to file this report for informational
purposes only.2

I. List of Documents Submitted

The NYISO submits with this letter, and the below request for confidential treatment, a public version of the Report, with Attachments I, III, and IV redacted. Separately, the NYISO is submitting as confidential, Attachments I, III and IV (the “Confidential Attachments”).

As with prior annual Installed Capacity Reports, the Report is comprised of the following

separate sections: Section I: Capacity Market Report and Withholding Analysis, Section II: Report on New Generation Projects, and Section III: New Generation Projects and Net Revenue Analysis.

1 New York Indepen. Sys. Operator, Inc., 117 FERC ¶ 61,086 (2006); New York Indepen. Sys. Operator, Inc., 103 FERC ¶ 61,201 (2003), 108 FERC ¶ 61,280 (2004), 121 FERC ¶ 61,090 (2007), 123 FERC ¶ 61,206 (2008). In Docket ER03-647, the NYISO files an annual report regarding its Demand Side Management
programs on January 15, and a semi-annual report on its Demand Side Management programs and new
generation projects on June 15 each year.

2 New York Indepen. Sys. Operator, Inc., Order, Docket Nos. ER01-3001 and ER03-647 (Feb. 3, 2010).

II. Request for Confidential Treatment of Attachments I, III, and IV

In accordance with Sections 388.107 and 388.112 of the Commission’s Regulations,3 Article 6
of the NYISO’s Market Administration and Control Area Services Tariff, Sections 1.0(4) and 4.0 of
the NYISO’s Code of Conduct, the NYISO requests Privileged and Confidential treatment of the
contents of the Confidential Attachments. The NYISO also requests that the Confidential Attachments
be exempted from public disclosure under the Freedom of Information Act (“FOIA”), 5 U.S.C. §522.4

The Confidential Attachments contain privileged, commercially sensitive, and trade secret information that is not made public by the NYISO and that could cause competitive harm to the
affected Market Participants,5 and could adversely affect competition in the markets administered by the NYISO, if publicly disclosed. This information includes the identity of Installed Capacity
Suppliers and their respective offering behavior, and the basis therefor. This confidential,
commercially sensitive information is exempt from disclosure under 5 U.S.C. §522(b)(4). For this reason, the NYISO requests that the contents of Confidential Attachments receive Privileged and Confidential treatment and be exempt from FOIA disclosure.

A public version of the contents of Attachment I is set forth in Report Section 1.5.4.2. A public version of Confidential Attachment III, summarizing and masking the contents of Attachment III, is included in the Report as Attachment II. A masked and aggregated version of Confidential Attachment IV is set forth in Report Section 1.5.4.4.

The NYISO requests waiver of any obligation it may have under the Commission’s regulations
or the Secretary’s rules to submit a redacted version of the Confidential Attachments. The NYISO
incorporated into the body of Report Section I a masked or aggregated version of the information that
is contained in the Confidential Attachments and thereby makes publicly available the information
contained in Attachment III that is not confidential and commercially sensitive. In that regard, the
NYISO has provided a redacted version of the information contained in the Confidential Attachments.

The Confidential Attachments are identified and marked in accordance with the Commission’s regulations and rules published by the Secretary’s Office for submitting Privileged information.

3 18 C.F.R. §§ 388.107, 388.112.

4 The information provided by the NYISO for which the NYISO claims an exemption from FOIA disclosure is labeled “Contains Privileged Information - Do Not Release.”

5 Terms with initial capitalization not defined herein have the meaning set forth in the NYISO’s Market Administration and Control Area Services Tariff.

Contents

I. Capacity Market Report.........................................................3

I.2 Overview...................................................................3

I.3 Market Design and Regulatory Developments........................................7

I.3.1. Buyer-Side Mitigation Enhancements.............................................7

I.3.2. Revisions to Pivotal Supplier Rules..............................................7

I.3.3 Annual Updates for the ICAP Demand Curves.......................................7

I.3.4 Locality Exchange Factor......................................................8

I.4. Recent Installed Capacity Auction Results...........................................9

I.5 Capacity Withholding Analysis...................................................21

I.5.1 All Capacity Areas in the NYCA................................................21

I.5.2 Unoffered and Unsold Capacity................................................23

I.5.3 New York City and G-J Localities...............................................26

I.5.4 Rest of State..............................................................30

I.5.4.1 Overview...............................................................30

I.5.4.2 Analysis of ROS Unoffered Capacity...........................................32

I.5.4.3 Analysis of ROS Unsold Capacity..............................................33

I.5.4.4 Monthly Price Impacts......................................................34

II. NYISO Report on New Generation Projects..........................................38

III. New Generation Projects and Net Revenue Analysis..................................39

III.1 Overview.................................................................39

III.2 Market Design Developments to Enhance ICAP Demand Curve Performance...............39

III.3 Interconnection Queue Projects.................................................39

III.4 Proposed Resource Additions..................................................41

III.5 Net Revenue Analysis........................................................44

III.5.1 Quantification of “Need”.....................................................44

Attachments

Attachment I: Confidential. Unoffered Capacity: Market Participant Explanations Attachment II: Unsold Capacity Offers (Masked)

Attachment III: Confidential. Unsold Capacity Offers (Unmasked)

Attachment IV: Confidential. Unsold Capacity Offers: Market Participant Explanations Attachment V: Interconnection Queue

Attachment VI: Status Key for Interconnection Queue

Attachment VII: November 1999 - October 2016 Installed Capacity Auction Activity

2017 Annual Installed Capacity Report |December 15, 2017| I

Tables

Table 1: List of Mothballed and Retired Units..........................................18

Table 2: Minimum Installed Capacity Requirements (%)...................................25

Table 3: Unoffered and Unsold MW.................................................26

Table 4: ROS Unoffered and Unsold Capacity MW by Type of Market Participant................31

Table 5: Maximum Price Impact of ROS Unoffered Capacity (15MW+)........................33

Table 6: Maximum Price Impact of ROS Unsold MW.....................................34

Table 7: Going Forward Cost Definitions..............................................35

Table 8: ROS Unsold MW with reported GFCs costs above ICAP Monthly Auction Prices (15MW+)...35

Table 9: ROS ICAP Spot Auction Price Impact Analysis Results.............................36

Table 10: Capacity Resource Changes since the publication of the 2017 NYISO Gold Book........42

Table 11: Current Status of Tracked Market-Based Solutions and Transmission Owner Plans.......43

Table 12: Summer Available Capacity vs. Required Capacity...............................45

Table 13: Annual Revenue Requirements in UCAP terms ($/MW)...........................46

Table 14: Benchmark Annual Revenues in UCAP terms ($/MW)............................47

Table 15: Revenue Margins.......................................................47

Charts

Chart 1: UCAP Available Reserve and Spot Market Clearing Prices...........................5

Chart 2: NYCA Market Clearing Prices...............................................10

Chart 3: NYCA Offered MW.......................................................11

Chart 4: NYC Market Clearing Prices................................................12

Chart 5: NYC Offered MW........................................................13

Chart 6: G-J Locality Market Clearing Prices...........................................14

Chart 7: G-J Locality Offered MW...................................................15

Chart 8: Long Island Market Clearing Prices...........................................16

Chart 9: Long Island Offered MW...................................................17

Chart 10: Average Percent of Unoffered MW...........................................23

Chart 11: Average Percent of Unsold MW.............................................24

Chart 12: NYC Mitigation Results...................................................28

Chart 13: NYC Generator and SCR UCAP............................................28

Chart 14: G-J Locality Mitigation Results..............................................29

Chart 15: G-J Locality Generator and SCR UCAP.......................................29

Chart 16: Rest of State Capacity Available, Offered, Sold and Exported.......................30

Chart 17: NYISO Interconnection Queue Projects.......................................40

Chart 18: UCAP based Revenue Margins.............................................48

Chart 19: UCAP based Capacity Margins.............................................49

Chart 20: Capacity Market Revenues Relative to CONE Requirements........................49

2017 Annual Installed Capacity Report |December 15, 2017| II

I. Capacity Market Report I.2 Overview

This report (the “December 2017 Report”) reviews the outcomes of the Installed

Capacity (“ICAP”) market administered by the New York Independent System Operator

(“NYISO”); assesses the effectiveness of the ICAP Demand Curves1 (“Demand Curves”) in

attracting investment in new and existing capacity resources; and examines potential

withholding activity in the NYISO-administered Capacity auctions for the New York Control Area
(“NYCA”) within its three Localities, New York City (“NYC”), the G-J Locality (“G-J”), and Long
Island (“LI”), and the remaining area that comprises the NYCA, the Rest of State (“ROS”)
(referred to in this report as “capacity areas”).2 The December 2017 Report covers the Winter
2016-2017 and Summer 2017 Capability Periods, which span from November 2016 through
October 2017. Similar NYISO reports filed in previous years cover earlier periods.

With the exception of the G-J Locality capacity prices, during the Winter 2016-2017

Capability Period capacity prices were lower, on average, than those of the previous Winter

Capability Period. The average ICAP Spot Market Auction (“Spot Market Auction”) prices over the Winter 2016-2017 Capability Period were $0.47/kW-month, $3.48/kW-month, $3.48/kW-
month, and $0.47/kW-month, for NYCA, the G-J Locality, NYC, and LI, respectively. These prices compare with $0.95/kW-month, $3.24/kW-month, $5.97/kW-month and $1.65/kW-month during the previous winter for NYCA, the G-J Locality, NYC, and LI respectively.

Capacity prices during the Summer 2017 Capability Period in NYC and NYCA were

lower on average than those of the previous (2016) Summer Capability Period. The average

Spot Market Auction prices in NYC were $10.04/kW-month compared to $12.24/kW-month, and were $2.35/kW-month compared to $4.09/kW-month for NYCA. The average Spot Market
Auction prices over the Summer 2017 Capability Period were higher for G-J and the LI Locality, i.e., $9.85/kW-month and $6.66/kW-month compared to $9.24/kW-month and $4.63/kW-month respectively during the previous Summer Capability Period.

The average Spot Market Auction prices for Summer 2017 were lower than the Summer 2016 average by $1.74/kW-month in NYCA; by $2.20/kW-month in NYC; and higher by
$0.61/kW-month in the G-J Locality; and by $2.03/kW-month in LI. These price changes were driven primarily by changes in the respective Locational Minimum Installed Capacity
Requirements (“LCRs”), as well as by the changes in available capacity compared to the load forecast throughout NYCA. These dynamics are depicted in Table 1.

1 Terms in upper case not defined herein shall have the meaning set forth in the NYISO’s Market Administration and Control Area Services Tariff (“Services Tariff”), with the exception of Rest of State
(“ROS”) when such term refers to a period before the Summer 2014 Capability Period. Consistent with the Services Tariff revision to establish the G-J Locality beginning with the Summer 2014 Capability
Period and change the definition of Rest of State accordingly, when ROS refers to Winter 2013-2014 or a prior period, it means Load Zones A through I. Any other terms not so defined have the meaning set forth in the Open Access Transmission Tariff (“OATT”).

2 The NYISO’s Capacity auctions have four Market-Clearing Prices: NYCA, New York City, Long Island and the G-J Locality.

2017 Annual Installed Capacity Report |December 15 2017|3

For the Winter 2016-2017 and Summer 2017 Capability Periods, there was minimal

change in the proportion of Load Serving Entity (“LSE”) Unforced Capacity (“UCAP”)

requirements met through purchases in the NYISO-administered capacity auctions versus

bilateral transactions when compared to previous Capability Periods. In the Winter 2016-2017 Capability Period, 34.78% of LSE Capacity requirements were met through bilateral
transactions (35.71% in the previous Winter Capability Period), while the remaining percent of LSE requirements were met through purchases in the NYISO-administered auctions. Similarly, in the Summer 2017 Capability Period, 39.16% of LSE capability requirements were met
through bilateral transactions (36.38% in Summer 2016), while the remaining LSE requirements were satisfied through purchases made in the NYISO-administered auctions.

The seasonal average quantities of unoffered capacity constituted less than 0.7% of

available supply in the NYC, LI, and the G-J Locality (see Chart 10). The seasonal average

quantities of unsold capacity (i.e., capacity that was offered but went unsold) was below 1% for
each of the three Localities (see Chart 11).3 Total unsold and unoffered capacity quantities from
ROS resources were at or below 1% in the Winter 2016-2017, and at or below 0.5% in Summer
2017. The UCAP offered and purchased in NYCA and each of the three Localities exceeded
the LCRs; therefore, prices were below the base reference point on the respective ICAP
Demand Curves.

Overall, the Market-Clearing Prices in the ICAP Spot Market Auctions support the

conclusion that the ICAP Spot Market Auctions continue to be attractive to Installed Capacity
Suppliers. Previously the NYISO stated that it is difficult to correlate the effect of the ICAP
Demand Curves on the level of investment in the NYCA, partially because in the past NYC has
had capacity in excess of the LCR, and partially due to the lead-time required to site, develop,
and construct a new generator. The ICAP Demand Curves provide transparent capacity market
price signals that developers consider in their projections of anticipated future revenues when
making near-term investment decisions. Capacity market outcomes are reviewed to ensure
market signals are aligned with reliability needs. When market changes are identified, the
NYISO works with its stakeholders on prioritizing the need for and developing a suitable market
rules.

The NYISO continues to monitor potential reliability risks and other issues that may
affect the reliability outlook for New York’s bulk electric system. On October 18, 2016, the
NYISO Board of Directors approved the 2016 Reliability Needs Assessment (“RNA”) Report
(“2016 RNA Report”),4 which is the first step in preparing the 2016 Comprehensive Reliability
Plan. The 2016 RNA Report’s key findings identified two transmission security needs in portion
of the Bulk Power Transmission Facilities beginning in 2017. On April 11, 2017issued the
Comprehensive Reliability Plan Final Report (“CRP”).5 The CRP concluded that the Bulk

3 Section I.5.2 of this report provides information and analysis of the unoffered and unsold
capacity.

4 The 2016 RNA Report is available at:

<http://www.nyiso.com/public/webdocs/media_room/press_releases/2016/Child_2016_RNA/2016RNA_Fi
nal_Oct18_2016.pdf>.

5 See New York Independent System Operator, “2016 Comprehensive Reliability Plan issued on April 11, 2017, available at:

<http://www.nyiso.com/public/webdocs/markets_operations/services/planning/Planning_Studies/Reliabilit
y_Planning_Studies/Reliability_Assessment_Documents/2016CRP_Report_Final_Apr11_2017.pdf>.

2017 Annual Installed Capacity Report |December 15 2017|4

I.3 Market Design and Regulatory Developments

Over the past year there have been several ICAP market design initiatives and

regulatory developments pertaining to the NYISO’s Installed Capacity market. The significant developments are described below.

I.3.1. Buyer-Side Mitigation Enhancements

On July 14, 2017, NYISO filed proposed Services Tariff revisions to include: (i)

enhancements to the rules governing the forecasts determined and used by the NYISO in the
course of making determinations under the Buyer-Side Mitigation (“BSM”) Rules; and (ii)
improvements to rules governing the use of escalation factors and inflation rates under the BSM
Rules. Federal Energy Regulatory Commission (“FERC”) accepted the revisions on September
11, 2017.

I.3.2. Revisions to Pivotal Supplier Rules

On February 6, 2017, NYISO filed revisions to the Services Tariff to apply across all

Mitigated Capacity Zones uniform rule by which a “Pivotal Supplier” can rebut the presumption
of control of unforced capacity. Under the revisions, Control of Unforced Capacity will no longer
be rebuttable in Zone J through forward capacity sales, such as sales in Strip or Monthly
auctions. These revisions are necessary to eliminate incongruities in the rebuttal standard
between Mitigated Capacity Zones and that, in so doing, all suppliers will be treated the same,
irrespective of the Mitigated Capacity Zone in which they are selling. FERC accepted revisions,
effective April 7, 2017.

I.3.3 Annual Updates for the ICAP Demand Curves

FERC accepted proposed revisions to the NYISO’s rules to move from a triennial ICAP Demand Curve reset to a quadrennial reset period with annual updates. The ICAP Demand
Curves will be updated formulaically for each of the remaining three years of each reset period. The three components of the ICAP Demand Curve input parameters that will be updated
annually are the (i) winter-to-summer ratio, (ii) gross cost of new entry for peaking plants using
an escalation factor, and iii) Net Energy and Ancillary Services revenue offset. The updates to the winter-to-summer ratio and the Energy and Ancillary Services revenue will be based on
rolling three years of data. On November 2, 2017, the NYISO posted the first annual update for each of the ICAP Demand Curves. The tariff provision for a collar was triggered for the New
York City and Long Island Demand Curves.

2017 Annual Installed Capacity Report |December 15 2017|7

I.3.4 Locality Exchange Factor

On November 30, 2016, NYISO filed revisions to its Services Tariff to correct a pricing inefficiency that could arise in the event of capacity exports from certain Localities in the NYCA. The methodology recognizes that an exporting generator continues to operate within its Locality, which would be reflected in the ICAP Spot Market Auction clearing prices by accounting for the portion of exported capacity that can be replaced by capacity located in Rest of State. FERC accepted the revisions, effective January 29, 2017.

2017 Annual Installed Capacity Report |December 15 2017|8

I.4. Recent Installed Capacity Auction Results

Capacity committed through self-supply, bilateral transactions, and the NYISO-

administered auctions (referred to herein as “committed” capacity) remains above the NYCA
Minimum Installed Capacity Requirement and above each Locality’s LCRs. In general, the
amount of capacity available from many generators in the NYCA increases in the Winter
Capability Period because of higher possible output at lower ambient temperatures. Capacity
imports from External Control Areas fluctuate both seasonally and monthly. The NYCA
Demand Curve price can decline to zero when supply exceeds the NYCA Minimum Installed
Capacity Requirement by 12 percent or more. Accordingly, the NYCA Market-Clearing Prices
have been consistently at or above ten percent of the NYCA ICAP Demand Curve reference
price6, particularly in the Winter Capability Period when prices were consistently below $1/kW-
month on average.

The amount of Capacity committed to the NYCA, including imports, continues to be high relative to the minimum requirements established with the Installed Reserve Margin of 18
percent. The monthly average import levels into the entire NYCA were about 2,440 MW in the Winter 2016-2017 Capability Period and about 3,070 MW in the Summer 2017 Capability
Period. Those values represent approximately a 460 MW increase in the monthly average over the amount imported in the previous Winter Capability Period and a 390 MW monthly average increase relative to the 2016 Summer Capability Period.

ICAP Market-Clearing Prices and auction activity levels from November 1999 through October 2017 for the NYCA, G-J Locality, NYC, and LI are summarized in tabular form in
Attachment VII. Market-Clearing Prices are depicted graphically in Chart 2, Chart 4, Chart 6 and Chart 8; and the amount of capacity committed, MW that were offered, and unsold MW are depicted in Chart 37, Chart 5, Chart 78, and Chart 9.

6 The reference price when the ICAP Demand Curve is translated to UCAP.

7 Previous years’ Reports presented only ROS unsold data in Chart 3. This year’s Report presents in Chart 3 the NYCA-wide unsold data.

8 The previous year’s Report presented only Load Zone G, H and I unsold data in Chart 5. This year’s Report presents in Chart 5 the Zones G, H, I, and J unsold data.

2017 Annual Installed Capacity Report |December 15 2017|9

Organization NameUnit NameZoneMW1Status2Period

TC Ravenswood, LLCTC Ravenswood GT 3-3J37.70MSummer 2014

TC Ravenswood, LLCTC Ravenswood GT 3-4J35.80RSummer 2011

TC Ravenswood, LLCTC Ravenswood GT 3-4J(38.60)RTSSummer 2014

TC Ravenswood, LLCTC Ravenswood GT05J15.70MOSummer 2016

TC Ravenswood, LLCTC Ravenswood GT06J16.70MOSummer 2016

TC Ravenswood, LLCTC Ravenswood GT07J16.50MWinter 2013-2014

AES Eastern Energy LPWestover Unit 8C83.80MWinter 2010-2011

AES ES Westover LLCWestover LESRC0.00RSummer 2013

Helix Ravenswood, LLCRavenswood GT09J16.30IIFOWinter 2017-2018

Notes to Table 1:

Note 1: The capacity values listed are the CRIS MW values stated in the NYISO’s Load and Capacity Data Report
(referred to as the “Gold Book”).

Note 2: “IIFO” means ICAP Ineligible Forced Outage, “R” indicates “retired” (including “Retired,) “M” indicates

“mothballed”, MO means “Mothball Outage”, and “RTS” indicates returned to service after being M, MO, or

R. RTS” Changes in status of generators that were IIFO and subsequently changed their status are indicated on this table. Services Tariff provisions defining the terms ICAP Ineligible Force Outage, Mothball, and Retire apply to outages pursuant to the rules effective May 1, 2015.

Note 3: Helios Power Capital, LLC, et al., Joint Petition for Expedited Approval for the Lease, Sale and Operation of
the Danskammer Generating Facility Under Lightened Regulation and for Related Relief, PSC Case No. 14-
E-0117 (Jun. 27, 2014).

2017 Annual Installed Capacity Report |December 15, 2017|20

I.5 Capacity Withholding Analysis

I.5.1 All Capacity Areas in the NYCA

This section of the report addresses potential withholding issues in the NYISO-

administered capacity auctions for all four capacity areas during the period of November 2016 to
October 2017: ROS, NYC, the G-J Locality, and LI. For purposes of this report, in order to
identify whether any potential withholding occurred, the NYISO analyzed the differences
between available capacity9 and the supply committed through self-supply, bilateral
transactions, and the NYISO-administered auctions. In particular, the NYISO examined:

 The NYCA capacity that was available to be offered into the ICAP Spot Market Auctions,
but was not offered (“unoffered capacity”),

 Available NYCA capacity that was offered into the ICAP Spot Market Auctions but was
not sold (“unsold capacity”),

 Unoffered capacity as a percentage of available capacity, and  Unsold capacity as a percentage of offered capacity.

When capacity is available but not offered, it is an indication that physical withholding

may have occurred. Similarly, if available capacity is offered at a price that causes it to not

clear, it is an indication of possible economic withholding. The amounts of unoffered and unsold
capacity are determined from the ICAP Spot Market Auction results because this auction is the
last opportunity for an Installed Capacity Supplier to sell its capacity. The existence of unoffered
and unsold capacity, however, does not necessarily imply the intent to manipulate market
prices.

As reflected in the NYISO’s previous reports on the Installed Capacity Demand Curves,
patterns of unsold capacity have varied across the three Localities and the NYCA. For the
entire NYCA there generally has been more unsold capacity in Winter months than Summer
months, due in part to lower prices in the Winter months. The monthly average of unsold MW
for the Winter 2016-2017 Capability period in relation to the Winter 2015-2016 Capability Period
was as follows: NYC 51 MW compared to 2 MW, G-J Locality 31 MW compared to 2 MW, Long
Island 4 MW compared to 1 MW, and NYCA-wide 227 MW compared to 187 MW. The
seasonal monthly average amount of unsold MW for the Summer 2017 Capability Period for all
of the NYCA was zero MW, while it was near zero (0.46) MW in the Summer 2016 Capability
Period.

In Long Island, there was a monthly average of 4 MW of unsold capacity in the Winter 2016-2017 Capability Period, compared to near 1 MW in the Winter 2015-2016 Capability Period; and 0 MW in the Summer 2017 Capability Period compared to near 1 MW in the
Summer 2016 Capability Period.

In NYC, there was a monthly average of 51 MW of unsold capacity in the Winter 2016-
2017 Capability Period, compared to 2 MW in the Winter 2015-2016 Capability Period; and 0

9 Available capacity is defined as the lesser of the NYISO-accepted DMNC and the Capacity

Resource Interconnection Service (“CRIS”) MW value, with the Equivalent Demand Forced Outage Rates (“EFORd”) reduction applied.

2017 Annual Installed Capacity Report |December 15, 2017|21

MW in the Summer 2017 Capability Period compared to near 0 MW in the Summer 2016 Capability Period.

In the G-J Locality, there was a monthly average of 31 MW of unsold capacity in the
Winter 2016-2017 Capability Period, compared to 2 MW in the Winter 2015-2016 Capability
Period; and 0 MW in the Summer 2017 Capability Period compared to near 0 MW in the
Summer 2016 Capability Period. The increase in unsold capacity in NYC and the G-J Locality
from the prior Capability Year is due in part to offers from particular resources that cleared in
prior years but did not clear in Winter 2016-2017 due to lower Spot Market Auction clearing
prices.

There are three types of capacity auctions in each Capability Period: a Capability Period
Auction (also referred to as the “strip auction”), six Monthly Auctions, and six ICAP Spot Market
Auctions. Available capacity may be offered into any or all of the auctions. There are three
distinct minimum ICAP requirements: one each for the NYC, G-J, and LI Localities, as well as
one for the NYCA as a whole. LSEs with Load in NYC, G-J, or LI Localities are required to
procure minimum levels of capacity that is electrically located within the respective Locality - the
“LCRs” in terms of Unforced Capacity, i.e., the Locational Minimum Unforced Capacity
Requirement. Such capacity is also credited toward each NYC and Long Island LSE’s overall
NYCA obligation. The NYISO establishes the NYCA Minimum Installed Capacity Requirement
and the LCRs annually.

The Services Tariff does not require Installed Capacity Suppliers to offer UCAP into the
ICAP markets except for certain suppliers in Mitigated Capacity Zones (i.e., NYC and the G-J
Locality). Until the implementation of the ICAP market power mitigation measures set forth in
Attachment H of the Services Tariff, which were effectuated in May 2008, the majority of
capacity in NYC - that of the “Divested Generation Owners” - had been subject to Commission-
approved ICAP mitigation measures that imposed bid caps and required the units’ capacity to
be offered into the ICAP auctions. The Commission’s March 7, 2008 Order10 removed the
requirements unique to the Divested Generation Owners and approved mitigation measures
applicable to all In-City capacity. The March 7, 2008 Order effectuated new In-City mitigation
measures, based on Pivotal Supplier determinations combined with offering conduct and price
impact thresholds, to determine whether market power had been exercised. ICAP market
power mitigation measures became effective for the G-J Locality concurrent with its
implementation. These measures for NYC and G-J Locality are set forth in Section 23.4.5
(Attachment H) of the Services Tariff (as revised over time, “Supply-side Mitigation Measures”).

In developing the information for this report, the NYISO examined auction outcomes of the Capability Periods from Summer 2007, which began May 1, 2007, through Summer 2017, which ended October 31, 2017. Since the capacity product transacted in the NYISO-
administered ICAP auctions is UCAP, the following information was examined:

 Certification data, reflecting the certified MW of UCAP from all the Resources physically
located within New York available to supply capacity to the NYCA. The analysis did not
include resources physically located outside of the NYCA.

10 See New York Independent System Operator, Inc., Docket No. EL07-39-000, Order Conditionally Approving Proposal, 122 FERC ¶ 61,211 (2008).

2017 Annual Installed Capacity Report |December 15, 2017|22

 Certification data, reflecting the certified MW of UCAP from all the Resources within the
G-J Locality (Load Zones G, H, I, and J) available to supply capacity to the NYCA. The
analysis did not include resources physically located outside of the NYCA.

 The amount of UCAP supplied, which includes UCAP sold in any of the NYISO ICAP

auctions, UCAP certified as self-supplied against an LSE’s Unforced Capacity obligation, and UCAP committed through bilateral transactions.

I.5.2 Unoffered and Unsold Capacity

Chart 10 presents seasonal averages of unoffered capacity as a percentage of available Capacity for each of the three capacity areas.

Chart 10: Average Percent of Unoffered MW

The Long Island Locality has fairly consistent seasonal fluctuations in the amounts of
unoffered capacity, which can be seen in Chart 10. The LI Locality is characterized by
procurement chiefly through bilateral transactions and self-supply. The amount of unoffered
capacity in the LI Locality fluctuates between 0.02% and 2.3%. A portion of that unoffered
capacity is not actually available due, in some instances, to site permit restrictions. Another
portion arises from purchases due to bidders for NYCA capacity (i.e., not requiring capacity
located in Long Island) in the Capability Period and Monthly Auctions.11 The NYISO has
observed that these NYCA bidders sometimes fail to offer the Long Island capacity in the ICAP
Spot Market Auction.

11 When the Market Clearing Price in these auctions is the same for NYCA and Long Island capacity, offers of capacity located in the Long Island Locality is used to meet NYCA bids.

2017 Annual Installed Capacity Report |December 15, 2017|23

In the NYC Locality, prior to the Summer 2008 Capability Period, the low level of

unoffered capacity was principally due to the offer requirement applicable to the Divested

Generation Owners. Beginning with the Summer 2008 Capability Period, the near absence of

unoffered capacity can be attributed to the Supply-side Mitigation Measures effectuated in 2008.

The G-J Locality became effective beginning in May 2014. Initially, the level of unoffered capacity was at the level of that in ROS, but fell to near zero.

In ROS the unoffered MW for the Winter 2016-2017 and Summer 2017 Capability Periods was consistently below 0.5%.12

Chart 11 displays unsold capacity as a percent of available UCAP in each of the four capacity areas, which has been below 1% for the past nine Capability Periods.13

Chart 11: Average Percent of Unsold MW

For all Capability Periods beginning with the Summer 2007 Capability Period, nearly all
Long Island offered capacity was sold. In NYC, the average amount of unsold capacity as a
percentage of available capacity trended at near zero levels from the start of the Summer 2008
Capability Period, except for the Winter 2011-2012, and Winter 2012-2013 Capability Periods
when some offered capacity did not clear because it was offered at a price greater than the
UCAP Offer Reference Level. The UCAP Offer Reference Level is the price at which the ICAP
Spot Market Auction would clear if all available capacity was offered and sold. For the Winter

12 As noted in n. 1, the definition of Rest of State prior to the Summer 2014 Capability Period was
Load Zones A though I, and beginning with the Summer 2014 Capability Period is Load Zones A through

13 Section I.5.4.3 of this report provides information and analysis of the unsold capacity in ROS.

2017 Annual Installed Capacity Report |December 15, 2017|24

2016-2017 and Summer 2017 Capability Periods, nearly all of the capacity offered in NYC

auctions was sold. The G-J Locality had less than 0.5% unsold MW in the 2016-2017 Capability Year. The increase in unsold capacity in NYC and the G-J Locality from the prior Capability
Year is due in part to offers from particular resources that cleared in prior years but did not clear in Winter 2016-2017 due to lower Spot Market clearing prices.

The NYCA Minimum Installed Capacity Requirement and LCRs increased for each capacity area since last Capability Year. .

Table 2 summarizes these values for NYC, G-J, LI, and the NYCA over the past eleven

years.

Table 2: Minimum Installed Capacity Requirements (%)14

Capability YearNYCG-JLINYCA

2007/200880-99116.5

2008/200980-94115

2009/201080-97.5116.5

2010/2011 (May)80-102118

2010/2011 (June-April)80-104.5118

2011/201281-101.5115.5

2012/201383-99116

2013/201486-105117

2014/20158588107117

2015/201683.590.5103.5117

2016/201780.590102.5117.5

2017/201881.591.5103.5118

Table 3 displays the breakdown of unsold capacity for each Locality and NYCA. These
unsold MW were not cleared in the NYC, G-J, LI, or NYCA spot auctions. As part of the
NYISO’s August 24, 2010 ICAP compliance filing,15 the NYISO stated that it would include
unoffered and unsold capacity in the NYC Locality in its annual Installed Capacity Demand
Curves reports. Table 3 also displays the unoffered capacity values for MWs that came from
NYC, GHI, LI, and ROS to give a full representation of the data that underlies this report.

Beginning with November 2016, the amount of unoffered MW stayed very low in NYC,

LI, and G-J Locality, totaling 256 MW in the Winter 2016-2017 and 57 MW in the Summer 2017.

14 The New York State Reliability Council issues an annual IRM Study Report, which presents the lowest feasible amount of capacity for the NYCA. Each report includes a comparison of the IRM and LCR values to the previous year along with an explanation of each parameter that contributed to the changes. The NYISO determines the actual LCRs for each Locality taking into consideration changes that have occurred since the Reliability Council approved the IRM Study Report. The 2016 IRM Study Report
covering the period of May 2017 through April 2018 is available at:

˂http://www.nysrc.org/NYSRC_NYCA_ICR_Reports.html˃.

15 See New York Independent System Operator, Inc., Resubmittal of August 24, 2010 Filing, Docket Nos. ER10-2210-000, EL07-39-000, and ER08-695-0004 at p. 16.

2017 Annual Installed Capacity Report |December 15, 2017|25

The total amount of unsold MW in NYC, G-J and LI was 137.6 MW in the Winter 2016-2017, and zero MW in the Summer 2017.

Section I.5.4.2 discusses explanations provided by Market Participants for unoffered MW in ROS in Winter 2016-2017. There was no unsold MW in ROS in the Summer 2017. Section I.5.4.3 presents the Market Participant explanations for and an analysis of unsold MW in ROS in the Winter 2016-2017.

Table 3: Unoffered and Unsold MW

UnofferedUnsold

MonthNYCGHILIROSNYCG-JLINYCA

Nov-1617.32.228.194.340.430.84.20408.80

Dec-165.48.119.182.152.430.84.2251.8

Jan-174.83.519.3150.252.430.88.3221.9

Feb-174.80.126.297.357.330.84.175.9

Mar-173.7464.799.252.430.81.1180.8

Apr-1713.31.430.4177.352.430.83.8224.6

May-174.60.20101.60000

Jun-172.10.50118.30000

Jul-171.10.70.735.20000

Aug-171.21.50930000

Sep-1736.50.3167.80000

Oct-175.30.51.137.50000

I.5.3 New York City and G-J Localities

To administer the Supply-side Mitigation Measures, the NYISO identifies Pivotal

Suppliers by examining the NYC UCAP and G-J Locality UCAP that each ICAP Supplier, along
with its Affiliated Entities, Controls in excess of the pivotal control threshold.16 The UCAP under
the Control of Pivotal Suppliers (“Mitigated UCAP”) must be offered into the ICAP Spot Market
Auction at a price at or below the lesser of the UCAP Offer Reference Level or the ICAP
Supplier’s Going-Forward Costs determined by the NYISO (“GFCs”). Chart 12 and Chart 14
illustrate the effects of the Supply-side Mitigation Measures. The UCAP Offer Reference Level,
as shown in these Charts, becomes the price cap that the Pivotal Supplier must offer at or
below in the ICAP Spot Market Auction, unless the Pivotal Supplier’s GFCs are higher.

The level of unoffered and unsold MW can be inferred from Chart 12 and Chart 14 by
comparing the Locality Spot Market Auction price to the UCAP Offer Reference Level, while
Chart 13 and Chart 15 depict the levels of available generator and SCR UCAP in the Locality.
The difference between the ICAP Spot Market Auction clearing price and UCAP Offer
Reference Level can be attributed to Locality capacity that is either not offered or is offered at a
price above the UCAP Offer Reference Level. Note that the Locality Spot Market Auction price
will diverge from the UCAP Offer Reference Level when the NYCA ICAP Spot Market Auction

16 See Market Services Tariff Sections 23.2.1 and 23.4.5.

2017 Annual Installed Capacity Report |December 15, 2017|26

sets the Locality ICAP Spot Market Auction price.17 This divergence is the result of the auction rules, and is not caused by unoffered or unsold Locality Capacity.

17 In the 2015/2016 Capability Year, the NYCA ICAP price set the Long Island ICAP price in May 2016 and June 2016.

2017 Annual Installed Capacity Report |December 15, 2017|27

Chart 12: NYC Mitigation Results18

$202,000

$181,800

$161,600

$141,400

$121,200

$101,000

$8800

$6600

$4400

$2200

$-0

NYC Spot Auction PriceUCAP Offer Reference LevelPivotal Control Threshold

Chart 13: NYC Generator and SCR UCAP

11,000600

10,500

500

10,000

400

9,500

9,000300

8,500

200

8,000

100

7,500

7,0000

NYC Generator UCAPNYC SCR UCAP

18 Per Services Tariff Section 23.2, a “Pivotal Supplier” in NYC needs to control at least 500 MW of Unforced Capacity, and a specified portion of the capacity necessary to meet the NYC LCR in an ICAP Spot Market Auction.

2017 Annual Installed Capacity Report |December 15, 2017|28

Chart 14: G-J Locality Mitigation Results19

$202,000

$181,800

$161,600

$141,400

$121,200

$101,000

$8800

$6600

$4400

$2200

$-0

G-J Locality Spot Auction PriceUCAP Offer Reference LevelPivotal Control Threshold

Chart 15: G-J Locality Generator and SCR UCAP

16,000600

15,000

500

14,000

13,000400

12,000

300

11,000

10,000200

9,000

100

8,000

7,0000

G-J Locality Generator UCAPG-J Locality SCR UCAP

19 Per Services Tariff Section 23.2, a “Pivotal Supplier” in the G-J Locality needs to control at least 650 MW of Unforced Capacity, and a specified portion of the capacity necessary to meet the G-J Locality LCR in an ICAP Spot Market Auction.

2017 Annual Installed Capacity Report |December 15, 2017|29

1,258

19845

817

807

610

560

473

471

338

289

1,350

Starting with Summer 2014, ROS
is comprised of Load Zone s A-F

1,200

1,050

900

750

600

552

489514

450

350384372320

322323

308300

296

150

Table 4: ROS Unoffered and Unsold Capacity MW by Type of Market
Participant

ROS Monthly Average Unoffered Capacity MW by Type of Market Participant

GenCo% of GenCoOthers% OtherTO% TOCapability Period Monthly Average

Summer 2008114.232.74%30.328.69%204.3758.57%348.9

Summer 200949.241.06%1.421.18%69.2557.76%119.9

Summer 201098.137.13%7.872.98%158.2259.90%264.2

Summer 201154.125.80%76.7036.56%78.9737.64%209.8

Summer 201260.129.48%75.3236.96%68.4033.56%203.8

Summer 2013486.678.28%64.2010.33%70.7711.39%621.5

Summer 201458.962.03%24.2325.52%11.8212.45%95.0

Summer 201521.326.97%30.7338.98%26.8534.05%78.9

Summer 20166.610.81%15.525.42%38.863.77%60.9

Summer 201745.259.75%18.424.39%12.015.85%75.6

ROS Monthly Average Unoffered Capacity MW by Type of Market Participant

GenCo% of GenCoOthers% OtherTO% TOCapability Period Monthly Average

Winter 2008-2009236.878.54%0.60.19%64.121.27%301.5

Winter 2009-201093.348.14%9.54.88%91.046.98%193.7

Winter 2010-2011212.657.39%30.48.19%127.534.41%370.4

Winter 2011-2012138.536.98%93.725.00%142.438.02%374.6

Winter 2012-2013437.373.43%21.03.52%137.323.05%595.5

Winter 2013-2014118.250.12%54.122.94%63.626.94%235.9

Winter 2014-201570.641.63%47.027.72%52.030.65%169.6

Winter 2015-201682.557.83%9.26.41%51.035.76%142.7

Winter 2016-201738.232.70%32.527.86%46.139.45%116.7

ROS Monthly Average Unsold Capacity MW by Type of Market Participant

GenCo% of GenCoOthers% OtherTO% TOCapability Period Monthly Average

Summer 200861.699.49%0.30.51%00%61.9

Summer 200900%00%00%0

Summer 201015.435.56%27.864.44%00%43.2

Summer 2011479.991.01%44.98.52%2.50.47%527.3

Summer 201200%00%00%0

Summer 201311.6100%00%00%11.6

Summer 201400%00%00%0

Summer 201500%00%00%0

Summer 201600%00%00%0

Summer 201700%00%00%0

ROS Monthly Average Unsold Capacity MW by Type of Market Participant

GenCo% of GenCoOthers% OtherTO% TOCapability Period Monthly Average

Winter 2008-2009178.797.65%4.32.35%00%183.0

Winter 2009-201073.495.30%3.64.70%00%77.0

Winter 2010-2011895.689.53%104.710.47%00%1000.3

Winter 2011-2012811.386.49%88.49.43%38.44.09%938.0

Winter 2012-20138.360.98%5.339.02%00%13.7

Winter 2013-201400%7.0100%00%7.0

Winter 2014-20155.07.79%59.092.21%00%64.0

Winter 2015-2016127.567.86%17.69.38%42.823%187.9

Winter 2016-2017172.188.39%22.611.61%0.00.00%194.7

2017 Annual Installed Capacity Report |December 15, 2017|31

Salient facts from the above tables are:

 The group of all ROS generation-owning Transmission Owners consistently had

unoffered capacity which ranged from 11% to 65% of total unoffered capacity.

 The group of all ROS generation-owning Transmission Owners had up to 23% of offered
and unsold capacity.

 The group of generation owners consistently had unoffered capacity which ranged from
25% to 79% of total unoffered capacity.

 The group of generation owners had unsold capacity which accounted for 0% to 100% of
total capacity that was offered and unsold capacity.

 The group of all others including SCRs consistently had unoffered capacity that ranged
from 0% to 39% of total unoffered capacity.

 The group of all others including SCRs had capacity that was offered and unsold
capacity that ranged from 0% to 100%.

I.5.4.2 Analysis of ROS Unoffered Capacity

This section provides a detailed analysis of the unoffered capacity located in the ROS.
The section also presents the maximum price impact of the unoffered capacity, in each month
and averaged over the six months of each Capability Period. Market Participants with a
significant amount of unoffered capacity were provided an opportunity to justify their unoffered
MW. Generally, responses suggest that the Installed Capacity Suppliers’ reasons for not
offering the Capacity were benign, and none of the instances evidenced behavior intended to
artificially raise prices.

Instances of unoffered capacity in Mitigated Capacity Zones are potentially subject to a non-discretionary penalty assessment (Services Tariff Section 23.4.5.4.2), and are not included in this section.

The NYISO contacted each Installed Capacity Supplier with at least 15 MW of unoffered
capacity in any one month during the period November 2016 through October 2017 for an
explanation of why it did not offer all of its capacity. There were eleven Market Participants with

15 MW or more of unoffered capacity in any given month in ROS, and the NYISO sought and received explanations from each of them.21

Eight Market Participants reported that their failure to offer capacity into the ICAP market
was due to an administrative oversight. Six of the instances failed to offer in just one month
over the two capability periods. One instance failed to offer in two consecutive months and the
remaining instance had several months in which they failed to offer. Out of the eight Market
Participants that had reported that the failure to offer was due to an administrative oversight
reason, five indicated that new procedures would be put in place to avoid failing to offer capacity
in the future. One of the eight also indicated its offering pattern as part of its explanation.

Three Market Participants reported environmental and/or physical conditions as cause for not offering capacity. These responses detailed causes including conservative operating strategies, SCR aggregation changes, and planned maintenance.

21 Confidential Attachment I provides a detailed summary of the Market Participants’ explanations for having unoffered capacity.

2017 Annual Installed Capacity Report |December 15, 2017|32

• Three generators submitted avoidable cost estimates in support of a calculated
GFC value.

• Two SCRs submitted heuristic strategies in support of a GFC value, citing
approximate shutdown costs or administrative and operational costs.

The NYISO performed ICAP Spot Market Auction simulations for a more detailed

understanding of how the non-zero price offers may have affected Market Clearing Prices. The NYISO simulated auction outcomes under three scenarios: GFCs with full net revenues, GFCs with half net revenues and GFCs with no net revenues. These scenarios are labeled scenarios 1, 2, and 3 in Table 9. The NYISO performed the simulations by replacing offers that originally did not clear with the unit-specific GFC at varying levels of net revenues. It is important to note that offers were only replaced with the GFCs value if the offers were not awarded any MW. If
the offer was marginal and only cleared a portion of its MW, or if the offer was inframarginal, the specific offers at the original offer prices were used. The offers that were analyzed for purposes of the simulations are provided in Attachment II.25

Table 9 shows the results of the auction simulations in each of the scenarios, for each
month of the analysis period (Winter 2016/2017). For comparison, the original ROS ICAP Spot
Market Auction prices are reported, in addition to the simulated ROS ICAP Spot Auction Prices
under each of the scenarios. The simulation price deltas relative to the original clearing prices
should not be positive because only entire offers that did not clear and which were originally
priced above the ICAP Monthly Auction clearing price were replaced with GFCs. The amount of
the price reduction shown in the simulations is static or decreasing as half or no revenues are
recognized in the GFC calculations. That outcome is consistent with what would be expected.

Table 9: ROS ICAP Spot Auction Price Impact Analysis Results

MonthROS Spot PricesS1[1]S2[2]S3[3]S1 deltaS2 deltaS3 delta

Nov-16$0.35$0.35$0.35$0.35$0.00$0.00$0.00

Dec-16$0.55$0.55$0.55$0.55$0.00$0.00$0.00

Jan-17$0.32$0.32$0.32$0.32$0.00$0.00$0.00

Feb-17$0.54$0.54$0.54$0.54$0.00$0.00$0.00

Mar-17$0.71$0.71$0.71$0.71$0.00$0.00$0.00

Apr-17$0.35$0.35$0.35$0.35$0.00$0.00$0.00

Notes to Table 9:

Note 1: GFCs with full net revenues
Note 2: GFCs with half net revenues
Note 3: GFCs with no net revenues

The results of the simulations shown in Table 9 indicate that the NYCA ICAP Spot

Market Auction prices likely would not have been lower if the entire offers did not clear were
offered at their respective GFC values. In all three scenarios, there would be no price impact.
As noted earlier, the simulations were performed by replacing only entire offers that did not clear

25 The unmasked unsold capacity offers are provided in Confidential Attachment III.

2017 Annual Installed Capacity Report |December 15, 2017|36

with their respective GFCs. The associated potential zero price impacts do not indicate that economic withholding occurred.

The analysis shows that no economic withholding occurred over the Winter 2016-2017.
During this period, the ICAP Spot Market Auction Market-Clearing Price for the NYCA was
below the Capability Period Market-Clearing Price and both above and below the Monthly
Auction clearing prices for the NYCA. The Capability Period and Monthly Auctions reflect market
place expectations for upcoming Spot Auction Market-Clearing Prices. In addition the Winter
2016-2017 ICAP Spot Market Auction Market-Clearing Price for the NYCA was below the
estimated Going Forward Costs for all of the ROS generators with unsold capacity.

2017 Annual Installed Capacity Report |December 15, 2017|37

II. NYISO Report on New Generation Projects

In its October 23, 2006 order, the Commission ordered the NYISO to submit “a list of

investments in new generation projects in New York (including a description and current status of each such project), regardless of the stage of project development at the time of the filing.”26 The NYISO keeps a list of Interconnection Requests and Transmission Projects for the New
York Control Area that includes information about all generation projects in the State that have requested interconnection.

The NYISO interconnection process for generators and Merchant Transmission Facilities
is described in two attachments of the NYISO OATT: OATT Attachment X entitled, “Standard
Large Facility Interconnection Procedures,” and OATT Attachment Z entitled, “Small Generator
Interconnection Procedures.” OATT Attachment X applies to Generating Facilities that exceed

20 MW in size and to Merchant Transmission Facilities, collectively referred to as “Large
Facilities.” OATT Attachment Z applies to Generating Facilities no larger than 20 MW.

Under OATT Attachment X, Developers of Large Facilities must submit an

Interconnection Request to the NYISO. The NYISO assigns a Queue Position to all valid
Interconnection Requests. Under OATT Attachment X, proposed generation and Merchant Transmission Facility projects undergo up to three studies: the Feasibility Study, the System Reliability Impact Study, and the Class Year Interconnection Facilities Study. The Class Year Interconnection Facilities Study is performed on a Class Year basis for a group of eligible projects pursuant to the requirements of OATT Attachment S. Under OATT Attachment Z, proposed small generators undergo a process that is similar, but with different paths and
options that are dependent on the specific circumstances of the project.

Proposed generation and transmission projects currently in the NYISO interconnection process are listed on the list of Interconnection Requests and Transmission Projects for the New York Control Area (“NYISO Interconnection Queue”). The generation projects on that list are shown in Attachment IV to this report, which is dated November 30, 2017. The NYISO updates the NYISO Interconnection Queue on at least a monthly basis and posts the most recent list on the NYISO’s public web site27 at the “Planning Documents and Resources”,
underneath the “Interconnection Studies” section.

The status of each project on the NYISO Interconnection Queue is shown in the column
labeled “S.” An explanation of this column is provided in Attachment V to this report. Also, note
that the proposed In-Service Date for each project is the date provided to the NYISO by the
respective Owner/Developer, is updated only on a periodic basis, and is subject to change.

26 See New York Independent System Operator Inc., 117 FERC ¶ 61,086, at P 14 (2006).

27 See <http://www.nyiso.com/public/markets_operations/services/planning/documents/index.jsp>.

2017 Annual Installed Capacity Report |December 15, 2017|38

III. New Generation Projects and Net Revenue Analysis III.1 Overview

The ICAP Demand Curves are designed to send efficient price signals to developers to build new generation and to generation owners to invest in existing generation when and where it is needed. In past ICAP annual reports, the NYISO stated that it is difficult to relate the
investment in new generation to the ICAP Demand Curves given the lead-time required to site, develop, and construct new generation, and to address other barriers to new entry; however,
the ICAP Demand Curves provide transparency for projecting Spot Market capacity price
signals that developers and owners consider prior to making investment decisions. Further,
since the creation of the new G-J Locality (encompassing Load Zones G, H, I and J) and the
implementation of the ICAP Demand Curves for it, there has been investment in resources in
Load Zones G, H, I, and J. This section of the report provides net revenue analysis on a
comparable basis to that used in the prior reports.

III.2 Market Design Developments to Enhance ICAP Demand Curve Performance

On January 17, 2017, FERC accepted the tariff revisions that establish the ICAP

Demand Curves for the 2017-2018 Capability Year.28 The January 2017 Order accepted the NYISO’s proposal to use the dual-fuel F-class frame combustion turbine (Siemens SGT6-
5000(F)) with selective catalytic reduction emission controls (“selective catalytic reduction”) to develop the ICAP Demand Curves for NYC, LI, and the G-J Locality for purposes establishing the ICAP Demand Curves effective through April 2021. A gas-only Siemens SGT6-5000(F) frame combustion turbine with an operational limit in lieu of selective catalytic reduction was selected as the representative peaking plant for the NYCA ICAP Demand Curve. The current ICAP Demand Curves are sending appropriate price signals.

III.3 Interconnection Queue Projects

The NYISO’s interconnection queue lists the projects that are being and will be

evaluated in the interconnection study processes. In-service dates stated on the

interconnection queue for projects are provided by the developers, and the NYISO periodically updates the queue (Attachment V). Chart 177 was compiled using data from Attachment V.
Chart 17 depicts the amount of generation listed on the NYISO’s interconnection queue since
2003 in NYC, LI, and Rest of State (“ROS”), and starting with Summer 2014 Capability Period it includes the G-J Locality. Wind projects are depicted separately from generation projects with other fuel types. The ROS depiction in Chart 177 does account for the change in its composition starting in Summer 2014 Capability Period with the creation of the G-J Locality (“G-J”). From
2003 through April 2014, ROS was comprised of Load Zones A through I. Since May 2014, it
has been comprised of Load Zones A through F.

28 As discussed in [Section I[ ] above, the NYISO’s tariff now has a quadrennial ICAP Demand Curve reset, with annual updates in the intervening years.

2017 Annual Installed Capacity Report |December 15, 2017|39

Chart 17: NYISO Interconnection Queue Projects

Chart 177 reports only those projects that were placed in the queue after May 1, 2003.29 Since the queue includes projects at various stages, for purposes of the analysis for this section of the report, the NYISO included those projects that are identified as active. Accordingly, pre2005 period projects with codes ‘I’, ‘W’, or ‘C’ were excluded; and for 2005 and beyond projects, status codes 0, 1, 12, 13, and 14 were omitted.

The number of generation projects and the amount of MW in the interconnection process
has increased since the ICAP Demand Curves became effective in May 2003. The number of
MW associated with projects based on technologies other than wind (measured on the left Y-
axis, above) did not increase significantly until the summer of 2005. Chart 177 shows that

29 Each project in the queue is provided a status code that identifies its position in the study process that
ranges from the initial scoping meeting to entering service. Prior to 2005, each project was provided a status-code
based on the NYISO System Reliability Impact Study from the following: P=Pending, A=Active, I=Inactive, R=Under
Review, C=Completed, W=Withdrawn. Starting in 2005, the classification system was changed and status-codes
were based on the standard steps in the NYISO’s interconnection process as follows: 1=Scoping Meeting Pending,
2=FES Pending, 3=FES in Progress, 4=SRIS Pending, 5=SRIS in Progress, 6=SRIS Approved, 7=FS Pending,

8=Rejected Cost Allocation/Next FS Pending, 9=FS in Progress, 10=Accepted Cost Allocation/IA in Progress, 11=IA Completed, 12=Under Construction, 13=In Service for Test, 14=In Service Commercial, 0=Withdrawn, where
FES=Feasibility Study, SRIS=System Reliability Impact Study, FS=Facilities Study.

2017 Annual Installed Capacity Report |December 15, 2017|40

beginning with the Winter 2007-2008 Capability Period, the number of MW listed in the

interconnection queue for the Rest of State rose sharply, particularly new non-wind projects. By
the end of 2011, this trend had largely reversed to pre-Winter 2007-2008 Capability Period
levels. The sharp decrease in proposed new non-wind generation in ROS shown in Chart 177
beginning with the Summer 2014 Capability Period is indicative of Load Zones G, H, I no longer
being part of ROS. Non-wind generation projects have increased in both ROS and all localities
since 2015. Wind generation projects have increased in ROS since 2015, and one wind project
was proposed in LI in 2017. No wind projects have been proposed in NYC or the G-J Locality in
2015, 2016, or to-date in 2017.

In addition to the proposed projects reflected in Chart 177, there are proposed HVDC
transmission lines. Two of the projects are from External Control Areas, one project with a
terminus in NYC, and the other project with a terminus in LI. A third project is proposed to be a
connection between Load Zone F (in the ROS) and Load Zone H (in the G-J Locality). If these
projects receive CRIS and Unforced Capacity Deliverability Rights (“UDRs”), the UCAP
associated with the UDRs can be used to satisfy the applicable LCR in which the facility has a
terminus.

III.4 Proposed Resource Additions

On October 18, 2016, the NYISO Board of Directors approved the 2016 Reliability

Needs Assessment Report (RNA).30 This report assessed resource adequacy, transmission security and transmission adequacy of the New York Control Area (NYCA) bulk power
transmission system for calendar years 2017 through 2026. In April of 2017, the NYISO issued the 2016 Comprehensive Reliability Plan (CRP), which reflected a reliable system.31

As mentioned above, the G-J Locality and its ICAP Demand Curve are providing market price signals for resources to locate new units and invest in existing units, including returning capacity to service in this area. For example, CPV Valley and Taylor Biomass are new
generation that is being built in Load Zone G, and Bowline 2 received additional CRIS MW in order to restore its full capacity. Other indications that the Demand Curve price signals are
working include units in the NYCA returning to service. These resource additions are included among the capacity resource changes summarized in Table 10.

30 The 2016 RNA report is available at:

<http://www.nyiso.com/public/webdocs/markets_operations/services/planning/Planning_Studies/Reliability_Planning_
Studies/Reliability_Assessment_Documents/2016RNA_Final_Oct18_2016.pdf>

31 The 2016 CRP report is available at:

<http://www.nyiso.com/public/webdocs/markets_operations/services/planning/Planning_Studies/Reliability_Planning_
Studies/Reliability_Assessment_Documents/2016CRP_Report_Final_Apr11_2017.pdf >.

2017 Annual Installed Capacity Report |December 15, 2017|41

N/A

Clay-Teall #10
115kV

NYSEG/RGE’s
terminal

upgrades,

increasing the
ratings on

Stolle Road-
Gardenville 230

kV Line #66,
addressing a

preliminary

Reliability Need
identified in

preliminary
("1st pass")

2016 RNA

NYSEG/RGE’s
terminal

upgrades,

increasing the
ratings on both

Clay-Pannell
PC1 and PC2
345 kV lines,
addressing a

preliminary

Reliability Need
identified in

preliminary
("1st pass")

2016 RNA
Oakdale

345/115 kV 3rd
transformer
and substation
reconfiguration,

addressing the
Oakdale

345/115 kV

Reliability Need
identified in

final 2016 RNA

CRP 2012

RNA 2016

CRP 2016
CRP 2014

C2016N/A

A2019N/A

C2019N/A

C2015N/A

N/AN/ATO Plan

Q4 2017Yes

I/SYes

2019Yes

2021No

Table 12: Summer Available Capacity vs. Required Capacity

201220132014201520162017

NYCARequirement (MW)35,07635,46735,81235,92035,43035,513

Availability (MW)37,88136,17736,08137,34036,35036,749

Capacity margin %108.0%102.0%100.7%104.0%102.6%103.5%

NYCRequirement (MW)8,8979,3259,4719,2728,5899,095

Availability (MW)9,6969,7219,5689,6809,2519,888

Capacity margin %109.0%104.2%101.0%104.4%107.7%108.7%

LIRequirement (MW)4,9615,3945,4315,2845,2075,303

Availability (MW)5,8585,7405,6755,6185,6795,785

Capacity margin %118.1%106.4%104.5%106.3%109.1%109.1%

G-JRequirement (MW)n/an/a13,49513,93413,51513,622

Availability (MW)n/an/a13,61014,58114,18214,407

Capacity margin %n/an/a100.9%104.6%104.9%105.8%

In Table 12, the NYCA Minimum Unforced Capacity Requirement is based on the annual
NYCA Minimum Installed Capacity Requirement. For each of the NYC, LI, and the G-J Locality,
the respective Locational Minimum Unforced Capacity Requirement is derived from their
respective Locational Minimum Installed Capacity Requirement. “Available Capacity” reflects the
aggregate of UCAP ratings excluding the amount of imported capacity via external
transactions.34

Since November 2014, the ICAP Demand Curves were established based on a different
peaking plant than that used to establish prior curves. For the 2016 data in Table 12, the
NYISO assumed a revenue requirement based on the same plant used for the analysis in the
2013 annual report; i.e., the respective peaking plant used to establish the ICAP Demand
Curves for the 2013-2014 Capability Year. This representation provides a direct comparison of
the revenues and revenue margins for the twelve months of market outcomes prior to 2014-
2015 Capability Year to those in previous annual reports. For the 2014 G-J Locality revenue
analysis, the NYISO used cost assumptions for the LMS100 used in the NYCA region and
adjusted the costs based upon information developed by the ICAP Demand Curve reset
independent consultant in 2014.

Table 13 shows the annual revenue requirement for the hypothetical plants based on the
assumptions used in the previous ICAP Demand Curves and the 2017 ICAP Demand Curves.
For the G-J Locality the annual revenue requirements for 2014 have been adjusted for six
months only — the 2014 Summer Capability Period — the period that corresponds with the
initial implementation for the ICAP Demand Curves for the G-J Locality. The notional values
used for the New York City, LI, and G-J Localities are based on an LMS100 technology, and for
NYCA, figures are based on GE 7FA combustion turbine without selective catalytic reduction for
the years 2011 to 2014. For 2015 and 2016 figures, a dual-fuel Siemens F class Frame unit with
selective catalytic reduction was used as the peaking plant for the G-J, J, and LI Localities. A

34 In contrast to the forecasted figures used in the Gold Book, this table reflects data based on realized outcomes over the Summer Capability Periods.

2017 Annual Installed Capacity Report |December 15, 2017|45

gas-only Siemens F class Frame unit without selective catalytic reduction was used for the NYCA. For 2017, the same technology from 2016 was used assuming the 2017-2018 ICAP Demand Curve parameters.

Table 13: Annual Revenue Requirements in UCAP terms ($/MW)

201220132014201520162017

NYCA$122,650$124,094$126,111$113,738$117,709$117,970

NYC$282,388$284,578$288,371$217,390$231,098$228,487

LI$263,070$262,912$263,455$176,031$179,684$179,236

NCZ$116,966$154,522$162,388$161,911

Note to Table 13: As with prior annual reports, this table is based on November of the year prior to the year stated in the first row, through October of the year stated, except that the Annual Revenue Requirements for the G-J Locality for 2014 are based on the six month revenue requirement calculated beginning with the Summer 2014 Capability Period when the G-J Locality and its ICAP Demand Curve were first implemented.

Table 14 shows the revenues for individual markets (i.e., the Energy, Ancillary Services (A/S)), and the ICAP Spot Market Auction that the identified hypothetical peaking plant may have received based on actual LBMPs, natural gas prices, and other reasonable parameters used to calculate variable costs from the corresponding Demand Curve reports.

For previous reports, a model was used to calculate the Energy and Ancillary Services
revenue for the respective hypothetical peaking plants. Net Energy revenues are earned in
hours when the Day-Ahead Market LBMP exceeds the calculated variable cost. Otherwise, Day-
Ahead Ancillary Services revenues are earned. This approach is similar to the “standard
method” used by the Market Monitoring Unit for the NYISO in its annual State of the Market
reports. This year’s report relied upon the FERC-approved Net EAS Model used within the 2017
ICAP Demand Curves to calculate Net EAS revenues. This model utilizes both Day-Ahead and
Real-Time prices to provide a more accurate estimate of a proxy plant’s hypothetical revenue.

For 2012, 2013 and the Winter 2013/2014 Capability Period, the Ancillary Services
revenues earned by the hypothetical LMS100 technology were based upon 10-Minute Non-
Synchronized Reserve prices, whereas Ancillary Service revenues for the hypothetical NYCA peaking plant were based on Day-Ahead 30-Minute Reserve prices. For the Capability Year
beginning May 2014, the Frame Combustion Turbine technology Ancillary Services revenues for the hypothetical peaking plant technology in all capacity regions were based upon Day-Ahead 30-Minute Operating Reserve prices. The decrease in Net EAS from 2016-2017 was likely
attributable to the improved data available through the new model.

ICAP Market revenues were based on the ICAP Spot Market clearing prices for each Locality.

2017 Annual Installed Capacity Report |December 15, 2017|46

(Chart 18) and Capacity (Chart 19), as well as revenue relative to value used for the cost of new entry (Chart 20).

The capacity revenue component of the total net revenue as a percentage of the cost of new entry in the NYCA and in each Locality is depicted in Chart 20. The amount of excess
capacity peaked in NYCA, NYC, and LI in 2011, and as a result, the capacity market revenues relative to the cost of new entry requirements shown in this chart dropped precipitously, thereby appropriately signaling to the market that sufficient capacity already existed.35 As the amount of excess capacity above requirements shrinks, capacity market revenues increase. The effect of the recent increases to the level of excess capacity is reflected in the generally lower revenue margins calculated for 2016 and 2017 compared to other recent prior years

Chart 18: UCAP based Revenue Margins

35 2011 State of Market Report, p. A-13.

2017 Annual Installed Capacity Report |December 15, 2017|48

Attachments

2017 Annual Installed Capacity Report |December 15, 2017|

Attachment I: Confidential.

Unoffered Capacity: Market Participant Explanations

(Not included with the public filing.)

2017 Annual Installed Capacity Report |December 15, 2017|Attachment I| i

Attachment III: Unsold Capacity Offers (UnMasked)

(Not included with the public filing.)

2017 Annual Installed Capacity Report |December 15, 2017|Attachment III| iii

Attachment V: Interconnection Queue

QueueDateSPWPType/LocationInterconnectionLastAvailabilityFS Complete/ProposedProposed

Pos.Owner/DeveloperProject Nameof IR(MW)(MW)FuelCounty/StateZPointUtilitySUpdateof StudiesSGIA TenderIn-ServiceCOD

251CPV Valley, LLCCPV Valley Energy Center7/5/07677.6690.6CC-DOrange, NYGCoopers - Rock Tavern 345kVNYPA117/31/16FES, SRIS, FS10/15/132017/062018/02

276Air Energie TCI, Inc.Crown City Wind Farm1/30/089090WCortland, NYCCortland - Fenner 115kVNM-NG71/31/15FES, SRIS2018/122018/12

331National GridNortheast NY Reinforcement4/22/09N/AN/A ACSaratoga, NYFNGrid 230kVNM-NG12,145/31/16SIS2010-2019N/A

333National GridWestern NY Reinforcement5/5/09N/AN/A ACCattaraugus, NYANGrid 115kVNM-NG12,145/31/16SIS2015-2019N/A

338RG&EBrown's Race II8/11/096.36.3HMonroe, NYBStation 137 11kVRG&E115/31/17FS2018/092018/09

339RG&ETransmission Reinforcement8/17/09N/AN/A ACMonroe, NYBNiagara - Kintigh 345kVRG&E1212/31/16SIS2019/WN/A

347Franklin Wind Farm, LLCFranklin Wind12/2/0950.450.4WDelaware, NYEOakdale - Delhi 115kVNYSEG74/30/16FES, SRIS2019/102019/12

349Taylor Biomass Energy-Montgomery, LLC Taylor Biomass12/30/091922.5SWOrange, NYGMaybrook - Rock Tavern 69kVCHGE1211/30/16SRIS, FS10/15/132017/122018/04

358West Point Partners, LLCWest Point Transmission9/13/1010001000DCGreene, Westchester, NYF, HLeeds - Buchanan North 345kVNM-NG/ConEd74/30/17FES, SRIS2021/012021/05

361US PowerGen Co.Luyster Creek Energy2/15/11401444CC-DQueens, NYJAstoria West Substation 138kVCONED76/30/17FES, SRIS2021/062021/06

363Poseidon Transmission 1, LLCPoseidon Transmission4/27/11500500DCNJ - Suffolk, NYKRuland Rd. 138kVLIPA107/31/17FES, SRIS, FS2/2/20172020/032021/01

367Orange & RocklandNorth Rockland Transformer9/14/11N/AN/A ACRockland, NYGLine Y94 345kVConEd65/31/16SIS2018/06N/A

371South Mountain Wind, LLCSouth Mountain Wind10/31/111818WDelaware, NYERiver Rd Substation 46kVNYSEG710/31/17FES2020/112020/12

372Dry Lots Wind, LLCDry Lots Wind10/31/113333WHerkimer, NYESchuyler - Whitesboro 46kVNM-NG710/31/17FES, SRIS2020/112020/12

382Astoria Generating Co.South Pier Improvement5/30/1291.295.5CT-NGKings, NYJGowanus Substation 138kVConEd76/30/17SRIS2020/062020/06

383NRG Energy, Inc.Bowline Gen. Station Unit #35/30/12775814CC-NG Rockland, NYGLadentown Subsation 345kVO&R/ConEd76/30/16SRIS2022/012022/06

386Vermont Green Line Devco, LLCGrand Isle Intertie6/28/12400400DCClinton, NY - VTDPlattsburgh 230kV-New Haven, VT 345kVNYPA79/30/16FES, SRIS2018/062018/06

387Cassadaga Wind, LLCCassadaga Wind7/19/12126126WChautauqua, NYADunkirk - Moon Station 115 kVNM-NG94/30/17FES, SRIS2019/092019/12

393NRG Berrians East Development, LLCBerrians East Replacement10/16/1294.257CT-DQueens , NYJAstoria East Substation 138kVCONED97/31/17FES, SRIS2018/062018/06

395Copenhagen Wind Farm, LLCCopenhagen Wind11/12/1279.979.9WLewis, NYEBlack River-Lighthouse Hill 115kVNM-NG107/31/17FES, SRIS, FS2/2/20172018/052018/11

396Baron Winds, LLCBaron Winds11/30/12300300WSteuben, NYCHillside - Meyer 230kVNYSEG95/31/17FES, SRIS2019/092019/12

396ANew York State Electric & GasWood Street Transformer12/14/12N/AN/A ACPutnum, NYGWood St. 345/115kVNYSEG65/31/16SIS2021/12N/A

398Black Oak Wind Farm, LLCBlack Oak Wind1/10/1312.512.5WTompkins, NYCMontour - Coddington 115kVNYSEG105/31/17SIS, FS8/28/152018/012018/03

401Caithness Long Island II, LLCCaithness Long Island II3/22/13599632CC-DSuffolk, NYKSills Road Substation 138kVLIPA86/30/17SRIS2018/042019/05

403PSEG Power New YorkBethlehem Energy Center Upr5/28/137251.2CC-DAlbany, NYFBethlehem Energy CenterNM-NG102/28/17FES, SRIS, FS2/2/20172017-20192017-2019

414North America Transmission, LLCSegment B Enhanced9/5/13N/AN/A ACAlbany-Dutchess, NYF, GNew Scotland - P. Valley 345kVNM-NG/ConEd53/31/17None20192019

421EDP Renewables North AmericaArkwright Summit11/1/137878WChautauqua, NYADunkirk - Falconer 115 kVNM-NG97/31/17SRIS2017/102018/10

422NextEra Energy Resources, LLCEight Point Wind Energy Center11/7/13101.2101.2WSteuben-Allegany, NY CBennett 115kVNYSEG96/30/17FES, SRIS2018/122018/12

429Orange & RocklandNorth Rockland Station2/12/14N/AN/A ACRockland, NYGLine Y88 345kVConEd65/31/16SIS2018/06N/A

430H.Q. Energy Services U.S. Inc.Cedar Rapids Transmission3/5/14N/AN/A ACSt. Lawrence, NYDDennison - Alcoa 115kVNM-NG911/30/17SIS2019/Q4N/A

431Greenidge GenerationGreenidge Unit #44/11/14106.3106.3ST-NGYates, NYCGreenidge Substation 115kVNYSEG143/31/17SRIS, FSI/SI/S

432New York State Electric & GasSouth Perry Transformer4/15/14N/AN/A ACWyoming, NYBSouth Perry Substation 115kVNYSEG65/31/17SIS2019/07N/A

440Erie Power, LLCErie Power6/2/1479.488CC-NG Chautauqua, NYASouth Ripley Substation 230kVNM-NG97/31/17SRIS2019/022019/02

444Cricket Valley Energy Center, LLC Cricket Valley Energy Center II6/18/1410201132CC-NG Dutchess, NYGPleasant Valley - Long Mt. 345kVConEd9, 117/31/17SRIS2017/122020/01

445Lighthouse Wind, LLCLighthouse Wind6/30/14201.3201.3WNiagara, NYAAES Somerset Substation 345kVNYSEG78/31/17FES, SRIS2020/082020/12

448Alps Interconnector, LLCAlps HVDC8/12/14600600DCNE-Rensselaer, NYFAlps Substation 345kVNM-NG51/31/16FES2019/062019/06

449Stockbridge Wind, LLCStockbridge Wind8/13/1472.672.6WMadison, NYEWhitman - Oneida 115kVNM-NG710/31/17SRIS2019/082019/12

458TDI-USA Holdings, Inc.CH Interconnection10/24/1410001000DCQuebec - NY, NYJAstoria Annex Substation 345kVNYPA96/30/17FES, SRIS2021/Q12021/Q2

461Consolidated Edison Co. of NYEast River 1 Uprate12/1/1422CT-NGNew York, NYJEast River ComplexConEd9, 144/30/17SRIS, FS2/2/2017I/SI/S

462Consolidated Edison Co. of NYEast River 2 Uprate12/1/1422CT-NGNew York, NYJEast River ComplexConEd9, 144/30/17SRIS, FS2/2/2017I/SI/S

465Hudson Transmssion PartnersHudson Transmission NY to PJM12/15/14675675DC/ACNew York, NYJW49th St 345kV - Bergen 230kVConEd75/31/17SRIS2021/012021/05

466Atlantic Wind, LLCBone Run Win12/16/14132132WCattaraugus, NYAFalconer - Homer Hill 115kVNM-NG711/30/16FES, SRIS2019/122019/12

467Invenergy Solar Development, LLCShoreham Solar12/22/142525SSuffolk, NYKRidge - Wildwood 69kVLIPA93/31/17SRIS2018/062018/06

468Apex Clean Energy LLCGalloo Island Wind12/30/14110.4110.4WOswego, NYCHammermill - Wine Creek 115kVNM-NG95/31/17FES, SRIS2019/102019/12

473Calverton Solar LLCCalverton Solar1/21/151010SSuffolk, NYKRiverhead - Wildwood 69kVLIPA512/31/16FES2017/Q32017/Q3

474EDP Renewables North AmericaNorth Slope Wind1/30/15200200WFranklin-Clinton, NYDPatnode 230kVNYPA73/31/17FES, SRIS2021/102021/10

477Riverhead Solar Farm LLCRiverhead Solar2/18/152020SSuffolk, NYKEdwards Substation 138kVLIPA96/30/17FES, SIS2018/102018/10

487LI Energy Storage SystemFar Rockaway Battery Storage3/9/152020ESSuffolk, NYKFar Rockaway Substation 69kVLIPA45/31/17FES2018/102018/10

494Alabama Ledge Wind Farm LLCAlabama Ledge Wind3/31/1579.879.8WGenesee, NYAOakfield - Lockport 115kVNM-NG95/31/17SRIS2020/072020/10

495Mohawk Solar LLCMohawk Solar4/2/159898SMontgomery, NYFSt. Johnsville - Marshville 115kVNM-NG68/31/17FES, SRIS2018/092018/12

2017 Annual Installed Capacity Report |December 15, 2017|Attachment V| v

496Renovo Energy Center, LLCRenovo Energy Center

497Invenergy Wind Developm ent LLC Bull Run Wind

498ESC Tioga County Power, LLCTioga County Power

505RES America Devlopments Inc.Ball Hill Wind

506Empire State Connector Corp.Empire State Connector

510Bayonne Energy CenterBayonne Energy Center II

511AG Energy, LPOgdensburg

512Northbrook Lyons FallsLyons Fills Mill Hydro

513Stony Creek Energy LLCOrangeville

514RES Americas Developments Inc. Empire Wind

515North Bergen Liberty Generation Center LLCLiberty Generation

516East Coast Power LLCLinden Cogen Uprate

518PPL Electric UtilitiesCompass

519Canisteo Wind Energy LLCCanisteo Wind

520EDP Renewables North AmericaRolling Upland Wind

521Invenergy NY, LLCBull Run II Wind

522NYC Energy LLCNYC Energy

523Dunkirk Power LLCDunkirk Unit 2

524Dunkirk Power LLCDunkirk Unit 3 & 4

525New York Power AuthorityWestern NY Energy Link

526Atlantic Wind, LLCNorth Ridge Wind

530NextEra Energy Transmission New York, Inc.Empire State Line

531Invenergy Wind Developm ent LLC Num ber 3 Wind Energy

532RES America Devlopments LLCAllegany Wind

534OneEnergy Development, LLCGreat Valley Solar

535sPower Development Company, LLC Riverhead Expansion

537NextEra Energy Transmission New York, Inc.Segment A

538NextEra Energy Transmission New York, Inc.Segment B

539NextEra Energy Transmission New York, Inc.Segment B Alt

540AVANGRIDConnect NY Edic - PV

541AVANGRIDConnect NY Edic - Ramapo

542National GridSegment A Edic-New Scotland

543National GridSegment B Knickerbocker-PV

545Sky High Solar, LLCSky High Solar

545ANextEra Energy Transmission New York, Inc.Empire State Line Alt

546Atlantic Wind, LLCRoaring Brook Wind

547North America Transmission, LLC Dysinger-Stolle

555North America Transmission, LLC Segment A Base

556North America Transmission, LLC Segment A Double Circuit

557North America Transmission, LLC Segment A Enhanced

558North America Transmission, LLC Segment A 765

559North America Transmission, LLC Segmant B Base

560Atlantic Wind, LLCDeer River Wind

561As toria Generating Co. LPAs toria Generating Unit 4

563Double Lock Solar, LLCDouble Lock Solar

564Rock District Solar, LLCRock District Solar

565Tayandenga Solar, LLCeTayandenega Solar

566New York Power AuthorityMA 1 & 2 Rebuild

567Tribes Hill Solar, LLCTribes Hill Solar

568Turkey Hollow Solar, LLCTurkey Hollow Solar

570Hecate Energy, LLCAlbany County

4/13/15480504CC-NG Chemung, NY - PA

4/24/15303.6303.6WClinton, NY

4/29/15550550CC-NG Chemung, NY - PA

6/2/15100100WChautauqua, NY

6/10/1510001000DCOnondaga-New Y ork, NY

8/3/15120.4129.4CT-DBayonne, NJ

9/4/157990.1CT-NG St. Lawrence, NY

9/11/1514.114.1HLewis, NY

9/21/152020ESWyoming, NY

10/1/15120120WRensselaer, NY

10/7/1510001000 CC-NG New York, NY

10/12/15234.4234.4 CT-NG Linden, NJ-NY,NY

10/27/15N/AN/AACPA-Rockland, NY

11/2/15290.7290.7WSteuben, NY

12/3/1572.672.6WMadison, NY

12/15/15145.4145.4WClinton, NY

12/16/1579.979.9CT-NG New York, NY

12/17/157575ST-NG Chautauqua, NY

12/17/15370370ST-NG Chautauqua, NY

12/18/15N/AN/AACNiagara, NY

12/23/15100100WSt. Lawrence, NY

1/4/16N/AN/AACNiagara-Erie, NY

1/11/16105.8105.8WLewis, NY

2/1/16100100WAllegany, NY

2/3/162020SWashington, NY

2/23/163636SSuffolk, NY

4/25/16N/AN/AACOneida-Albany NY

4/25/16N/AN/AACAlbany-Dutchess, NY

4/28/1610001000DCOneida-Dutchess, NY

5/4/16N/AN/AACOneida-Albany NY

5/4/16N/AN/AACAlbany-Dutchess, NY

5/10/162020SOnondaga, NY

5/17/16N/AN/AACNiagara-Erie, NY

5/19/167878WLewis, NY

5/25/16N/AN/AACNiagara-Erie, NY

7/6/16N/AN/AACOneida-Albany NY

7/8/16100100WLewis, NY

7/18/16385385ST-DNew York, NY

7/25/162020SHerkimer, NY

7/25/162020SSchoharie, NY

7/25/162020SHerkimer, NY

8/4/16N/AN/AACSt. Law rence-Lew is, NY

8/10/162020SMongomery, NY

8/16/162020SDelaware, NY
8/17/16 20 20 S Albany, NY

CHomer City - Watercure 345kV

DPatnode 230kV

CHomer City - Watercure 345kV

ADunkirk - Gardenville 230kV C, J Clay - Gowanus 345kV

JGowanus Substation 345kV

ENorth Ogdensburg Substation

ETaylorville- Boonville 115 kV

AStony Creek 230kV

FStephentown - Greenbush 115kV

JW49th St 345kV

JLinden Cogen 345kV

GLackawanna - Ramapo 345kV

CBennett 115kV

ECounty Line - Bothertown 115kV

DPatnode 230kV

JHudson Avenue East 138kV

ADunkirk 115kV

ADunkirk 230kV

ANiagara - Stolle - Gardenville

EColton - Malone 115kV

ADysinger - Stolle 345kV

ELowville - Bremen 115kV

BFreedom Substation

FBattenkill Substation

KEdwards Substation 138kV
E, F Edic - New Scotland 345kV
F, G Greenbush - PV 345kV

F, G Greenbush - PV 345kV
E, G Edic - PV 345kV

E, G Edic - Ramapo 345kV
E, F Edic - New Scotland 345kV
F, G Greenbush - PV 345kV

C115kV

ADysinger - Stolle 345kV

EChases Lake Substation

ADysinger - Stolle 345kV
E, F Edic - New Scotland 345kV
E, F Edic - New Scotland 345kV
E, F Edic - New Scotland 345kV
E, F Edic - New Scotland 345kV
E, F Knickerbocker - PV 345kV

EBlack River-Lighthouse Hill 115kV

JAstoria West Substation 138 kV

EMarshville 115kV

FSharon - Cobleskill 69kV

ESt. Johnsville - Inghams 115kV D, E Moses & Adirondack 230kV

FChurch St. 69KV

FGrand Gorge - Axtell Road 115kV
F Long Lane - Lafarge 115kV

NYSEG911/30/17FES, SRIS2019/092020/06

NYPA56/30/16FES2018/102018/12

NYSEG94/30/17FES, SRIS2020/062021/05

NM-NG94/30/17SRIS2018/092018/12

NYPA/NM-NG/

ConEd45/31/17FES2021/102022/01

ConEd97/31/17SRIS2017/112018/02

NM-NG910/31/17SRIS2018/052018/05

NM-NG711/30/16SIS2018/032018/03

NYSEG78/31/17SIS2018/032018/03

NM-NG42/28/17FES2019/102019/10

ConEd39/30/17None2019/062019/06

ConEd95/31/17SRIS2020/052020/05

ConEd58/31/17FES2023/122023/12

NYSEG510/31/16FES2019/102019/12

NYSEG56/30/17FES2019/072019/10

NYPA56/30/17FES2018/102018/12

ConEd511/30/17FES2019/102019/10

NM-NG911/30/17SRIS2018/082018/12

NY PA /NY SEG65/31/17SIS2020N/A

NM-NG611/30/17FES, SRIS2019/112019/12

NY PA /NY SEG610/31/17SIS2020/052020/05

NM-NG52/28/17FES2019/102019/12

Village of Arcade54/30/17None2018/092018/12

NM-NG711/30/17FES, SIS2018/022018/02

LIPA511/30/17FES2020/112020/12

NM-NG/NYPA

58/31/17None2018/112018/11

NM-NG/NYSEG/

CHGE/ConEd58/31/17None2018/112018/11

NM-NG/NYSEG/

CHGE/ConEd58/31/17None2018/112018/11

NM-NG/NYSEG/

ConEd512/31/16None2020/122020/12

NM-NG/NYSEG/

O&R510/31/16None2020/122020/12

NM-NG511/30/16None2021/122021/12

NM-NG/NYSEG/

CHGE/ConEd511/30/16None2021/122021/12

NM-NG57/31/17FES2018/122018/12

NY PA /NY SEG610/31/17SIS2020/062020/06

NM-NG57/31/17FES2019/112019/12

NYPA/NYSEG/

NM-NG610/31/17SIS2020/062020/06

NM-NG/NYSEG/

CHGE/ConEd51/31/17None2020/012020/01

NM-NG/NYSEG/

CHGE/ConEd51/31/17None2020/062020/06

NM-NG/NYSEG/

CHGE/ConEd51/31/17None2020/012020/01

NM-NG/NYSEG/
NYPA/CHGE/ConE

d512/31/16None2020/012020/01

NM-NG/NYSEG/

CHGE/ConEd51/31/17None2019/092019/09

NM-NG410/31/17FES2019/112019/12

ConEd511/30/17None2018/052018/05

NM-NG44/30/17None2018/122018/12

NYPA510/31/16None2022/122022/12

NM-NG44/30/17None2018/122018/12

NYSEG711/30/17SIS2018/122018/12
NM-NG 5 10/31/17 None 2019/06 2019/06

Attachment V: Interconnection Queue

QueueDateSPWPType/LocationInterconnectionLastAvailabilityFS Complete/ProposedProposed

Pos.Owner/DeveloperProject Nameof IR(MW)(MW)FuelCounty/StateZPointUtilitySUpdateof StudiesSGIA TenderIn-ServiceCOD

671East Coast Power LLCLinden Cogen Uprate9/25/1732.023.0CT-NG Linden, NJ-NY,NYJ Linden Cogen 345kVConEd411/30/17None2018/012018/01

672LS Power Development, LLCHelix Ravenswood I10/6/1730.230.2NG New York, NYJ Rainey Substation 345kVConEd210/31/17None2022/072023/01

673LS Power Development, LLCHelix Ravenswood II10/6/1772.472.4NG New York, NYJ Rainey Substation 345kVConEd210/31/17None2022/072023/01

674Helix Ravenswood, LLCVernon Battery Storage I10/24/171010ES Queens, NYJ Vernon SubstationConEd411/30/17None2020/052020/05

675Helix Ravenswood, LLCVernon Battery Storage II10/24/171010ES Queens, NYJ Vernon SubstationConEd411/30/17None2020/052020/05

677Granada Solar, LLCGrange Solar10/25/172020S Nanticoke, NYC Vincent Cors 34.5kVNYSEG111/30/17None2019/062019/06

678LI Solar Generation, LLCCalverton Solar Energy Center10/26/1722.922.9S Suffolk, NYK Edwards Substation 138kVLIPA111/30/17None2020/122020/12

Number of new projects during November2

Number of new projects year to date85

Number withdrawn during November4

Number withdrawn year to date38

NOTES: ● The column labeled 'SP' refers to the maximum summer megawatt electrical output. The column labeled 'WP' refers to the maximum winter megawatt electrical output.

● Type / Fuel. Key: ST=Steam Turbine, CT=Combustion Turbine, CC=Combined Cycle, CS= Steam Turbine & Combustion Turbine, H=Hydro, PS=Pumped Storage, W=Wind, NU=Nuclear, NG=Natural Gas, M=Methane, SW=Solid Waste, S=Solar, Wo=Wood, F=Flywheel ES=Energy Storage, O=Oil, C=Coal, D=Dual Fuel, AC=AC Transmission, DC=DC Transmission, L=Load, FC=Fuel Cell

● The column labeled 'Z' refers to the zone

● The column labeled 'S' refers to the status of the project in the NYISO's LFIP. Key: 1=Scoping Meeting Pending, 2=FES Pending, 3=FES in Progress, 4=SRIS/SIS Pending, 5=SRIS/SIS in Progress, 6=SRIS/SIS Approved, 7=FS Pending, 8=Rejected Cost Allocation/Next FS Pending, 9=FS in Progress, 10=Accepted Cost Allocation/IA in Progress, 11=IA Completed, 12=Under Construction, 13=In Service for Test, 14=In Service Commercial, 0=Withdrawn

● Availability of Studies Key: None=Not Available, FES=Feasibility Study Available, SRIS=System Reliability Impact Study Available, FS=Facilities Study and/or ATRA Available ● FS Complete/SGIA Tender refers to the Attachment X milestone used to apply the 4-year COD limitation.

● Proposed in-service dates and Commerical Operation Dates (COD) are shown in format Year/Qualifier, where Qualifier may indicate the month, season, or quarter.

DPS/State - SIR Interconnection Queue (for Projects not subject to the NYISO process):

http://www3.dps.ny.gov/W/PSCWeb.nsf/All/286D2C179E9A5A8385257FBF003F1F7E?OpenDocument

2017 Annual Installed Capacity Report |December 15, 2017|Attachment V| vii

Attachment VII: November 1999 - October 2017 Installed Capacity Auction Activity

NYCANYCLIG-J Locality

CapabilityMonthly AuctionS pot Market **Minimum RequiredExcess S oldCapabilityMonthly AuctionS pot MarketMinimum RequiredExcess S oldCapabilityMonthlyS pot MarketMinimum RequiredExcess S oldCapabilityMonthly AuctionS pot MarketMinimum RequiredExcess S old

Period* (S trip)**Period* (S trip)Period*AuctionPeriod* (S trip)

(S trip)

MonthMW PriceMW PriceMW PriceMWMWMW PriceMW PriceMW PriceMWMWMW PriceMW PriceMW PriceMWMWMWPriceMWPriceMWPriceMWMW

Nov-9935,563.18,305.64,555.3

Dec-9935,563.18,305.64,555.3

Jan-00Installed Capacity M arket Existed but all purchases and35,563.1Installed Capacity M arket Existed but all purchases and8,305.6Installed Capacity M arket Existed but all purchases4,555.3

Feb-00sales were bilateral35,563.1sales were bilateral8,305.6and sales were bilateral4,555.3

Mar-0035,563.18,305.64,555.3

Apr-0035,563.18,305.64,555.3

May-001,976.0$1.50434.2$1.3032.7$0.5035,636.01,976.05,408.8$8.7559.4$12.500.0-8,272.00.0-0.0-0.0-4,638.0

Jun-001,976.0$1.50528.4$1.4037.1$1.2835,563.11,976.05,408.8$8.75313.4$9.4652.7$12.508,272.00.0-0.0-0.0-4,638.0

Jul-001,976.0$1.50344.2$1.80140.8$1.9835,563.11,976.05,408.8$8.75342.7$9.40100.0$12.508,272.00.0-0.0-0.0-4,638.0

Aug-001,976.0$1.50351.4$1.62194.8$1.7735,563.11,976.05,408.8$8.75332.6$9.42133.9$12.508,272.00.0-0.0-0.0-4,638.0

Sep-001,976.0$1.50648.9$1.3281.3$1.1635,563.11,976.05,408.8$8.75344.5$9.40149.5$12.508,272.00.0-0.0-0.0-4,638.0

Oct-001,976.0$1.50681.6$1.3096.9$0.8935,563.11,976.05,408.8$8.75304.2$9.49214.0$12.508,272.00.0-0.0-0.0-4,638.0

Nov-004,010.6$1.041,813.6$1.00157.7$0.8035,563.14,010.64,861.4$8.75735.0$8.74170.3$8.758,272.00.0-0.0-0.0-4,638.0

Dec-004,010.6$1.041,854.1$0.97167.2$0.8635,563.14,010.64,861.4$8.75785.1$8.74154.8$8.758,272.00.0-0.0-0.0-4,638.0

Jan-014,010.6$1.041,847.6$0.97170.5$0.8535,563.14,010.64,861.4$8.75899.5$8.74154.8$8.758,272.00.0-0.0-0.0-4,638.0

Feb-014,010.6$1.041,893.8$0.95177.2$0.8335,563.14,010.64,861.4$8.75921.7$8.71154.8$8.758,272.00.0-0.0-0.0-4,638.0

Mar-014,010.6$1.042,032.8$0.95208.1$0.7935,563.14,010.64,861.4$8.75936.5$8.74156.0$8.758,272.00.0-0.0-0.0-4,638.0

Apr-014,010.6$1.041,659.7$0.87192.3$0.5935,563.14,010.64,861.4$8.75985.6$8.56156.7$8.728,272.00.0-0.0-0.0-4,638.0

May-012,738.6$1.90852.3$2.251,022.2$9.5836,132.02,738.65,316.6$8.75248.7$8.75235.1$12.508,375.0(est.)0.0-0.0-3.2$10.834,625.0

Jun-012,738.6$1.90397.6$2.681,521.0$9.4136,132.02,738.65,316.6$8.75228.4$10.92299.0$12.188,375.0(est.)0.0-0.0-7.0$10.834,625.0

Jul-012,738.6$1.901,776.6$4.311,534.9$9.4436,132.02,738.65,316.6$8.75407.8$9.77292.5$8.838,375.0(est.)0.0-0.0-20.2$10.834,625.0

Aug-012,738.6$1.901,788.4$4.561,601.3$9.3536,132.02,738.65,316.6$8.75440.1$8.38350.1$9.468,375.0(est.)0.0-0.0-21.3$10.834,625.0

Sep-012,738.6$1.901,701.2$4.161,498.0$9.2136,132.02,738.65,316.6$8.75434.9$8.42316.0$8.348,375.0(est.)0.0-0.0-33.0$10.834,625.0

Oct-012,738.6$1.901,787.1$4.031,473.4$9.1436,132.02,738.65,316.6$8.75430.1$7.99343.4$8.728,375.0(est.)0.0-0.0-33.0$10.834,625.0

Nov-011,760.4$2.00878.0$0.105.8$-32,892.31,760.43,972.5$9.40772.8$9.0077.7$4.807,613.30.0-0.6$3.508.5$12.334,077.6

Dec-011,760.4$2.00687.2$0.496.5$-32,892.31,760.43,972.5$9.40906.8$6.8811.5$ -7,613.30.0-1.3$3.5037.4$12.334,077.6

Jan-021,760.4$2.00750.5$0.84133.0$0.7532,892.31,760.43,972.5$9.40492.6$5.47377.3$8.257,613.30.0-1.3$5.0039.7$12.334,077.6

Feb-021,760.4$2.00836.2$0.7025.5$-32,892.31,760.43,972.5$9.40631.1$6.69229.3$9.207,613.30.0-0.0$ -40.6$11.504,077.6

Mar-021,760.4$2.00901.3$0.6130.0$0.2532,892.31,760.43,972.5$9.40784.3$6.9290.6$7.507,613.30.0-14.0$11.5026.4$11.494,077.6

Apr-021,760.4$2.00677.9$0.695.6$0.0232,892.31,760.43,972.5$9.40932.9$7.1211.6$9.407,613.30.0-41.4$11.480.0-4,077.6

May-023,201.6$1.75552.1$0.332.3$-32,479.53,201.64,355.2$9.20684.1$9.3830.5$9.397,621.60.0-0.0-0.0-4,177.8

Jun-023,201.6$1.75438.3$0.3620.3$0.0132,479.53,201.64,355.2$9.20671.2$6.1116.7$0.507,621.60.0-0.0-0.0-4,177.8

Jul-023,201.6$1.75721.9$0.9711.1$0.0132,479.53,201.64,355.2$9.20684.7$5.340.3$0.017,621.60.0-0.0-0.0-4,177.8

Aug-023,201.6$1.75722.6$0.9155.4$0.0132,479.53,201.64,355.2$9.20693.8$5.1515.1$2.007,621.60.0-0.0-0.0-4,177.8

Sep-023,201.6$1.75714.0$0.2571.2$0.0132,479.53,201.64,355.2$9.20688.4$4.8324.5$0.017,621.60.0-0.0-0.0-4,177.8

Oct-023,201.6$1.75712.1$0.161.4$-32,479.53,201.64,355.2$9.20699.0$4.7219.2$1.957,621.60.0-0.0-0.0-4,177.8

Nov-023,486.7$0.651,024.3$0.5085.0$0.4034,169.73,486.74,540.0$7.00748.1$6.4061.1$4.108,021.80.0-0.0-0.0-4,256.2

Dec-023,486.7$0.651,219.3$0.2851.4$0.1034,169.73,486.74,540.0$7.00762.7$4.0929.9$2.808,021.80.0-0.0-0.0-4,256.2

Jan-033,486.7$0.651,584.4$0.26189.1$2.1034,169.73,486.74,540.0$7.00787.9$4.0213.3$2.108,021.80.0-0.0-0.0-4,256.2

Feb-033,486.7$0.651,623.1$0.3485.6$0.5034,169.73,486.74,540.0$7.00808.6$3.511.5$3.008,021.80.0-0.0-0.0-4,256.2

Mar-033,486.7$0.651,825.9$0.3258.8$0.2534,169.73,486.74,540.0$7.00799.7$3.9721.9$4.008,021.80.0-0.0-0.0-4,256.2

Apr-033,486.7$0.651,571.5$0.154.2$0.0134,169.73,486.74,540.0$7.00829.7$3.399.1$3.608,021.80.0-0.0-0.0-4,256.2

May-032,889.2$1.671,634.8$1.30101.5$0.2535,303.50.02,501.7$11.223,016.3$10.00110.2$12.368,356.70.06.6$9.412.2$24.000.2$23.004,415.30.0

Jun-032,889.2$1.671,866.0$1.062,148.7$2.3435,303.52,073.22,501.7$11.22683.0$13.782,375.5$11.468,356.70.06.6$9.410.0--------341.9$5.174,415.3341.9

Jul-032,889.2$1.671,249.2$2.012,824.2$2.2835,303.52,274.12,501.7$11.22527.9$11.572,558.0$11.468,356.70.06.6$9.411.0$5.00344.7$5.144,415.3344.7

Aug-032,889.2$1.671,344.1$2.043,096.6$2.2535,303.52,299.32,501.7$11.22567.9$11.562,497.9$11.468,356.70.06.6$9.411.1$5.00441.8$4.034,415.3441.8

Sep-032,889.2$1.671,396.7$1.973,134.1$2.0835,303.52,448.12,501.7$11.22558.1$11.562,499.5$11.468,356.70.06.6$9.410.0--------397.8$4.554,415.3396.2

Oct-032,889.2$1.671,408.4$1.933,253.2$2.0135,303.52,504.82,501.7$11.22638.8$11.552,415.1$11.458,356.70.06.6$9.410.0--------397.8$4.554,415.3396.0

Nov-032,163.2$1.172,128.8$1.156,833.0$1.9435,203.42,566.9475.0$6.55579.3$6.675,029.3$6.988,346.1571.00.0$4.000.0--------114.3$8.144,401.983.7

Dec-032,163.2$1.171,860.1$1.487,203.1$1.7935,203.42,698.6475.0$6.55909.4$6.644,711.0$6.988,346.1571.00.0$4.000.0--------107.5$8.224,401.976.9

Jan-042,163.2$1.172,083.6$1.506,972.2$1.7535,203.42,732.1475.0$6.55968.9$6.644,644.8$6.988,346.1571.00.0$4.000.0--------128.2$7.994,401.997.0

Feb-042,163.2$1.172,475.9$1.586,379.9$1.7335,203.42,747.4475.0$6.552,167.5$6.773,422.4$6.988,346.1571.00.0$4.000.6$7.50202.6$7.084,401.9176.0

Mar-042,163.2$1.172,180.0$1.546,569.8$1.0035,203.43,369.3475.0$6.551,938.0$6.053,841.5$6.988,346.1571.00.0$4.000.6$7.00142.6$7.724,401.9119.9

Apr-042,163.2$1.172,646.7$0.996,987.5$0.8035,203.43,543.8475.0$6.552,047.2$6.003,779.1$6.988,346.1571.00.0$4.000.6$6.85199.0$7.044,401.9179.7

Starting May 2006, Monthly Auction prices and quantities are reported for the upcoming auction month only**Including auction sales from neighboring Control Areas

Attachment VII: November 1999 - October 2017 Installed Capacity Auction Activity

NYCANYCLIG-J Locality

CapabilityMonthly AuctionSpot Market **Minimum RequiredExcess SoldCapabilityMonthly AuctionSpot MarketMinimum RequiredExcess SoldCapabilityMonthlySpot MarketMinimum RequiredExcess SoldCapabilityMonthly AuctionSpot MarketMinimum RequiredExcess Sold

Period* (Strip)**Period* (Strip)Period*AuctionPeriod* (Strip)

(Strip)

MonthMWPriceMWPriceMWPriceMWMWMWPriceMWPriceMWPriceMWMWMW PriceMWPriceMWPriceMWMWMWPriceMWPriceMWPriceMWMW

May-042,441.0$1.682,489.7$1.656,189.1$1.3135,584.53,328.01,245.3$11.152,022.4$11.162,898.3$11.428,444.6214.911.2$8.001.6$8.0097.5$9.834,761.581.2

Jun-042,441.0$1.682,133.6$1.486,239.9$1.2735,584.53,355.31,245.3$11.152,532.8$11.292,391.9$11.428,444.6214.911.2$8.0011.2$9.2990.8$9.794,761.584.3

Jul-042,441.0$1.681,756.7$1.296,410.6$1.0435,584.53,518.81,245.3$11.152,705.7$11.292,261.3$11.428,444.6214.911.2$8.0015.9$8.67193.4$8.424,761.5192.9

Aug-042,441.0$1.682,046.5$1.156,544.7$1.1735,584.53,428.11,245.3$11.153,126.1$11.251,854.4$11.428,444.6214.911.2$8.0016.4$8.05213.1$8.164,761.5213.1

Sep-042,441.0$1.682,258.8$1.166,456.2$1.0735,584.53,499.61,245.3$11.153,272.4$11.251,798.6$11.428,444.6214.911.2$8.0016.2$8.06214.2$8.154,761.5214.2

Oct-042,441.0$1.682,460.8$1.186,633.9$1.1235,584.53,465.61,245.3$11.152,771.9$11.212,336.3$11.428,444.6214.911.2$8.0016.2$8.06214.2$8.154,761.5214.2

Nov-043,050.7$0.602,344.4$0.706,730.6$0.7035,515.93,759.32,249.4$6.681,253.8$6.963,137.5$7.128,469.5705.913.9$4.0010.9$4.00358.2$6.344,736.0357.7

Dec-043,050.7$0.603,058.4$0.696,011.5$0.6135,515.93,823.52,249.4$6.681,606.0$7.072,758.3$7.128,469.5705.913.9$4.009.0$4.33368.5$6.214,736.0367.6

Jan-053,050.7$0.602,945.8$0.595,928.6$0.2735,515.94,064.82,249.4$6.682,433.6$7.031,919.3$7.128,469.5705.913.9$4.009.0$3.81372.1$6.164,736.0371.4

Feb-053,050.7$0.602,769.6$0.496,256.2$0.2535,515.94,082.22,249.4$6.682,596.5$7.031,761.5$7.128,469.5705.913.9$4.007.6$3.68373.3$6.144,736.0372.8

Mar-053,050.7$0.602,890.9$0.456,025.4$0.4135,515.93,966.22,249.4$6.682,671.8$7.031,784.0$7.128,469.5705.913.9$4.007.0$3.54371.9$6.164,736.0371.9

Apr-053,050.7$0.602,891.5$0.486,241.1$0.2735,515.94,064.82,249.4$6.682,611.4$7.031,851.9$7.128,469.5705.913.9$4.007.0$3.54367.4$6.234,736.0365.8

May-052,624.6$0.751,630.0$0.756,975.7$2.0035,799.23,110.82,547.2$11.681,035.2$11.862,547.1$12.038,526.8284.010.6$8.002.7$8.0085.5$12.154,904.985.4

Jun-052,624.6$0.751,752.9$1.406,306.6$1.9635,799.23,135.22,547.2$11.682,657.9$11.80974.2$11.968,526.8291.310.6$8.002.0$8.50100.4$11.964,904.997.8

Jul-052,624.6$0.754,077.8$1.295,073.3$1.0035,799.23,703.42,547.2$11.682,742.6$11.82992.5$11.958,526.8292.510.6$8.004.3$9.00195.3$10.484,904.9195.0

Aug-052,624.6$0.753,819.1$0.815,147.3$1.0035,799.23,703.42,547.2$11.682,689.7$11.821,134.8$11.868,526.8301.610.6$8.004.6$8.50222.5$10.064,904.9222.5

Sep-052,624.6$0.753,412.5$0.815,303.5$1.4535,799.23,436.72,547.2$11.682,842.0$11.821,086.6$11.708,526.8318.210.6$8.004.6$8.61233.0$9.904,904.9233.0

Oct-052,624.6$0.753,861.2$1.035,142.0$1.2535,799.23,555.22,547.2$11.682,644.5$11.821,238.1$11.868,526.8301.610.6$8.004.6$8.71260.0$9.494,904.9260.0

Nov-052,987.1$0.622,676.1$0.676,661.9$0.8535,761.53,789.01,846.4$5.11943.9$6.393,865.4$6.558,569.2854.315.0$0.6810.0$5.00330.5$8.374,962.4330.5

Dec-052,987.1$0.623,466.7$0.686,306.0$0.6535,761.53,907.21,846.4$5.112,130.4$6.442,674.7$6.558,569.2854.315.0$0.6810.1$4.99344.5$8.164,962.4344.5

Jan-062,987.1$0.623,966.1$0.635,625.3$2.0135,761.53,102.51,846.4$5.112,558.2$6.212,116.6$6.558,569.2854.315.0$0.6810.0$5.00288.1$9.004,962.4288.1

Feb-062,987.1$0.623,379.8$1.016,432.7$1.6735,761.53,305.21,846.4$5.113,162.5$5.782,037.4$6.558,569.2854.315.0$0.6810.0$5.00343.1$8.184,962.4343.1

Mar-062,987.1$0.625,214.9$0.585,234.1$0.5735,761.53,954.51,846.4$5.112,704.7$5.782,031.7$6.558,569.2854.315.0$0.6810.0$5.00350.8$8.074,962.4350.8

Apr-062,987.1$0.624,899.7$0.515,357.5$0.4035,761.54,055.01,846.4$5.113,237.1$5.881,540.4$6.558,569.2854.315.0$0.6810.0$5.00346.1$8.144,962.4346.1

May-06 *3,014.5$1.442,196.7$1.646,936.8$3.2537,154.22,526.42,186.7$12.351,422.7$12.432,209.8$12.718,798.1255.94.0$6.509.0$6.50166.8$11.155,110.3165.0

Jun-063,014.5$1.442,747.7$2.596,163.0$3.1237,154.22,601.62,186.7$12.351,088.8$12.442,165.3$12.718,798.1255.94.0$6.502.3$7.50469.3$6.765,110.3462.5

Jul-063,014.5$1.442,914.1$2.945,901.1$3.3337,154.22,481.42,186.7$12.351,021.0$12.501,909.6$12.718,798.1255.94.0$6.503.0$7.00483.0$6.525,110.3478.8

Aug-063,014.5$1.443,447.6$3.305,488.5$3.0037,154.22,675.12,186.7$12.35930.5$12.601,870.7$12.718,798.1255.94.0$6.503.0$6.75497.2$6.315,110.3493.0

Sep-063,014.5$1.444,041.3$3.005,087.8$2.8037,154.22,295.32,186.7$12.35847.6$12.631,953.5$12.718,798.1255.94.0$6.504.6$6.50503.4$6.195,110.3500.8

Oct-063,014.5$1.444,258.0$2.755,368.3$2.7737,154.22,814.82,186.7$12.35818.3$12.702,316.7$12.718,798.1255.94.0$6.507.2$6.00513.6$6.025,110.3512.6

Nov-063,167.7$2.503,170.9$1.757,454.7$1.5037,319.23,577.83,298.4$5.671,023.5$5.802,057.8$5.848,831.5974.81.5$3.509.6$3.75672.0$3.665,072.2669.4

Dec-063,167.7$2.502,475.7$2.257,841.7$2.1837,319.23,170.53,298.4$5.671,015.1$5.842,018.8$5.848,831.5974.81.5$3.5011.0$3.50670.6$3.655,072.2669.7

Jan-073,167.7$2.502,756.5$2.457,780.6$2.7137,319.22,853.43,298.4$5.671,064.4$5.841,973.8$5.848,831.5974.81.5$3.5013.0$3.50673.0$3.605,072.2672.9

Feb-073,167.7$2.503,308.7$2.607,029.1$2.6737,319.22,876.63,298.4$5.67954.8$5.842,144.0$5.848,831.5974.81.5$3.5013.0$3.50672.3$3.615,072.2672.3

Mar-073,167.7$2.504,699.7$1.745,932.2$1.3437,319.23,673.83,298.4$5.67922.4$5.842,008.8$5.848,831.5974.81.5$3.5013.0$3.50672.3$3.615,072.2672.3

Apr-073,167.7$2.504,653.5$1.305,912.0$1.1037,319.23,817.93,298.4$5.67990.0$5.841,971.6$5.848,831.5974.81.5$3.5013.0$3.30672.3$3.615,072.2672.3

May-073,196.6$2.252,610.6$2.406,283.6$3.1637,228.32,618.71,894.0$12.371,099.1$12.343,125.4$12.729,058.3281.12.2$3.753.0$3.75450.3$7.255,056.3450.2

Jun-073,196.6$2.252,748.0$2.905,876.5$3.3937,228.32,485.61,894.0$12.371,194.4$12.372,951.5$12.729,058.3281.12.2$3.753.0$5.50353.1$8.785,056.3353.1

Jul-073,196.6$2.252,849.9$3.155,749.7$3.5237,228.32,407.61,894.0$12.371,088.3$12.373,073.0$12.729,058.3281.12.2$3.750.0$0.00451.5$7.235,056.3451.4

Aug-073,196.6$2.253,136.7$3.205,334.6$3.4337,228.32,462.41,894.0$12.371,092.6$12.373,153.8$12.729,058.3281.12.2$3.751.0$5.50454.0$7.225,056.3452.0

Sep-073,196.6$2.253,694.8$3.155,513.6$3.1437,228.32,631.61,894.0$12.371,161.0$12.373,037.9$12.729,058.3281.12.2$3.751.3$5.50455.6$7.175,056.3455.5

Oct-073,196.6$2.253,943.4$3.005,503.1$3.0337,228.32,698.21,894.0$12.371,251.1$12.372,942.8$12.729,058.3281.12.2$3.751.4$5.50455.7$7.175,056.3455.7

Nov-073,064.4$1.912,586.1$1.909,045.5$1.6036,819.23,503.7908.2$5.321,393.5$5.614,438.1$5.778,870.81,009.50.0$0.002.0$3.50631.5$4.314,972.5630.6

Dec-073,064.4$1.912,743.1$1.998,009.1$2.2236,819.23,149.2908.2$5.321,532.1$5.614,067.3$5.778,870.81,009.50.0$0.000.0$0.00635.9$4.274,972.5633.0

Jan-083,064.4$1.913,753.2$2.407,053.4$3.4036,819.22,477.3908.2$5.321,149.7$5.594,662.5$5.778,870.81,009.50.0$0.001.9$3.70640.3$4.204,972.5637.4

Feb-083,064.4$1.913,065.0$3.006,848.0$3.1836,819.22,602.7908.2$5.321,342.9$5.594,442.2$5.778,870.81,009.50.0$0.007.2$3.00645.1$4.074,972.5645.1

Mar-083,064.4$1.914,215.1$1.508,288.3$1.0536,819.23,818.1908.2$5.321,573.3$3.603,348.7$1.058,870.81,494.90.0$0.002.8$2.10648.5$4.024,972.5648.5

Apr-083,064.4$1.914,308.8$1.057,759.5$0.7536,819.23,989.6908.2$5.321,245.5$1.052,964.9$0.758,870.81,591.60.0$0.002.8$2.10648.8$4.014,972.5648.8

May-082,994.7$2.671,851.8$2.808,294.8$2.6036,632.53,080.6494.9$6.50903.4$6.524,987.2$5.538,910.6985.90.0$2.8021.8$2.80652.1$2.604,684.9650.8

Jun-082,994.7$2.672,460.9$2.897,684.7$2.9436,632.52,909.9494.9$6.501,620.2$5.403,745.8$6.038,910.6930.10.0$2.80110.5$2.89644.9$2.944,684.9583.3

Jul-082,994.7$2.671,972.8$3.008,324.1$2.8036,632.52,981.6494.9$6.50744.5$6.033,758.3$6.338,910.6896.90.0$2.80128.2$3.00653.4$2.804,684.9650.8

Aug-082,994.7$2.672,542.7$2.897,451.6$2.7036,632.53,030.1494.9$6.501,157.8$6.333,349.2$6.178,910.6914.80.0$2.8087.1$2.89657.4$2.704,684.9656.3

Sep-082,994.7$2.673,494.7$2.706,766.6$2.4536,632.53,156.4494.9$6.501,083.2$5.993,083.4$5.988,910.6935.70.0$2.8013.0$2.70659.4$2.454,684.9658.9

Oct-082,994.7$2.673,526.1$2.406,944.8$1.9336,632.53,418.3494.9$6.50604.4$5.913,230.1$5.838,910.6951.90.0$2.807.9$2.40668.7$1.934,684.9668.7

Attachment VII: November 1999 - October 2017 Installed Capacity Auction Activity

NYCANYCLIG-J Locality

CapabilityMonthly AuctionSpot Market **Minimum RequiredExcess SoldCapabilityMonthly AuctionSpot MarketMinimum RequiredExcess SoldCapabilityMonthlySpot MarketMinimum RequiredExcess SoldCapabilityMonthly AuctionSpot MarketMinimum RequiredExcess Sold

Period* (Strip)**Period* (Strip)Period*AuctionPeriod* (Strip)

(Strip)

MonthMWPriceMWPriceMWPriceMWMWMWPriceMWPriceMWPriceMWMWMW PriceMWPriceMWPriceMWMWMWPriceMWPriceMWPriceMWMW

Nov-082,810.1$1.772,596.0$1.609,114.6$1.0036,492.63,877.51,260.8$2.791,378.2$2.283,974.3$1.529,003.41,447.10.3$1.771.8$1.60772.8$1.004,566.1772.6

Dec-082,810.1$1.772,200.1$1.509,113.9$1.2536,492.63,752.11,260.8$2.79616.1$1.594,186.0$1.259,003.41,558.10.3$1.7710.0$1.50802.4$1.254,566.1802.2

Jan-092,810.1$1.772,987.3$1.508,448.2$3.1936,492.62,779.01,260.8$2.79846.5$1.514,151.0$3.199,003.41,579.90.3$1.77147.9$1.50847.0$3.194,566.1733.9

Feb-092,810.1$1.773,863.7$2.508,250.3$1.7736,492.63,492.11,260.8$2.791,021.1$3.063,729.9$1.779,003.41,592.00.3$1.7766.4$2.50821.1$1.774,566.1820.9

Mar-092,810.1$1.773,674.6$1.108,190.4$0.5036,492.64,128.21,260.8$2.79849.6$1.493,622.8$0.509,003.41,592.00.3$1.7797.0$1.10849.1$0.504,566.1816.9

Apr-092,810.1$1.773,991.3$0.508,257.2$0.3036,492.64,228.61,260.8$2.79588.0$0.753,755.6$0.309,003.41,586.60.3$1.7725.4$0.50821.1$0.304,566.1820.9

May-092,371.1$3.012,500.2$3.018,492.0$2.6136,362.43,216.7436.7$6.75757.9$7.004,976.3$8.728,855.3707.353.3$3.0169.5$3.01414.8$4.714,748.5410.4

Jun-092,371.1$3.013,034.3$3.508,675.3$4.2236,362.42,505.4436.7$6.751,447.7$8.603,854.3$8.658,855.3714.253.3$3.0141.5$3.50415.8$4.654,748.5415.8

Jul-092,371.1$3.013,915.6$4.117,495.4$4.4236,362.42,420.6436.7$6.751,623.8$8.712,930.4$8.478,855.3732.753.3$3.0170.6$4.11404.9$4.774,748.5404.8

Aug-092,371.1$3.014,459.5$4.197,242.4$3.4236,362.42,857.0436.7$6.751,281.0$8.522,960.2$8.458,855.3735.153.3$3.0167.6$4.19717.8$3.424,748.5717.8

Sep-092,371.1$3.014,413.9$3.497,393.3$2.7636,362.43,147.7436.7$6.75795.5$8.403,403.2$7.658,855.3816.453.3$3.0168.2$3.49742.9$2.764,748.5738.9

Oct-092,371.1$3.014,957.6$2.597,087.7$2.2336,362.43,380.5436.7$6.751,095.1$7.622,926.6$7.708,855.3811.153.3$3.0120.4$2.59749.3$2.234,748.5743.1

Nov-093,201.1$1.753,044.6$1.559,111.4$0.5035,785.34,081.4825.2$4.652,274.7$1.943,124.0$1.238,551.61,422.335.0$1.7531.0$1.55843.5$0.504,685.0843.3

Dec-093,201.1$1.753,125.0$1.308,472.6$0.7535,785.33,976.7825.2$4.65498.5$1.683,607.0$0.768,551.61,467.435.0$1.75113.1$1.30875.3$0.754,685.0842.3

Jan-103,201.1$1.753,765.0$1.648,871.7$1.8535,785.33,505.4825.2$4.65485.5$1.784,257.0$1.858,551.61,497.135.0$1.7582.0$1.64843.4$1.854,685.0843.3

Feb-103,201.1$1.753,948.2$2.568,406.4$3.4935,785.32,810.0825.2$4.65506.1$6.404,240.3$7.988,551.6782.035.0$1.7582.3$2.56843.3$3.494,685.0843.3

Mar-103,201.1$1.754,425.9$1.598,211.1$0.8535,785.33,933.4825.2$4.651,152.4$7.493,472.0$7.728,551.6807.335.0$1.7517.5$1.59843.3$0.854,685.0843.3

Apr-103,201.1$1.754,420.5$0.748,399.0$0.6435,785.34,021.8825.2$4.65945.5$7.503,468.4$7.168,551.6860.135.0$1.7579.5$0.74855.4$0.644,685.0843.3

May-102,868.1$2.474,462.0$2.707,827.0$3.5235,045.32,860.21,096.8$12.90335.7$13.334,004.2$13.538,336.0372.026.2$2.4716.8$2.70354.8$5.814,901.0354.0

Jun-102,868.1$2.474,521.8$2.758,863.7$2.1235,045.33,396.51,096.8$12.901,451.5$13.402,571.5$13.138,336.0403.626.2$2.4754.7$2.75829.0$2.125,021.0829.0

Jul-102,868.1$2.474,335.2$2.008,617.7$1.9135,045.33,475.31,096.8$12.90836.2$13.002,797.1$13.058,336.0412.126.2$2.4785.7$2.00816.9$1.915,021.0816.9

Aug-102,868.1$2.473,982.7$1.808,123.1$1.6835,045.33,563.71,096.8$12.90650.2$12.983,025.4$12.978,336.0418.726.2$2.4722.1$1.80851.2$1.685,021.0851.2

Sep-102,868.1$2.474,376.5$1.007,993.5$0.6335,045.33,964.31,096.8$12.90992.0$12.852,799.0$12.508,336.0457.826.2$2.478.4$1.00865.9$0.635,021.0865.9

Oct-102,868.1$2.474,178.9$0.458,165.3$0.4835,045.34,022.91,096.8$12.90882.1$12.452,838.5$12.728,336.0439.226.2$2.4725.7$0.45851.8$0.565,021.0851.8

Nov-102,820.1$0.394,179.3$0.279,383.4$0.0135,832.54,295.91,109.8$4.60829.9$4.754,571.0$4.298,737.51,179.51.2$0.396.1$0.27913.4$0.015,073.8913.3

Dec-102,820.1$0.394,173.1$0.108,433.9$0.5035,832.54,100.21,109.8$4.601,620.7$4.283,389.7$3.668,737.51,237.61.2$0.3917.7$0.10915.8$0.505,073.8913.3

Jan-112,820.1$0.393,272.7$0.659,786.2$0.5035,832.54,100.21,109.8$4.601,154.6$3.663,135.3$3.998,737.51,207.61.2$0.3947.1$0.65913.3$0.505,073.8913.3

Feb-112,820.1$0.393,848.7$0.458,839.8$0.6535,832.54,040.01,109.8$4.60736.7$4.253,516.2$3.578,737.51,245.81.2$0.3976.7$0.45913.3$0.655,073.8913.3

Mar-112,820.1$0.394,111.8$0.158,199.3$0.3035,832.54,180.11,109.8$4.60801.5$4.004,231.1$3.578,737.51,246.01.2$0.3975.9$0.15926.6$0.305,073.8913.3

Apr-112,820.1$0.394,450.5$0.208,448.2$0.1535,832.54,240.01,109.8$4.60800.7$3.823,509.6$3.328,737.51,269.11.2$0.3985.7$0.20918.4$0.155,073.8913.3

May-113,515.9$0.553,416.9$0.607,530.4$0.6534,684.43,911.1726.5$13.541,663.8$13.203,354.4$11.978,832.0462.41.2$0.5560.4$0.60895.3$0.655,051.7895.3

Jun-113,515.9$0.553,475.2$0.607,382.8$0.5534,684.43,948.7726.5$13.541,661.7$12.002,896.2$11.768,832.0482.31.2$0.5560.8$0.60904.5$0.555,051.7904.5

Jul-113,515.9$0.553,769.6$0.507,562.7$0.1534,684.44,104.2726.5$13.541,254.1$11.843,301.5$5.768,832.01,046.91.2$0.5535.6$0.50906.1$0.155,051.7904.5

Aug-113,515.9$0.553,922.3$0.167,786.3$0.0534,684.44,142.8726.5$13.54834.6$9.503,361.6$5.838,832.01,040.81.2$0.5532.5$0.16910.8$0.055,051.7908.3

Sep-113,515.9$0.553,832.0$0.107,936.4$0.1834,684.44,093.1726.5$13.54691.3$6.993,680.6$5.718,832.01,052.31.2$0.5558.5$0.10892.1$0.205,051.7890.0

Oct-113,515.9$0.554,200.8$0.107,384.2$0.1334,684.44,105.9726.5$13.54646.0$6.493,511.6$9.018,832.0883.01.2$0.5561.8$0.10900.9$0.135,051.7900.9

Nov-112,008.0$0.154,091.0$0.129,525.7$0.0634,778.94,147.41,031.2$2.701,089.8$3.004,279.6$0.508,833.01,550.73.6$0.1549.7$0.12900.7$0.064,989.3898.1

Dec-112,008.0$0.154,821.7$0.108,957.9$0.1034,778.94,130.01,031.2$2.70763.1$2.003,767.2$4.688,833.01,222.53.6$0.1548.2$0.10902.3$0.104,989.3898.1

Jan-122,008.0$0.155,072.3$0.159,513.6$0.5034,778.93,956.11,031.2$2.70647.3$4.003,886.5$4.918,833.01,205.03.6$0.1529.1$0.15923.7$0.504,989.3898.1

Feb-122,008.0$0.154,988.6$0.409,232.3$0.1834,778.94,095.21,031.2$2.701,020.3$4.803,172.1$4.878,833.01,208.13.6$0.1524.2$0.40900.4$0.184,989.3898.1

Mar-122,008.0$0.155,033.6$0.088,976.3$0.1034,778.94,130.01,031.2$2.70988.5$4.302,991.7$4.708,833.01,221.03.6$0.150.6$0.08922.2$0.104,989.3898.1

Apr-122,008.0$0.155,323.6$0.109,215.1$0.1034,778.94,130.01,031.2$2.70967.6$4.452,958.9$4.618,833.01,228.53.6$0.156.6$0.10921.4$0.104,989.3898.1

May-122,421.3$1.253,682.7$1.289,279.4$2.9135,076.32,970.8530.8$11.701,335.1$12.303,028.7$17.168,896.9288.82.5$1.4212.9$1.28877.2$2.914,961.1873.5

Jun-122,421.3$1.253,563.1$2.149,626.6$1.9435,076.33,386.1530.8$11.70596.6$15.653,991.5$11.548,896.9718.62.5$1.4213.7$2.14868.2$1.944,961.1868.2

Jul-122,421.3$1.255,070.0$1.458,508.7$1.9835,076.33,367.3530.8$11.701,074.6$11.853,397.6$10.958,896.9763.72.5$1.424.5$1.45609.3$3.564,961.1608.7

Aug-122,421.3$1.255,185.9$2.018,300.3$1.9035,076.33,401.0530.8$11.70858.5$11.393,234.6$10.648,896.9787.52.5$1.424.5$3.00616.0$3.564,961.1608.5

Sep-122,421.3$1.255,430.8$2.289,157.8$2.4035,076.33,190.1530.8$11.70572.9$10.743,230.1$10.478,896.9800.42.5$1.4213.9$3.50606.8$3.594,961.1606.8

Oct-122,421.3$1.255,783.6$2.387,906.1$2.4835,076.33,154.5530.8$11.70699.2$10.522,998.9$10.528,896.9796.72.5$1.4217.0$3.50607.5$3.584,961.1607.0

Nov-121,815.7$0.824,428.8$0.5412,143.0$0.7135,852.63,988.0275.1$4.501,093.6$3.004,579.7$3.369,057.31,364.428.4$2.250.4$0.54877.1$0.714,959.4876.7

Dec-121,815.7$0.824,696.1$1.1010,874.4$1.5035,852.63,636.9275.1$4.501,420.2$4.854,785.4$4.919,057.31,241.128.4$2.250.6$1.10891.8$1.504,959.4891.8

Jan-131,815.7$0.825,452.4$1.9810,063.0$3.4835,852.62,756.2275.1$4.502,202.4$4.893,851.5$4.919,057.31,241.128.4$2.257.7$1.98891.8$3.484,959.4891.8

Feb-131,815.7$0.825,684.1$3.029,372.0$2.6535,852.63,125.2275.1$4.502,398.4$4.943,521.2$4.919,057.31,241.128.4$2.2522.1$3.02892.7$2.654,959.4892.7

Mar-131,815.7$0.826,064.9$2.189,534.1$2.0935,852.63,372.6275.1$4.502,350.1$4.933,641.7$4.919,057.31,241.128.4$2.251.4$2.18892.7$2.094,959.4892.7

Apr-131,815.7$0.826,067.1$1.689,599.9$1.5035,852.63,634.2275.1$4.502,323.2$4.933,840.8$4.919,057.31,241.128.4$2.251.1$1.74892.7$1.504,959.4892.7

May-132,635.9$4.202,898.7$4.518,417.8$5.7635,466.81,817.2953.1$14.80931.1$15.504,065.1$16.299,325.0378.040.5$7.2010.2$6.00342.0$7.205,394.3340.3

Jun-132,635.9$4.203,486.2$5.757,704.8$6.0735,466.81,685.8953.1$14.801,250.1$16.153,796.8$16.459,325.0365.540.5$7.2020.2$5.91340.2$7.205,394.3340.2

Jul-132,635.9$4.203,908.6$5.767,298.2$5.7935,466.81,804.3953.1$14.801,447.0$16.303,553.8$16.109,325.0393.640.5$7.2034.8$6.11341.4$7.185,394.3341.4

Aug-132,635.9$4.204,048.4$5.707,056.5$5.6335,466.81,870.7953.1$14.801,513.6$15.993,533.5$15.809,325.0417.340.5$7.2045.4$6.06350.7$7.085,394.3350.7

Sep-132,635.9$4.204,160.1$5.496,709.4$5.6235,466.81,877.0953.1$14.801,107.0$15.723,923.9$15.669,325.0428.340.5$7.2051.4$5.97354.7$7.035,394.3354.7

Oct-132,635.9$4.204,238.3$5.556,812.1$5.9335,466.81,742.8953.1$14.801,269.8$15.703,790.9$16.119,325.0392.640.5$7.2052.7$6.09348.6$7.105,394.3348.6

Attachment VII: November 1999 - October 2017 Installed Capacity Auction Activity

NYCANYCLIG-J Locality

Period* (S trip)**Period* (S trip)Period*AuctionPeriod* (S trip)

(S trip)

MonthMWPriceMWPriceMWPriceMWMWMWPriceMWPriceMWPriceMWMWMWPriceMWPriceMWPriceMWMWMWPriceMWPriceMWPriceMWMW

Nov-132,157.7$2.583,116.4$2.1511,895.7$2.0635,700.43,401.7431.1$7.54533.0$7.905,503.5$10.019,222.2878.430.6$4.009.4$3.10729.9$2.735,363.6728.9

Dec-132,157.7$2.583,040.5$2.9510,260.2$3.1035,700.42,953.8431.1$7.54946.7$9.904,515.1$9.689,222.2904.030.6$4.0067.7$2.95709.2$3.105,363.6702.4

Jan-142,157.7$2.583,873.3$3.909,173.5$4.5735,700.42,322.5431.1$7.541,273.9$9.604,274.1$9.639,222.2908.130.6$4.0073.6$3.90729.0$4.575,363.6729.0

Feb-142,157.7$2.583,832.5$4.308,922.0$4.2935,700.42,440.5431.1$7.541,524.0$9.523,783.4$9.569,222.2913.530.6$4.0082.3$4.30722.4$4.295,363.6722.1

Mar-142,157.7$2.584,472.5$3.008,925.2$2.8635,700.43,058.5431.1$7.541,749.2$9.493,592.2$9.729,222.2901.030.6$4.0026.8$3.00742.7$2.865,363.6742.7

Apr-142,157.7$2.584,563.7$1.9010,046.8$1.7435,700.43,535.5431.1$7.541,668.5$9.613,489.5$9.759,222.2898.830.6$4.0012.1$2.59745.1$2.555,363.6744.8

May-142,147.9$5.152,467.4$5.506,600.9$6.6835,812.41,345.3655.3$16.24516.9$16.544,645.8$18.839,470.568.410.7$6.3940.5$6.20298.5$6.685,430.5249.0476.1$9.96435.4$10.332,384.8$12.3813,494.981.8

Jun-142,147.9$5.152,995.1$6.606,458.0$6.2135,812.41,549.9655.3$16.241,239.6$18.723,383.6$18.849,470.567.810.7$6.3951.4$6.68290.0$6.445,430.5247.4476.1$9.96996.6$12.241,775.2$12.3513,494.986.0

Jul-142,147.9$5.153,817.3$6.215,920.2$6.1035,812.41,598.6655.3$16.241,608.1$18.713,082.1$18.699,470.581.210.7$6.3961.6$6.40287.8$6.465,430.5245.2476.1$9.961,150.8$12.251,611.1$12.3213,494.990.5

Aug-142,147.9$5.153,830.9$5.956,594.8$5.8035,812.41,734.3655.3$16.241,816.1$18.472,887.8$18.569,470.592.510.7$6.3963.6$6.40281.9$6.475,430.5244.3476.1$9.961,148.7$12.251,643.1$12.2513,494.9101.3

Sep-142,147.9$5.153,849.7$5.756,334.4$5.6035,812.41,819.9655.3$16.241,956.9$18.372,937.9$18.179,470.5125.910.7$6.3966.5$6.40288.7$6.475,430.5244.3476.1$9.961,339.2$12.101,650.9$12.0413,494.9135.3

Oct-142,147.9$5.154,460.5$5.497,060.7$5.3935,812.41,915.8655.3$16.241,955.7$18.193,051.0$17.949,470.5146.310.7$6.39102.0$6.40275.0$6.515,430.5239.4476.1$9.961,319.7$11.891,813.8$11.6413,494.9197.1

Nov-142,324.7$2.903,417.2$2.2410,141.2$1.4336,505.63,725.51,023.8$8.45930.4$8.694,356.8$8.969,508.6926.945.6$3.0019.9$2.85635.9$2.995,393.5635.9389.5$5.90675.1$6.623,236.9$5.7613,582.31,121.1

Dec-142,324.7$2.903,575.8$2.568,544.1$3.5036,505.62,773.51,023.8$8.451,292.6$8.893,800.2$8.879,508.6934.445.6$3.0019.9$2.95636.2$3.505,393.5636.2389.5$5.90802.8$5.453,275.9$4.7613,582.31,281.0

Jan-152,324.7$2.903,320.2$3.619,299.0$2.4136,505.63,275.51,023.8$8.451,314.3$8.823,754.6$8.809,508.6940.745.6$3.00230.4$3.61613.4$3.205,393.5612.7389.5$5.90607.4$4.443,142.8$3.7613,582.31,438.9

Feb-152,324.7$2.903,641.3$2.608,452.9$3.3636,505.62,837.41,023.8$8.451,477.9$8.743,572.7$8.949,508.6928.345.6$3.0042.7$3.15644.0$3.365,393.5643.2389.5$5.90556.4$3.762,919.2$4.2113,582.31,367.7

Mar-152,324.7$2.904,372.2$1.809,956.8$0.7236,505.64,051.91,023.8$8.451,567.1$8.703,487.4$7.289,508.61,074.045.6$3.0034.4$2.90652.0$2.875,393.5650.0389.5$5.90726.0$3.973,368.3$2.9313,582.31,571.5

Apr-152,324.7$2.904,489.9$0.458,546.3$0.7536,505.64,036.21,023.8$8.451,820.6$7.253,313.8$7.309,508.61,072.145.6$3.0035.1$2.77644.7$2.925,393.5644.7389.5$5.90791.0$2.893,308.7$2.8213,582.31,588.1

May-152,108.4$3.501,977.6$3.968,381.6$4.0735,919.82,533.7548.6$15.50986.5$15.613,992.0$16.049,271.7354.220.0$5.3042.9$5.30339.7$5.785,284.0327.2723.0$8.50227.6$10.502,617.1$10.9313,934.4356.1

Jun-152,108.4$3.502,981.6$4.217,997.7$4.8835,919.82,178.1548.6$15.501,648.1$15.663,369.2$15.419,271.7405.820.0$5.3056.7$5.74328.1$5.775,284.0328.1723.0$8.50462.8$10.742,351.8$10.5613,934.4413.6

Jul-152,108.4$3.502,847.4$4.708,227.6$3.9835,919.82,570.7548.6$15.501,822.0$15.353,206.2$15.269,271.7418.020.0$5.3057.4$5.67328.7$5.775,284.0328.7723.0$8.50445.0$10.342,756.6$8.3613,934.4762.7

Aug-152,108.4$3.503,036.0$3.918,611.2$3.5835,919.82,744.9548.6$15.501,781.3$15.403,321.0$15.329,271.7413.520.0$5.3057.4$5.67327.8$5.775,284.0327.8723.0$8.501,061.0$8.342,078.7$8.3213,934.4769.1

Sep-152,108.4$3.503,410.3$3.508,650.2$3.4835,919.82,792.5548.6$15.501,759.2$15.363,542.6$15.269,271.7418.020.0$5.3057.4$5.74344.7$5.625,284.0344.7723.0$8.501,045.2$8.362,077.8$8.2713,934.4776.9

Oct-152,108.4$3.503,392.1$3.098,218.0$2.9635,919.83,017.9548.6$15.501,794.5$15.323,509.4$15.019,271.7438.620.0$5.3060.4$5.60345.7$5.615,284.0345.7723.0$8.501,100.3$8.392,100.9$8.1313,934.4799.5

Nov-151,806.5$1.252,404.5$0.6611,055.6$0.4635,715.54,087.3631.2$6.67996.1$6.654,166.1$6.368,916.11,122.912.0$1.6434.2$1.55866.1$1.825,215.8747.0400.5$3.73434.4$3.783,872.5$3.4613,538.11,512.3

Dec-151,806.5$1.252,994.1$1.2510,170.9$1.2835,715.53,731.2631.2$6.67958.0$6.404,203.8$6.298,916.11,128.012.0$1.6463.6$1.80764.9$1.855,215.8743.9400.5$3.73578.5$3.473,678.2$3.4813,538.11,509.3

Jan-161,806.5$1.252,969.7$1.6510,663.8$1.3735,715.53,694.4631.2$6.671,088.6$6.244,187.9$5.858,916.11,161.512.0$1.6475.4$1.80776.0$1.555,215.8776.0400.5$3.73698.8$3.443,413.8$3.1613,538.11,557.4

Feb-161,806.5$1.252,968.2$1.3410,383.8$1.4635,715.53,655.7631.2$6.671,122.1$6.104,100.1$5.848,916.11,162.312.0$1.6474.9$1.50777.4$1.535,215.8777.4400.5$3.73794.6$3.203,322.5$3.1513,538.11,558.4

Mar-161,806.5$1.253,201.7$0.6010,933.4$0.5435,715.54,052.7631.2$6.671,042.2$6.044,220.6$5.818,916.11,164.312.0$1.6474.4$1.50783.1$1.525,215.8778.6400.5$3.73820.1$3.163,337.5$3.1413,538.11,560.7

Apr-161,806.5$1.253,154.5$0.4010,780.6$0.5835,715.54,037.0631.2$6.671,063.1$5.954,189.5$5.658,916.11,176.212.0$1.6470.4$1.40775.3$1.605,215.8771.0400.5$3.73832.0$3.163,365.1$3.0313,538.11,576.7

May-161,823.9$3.622,607.6$3.838,971.6$5.2735,429.82,058.0581.0$10.99800.8$11.154,091.6$12.418,589.0650.030.0$4.1531.3$4.00489.2$5.275,207.2480.3375.5$8.25608.8$8.402,837.6$9.3613,514.5649.4

Jun-161,823.9$3.622,887.1$5.159,078.1$4.8935,429.82,214.7581.0$10.991,024.2$12.383,986.1$12.298,589.0658.530.0$4.15188.8$5.15456.8$4.895,207.2445.5375.5$8.25917.0$9.362,548.6$9.2813,514.5661.4

Jul-161,823.9$3.623,373.7$4.709,316.6$4.2735,429.82,471.4581.0$10.991,172.0$12.273,731.5$12.228,589.0663.630.0$4.1540.3$4.75482.5$4.375,207.2479.9375.5$8.25890.2$9.272,397.2$9.2513,514.5665.1

Aug-161,823.9$3.623,330.1$4.159,752.3$3.6435,429.82,736.0581.0$10.991,217.5$12.183,714.0$12.218,589.0664.430.0$4.1536.3$4.35477.0$4.425,207.2474.1375.5$8.25842.1$9.252,427.8$9.2313,514.5668.6

Sep-161,823.9$3.623,434.3$3.419,949.6$3.3235,429.82,870.0581.0$10.991,230.6$12.143,661.4$12.198,589.0666.030.0$4.1597.1$4.20477.9$4.465,207.2470.3375.5$8.25807.1$9.143,938.0$9.1513,514.5679.7

Oct-161,823.9$3.623,605.8$2.8410,128.3$3.1235,429.82,952.9581.0$10.991,155.4$12.153,905.6$12.148,589.0669.230.0$4.1544.9$4.19486.7$4.345,207.2483.0375.5$8.25775.2$9.102,729.2$9.1613,514.5678.5

Nov-161,624.4$0.752,384.7$0.4911,961.3$0.3536,354.84,208.8633.9$3.50590.7$3.505,218.9$3.698,977.31,456.430.0$1.2510.0$0.50958.8$0.355,258.3927.5230.6$3.50201.5$3.504,316.5$3.6913,827.11,506.1

Dec-161,624.4$0.752,504.7$0.8011,793.8$0.5536,354.84,123.1633.9$3.50750.5$3.655,161.9$3.638,977.31,458.730.0$1.2542.2$0.81937.4$0.555,258.3933.6230.6$3.50403.5$3.454,101.3$3.6313,827.11,514.8

Jan-171,624.4$0.753,413.7$0.8511,767.5$0.3236,354.84,223.8633.9$3.50889.0$3.594,883.5$3.538,977.31,470.030.0$1.2541.7$0.97938.6$0.325,258.3934.7230.6$3.50536.6$3.504,293.0$3.5313,827.11,530.4

Feb-171,624.4$0.753,020.0$0.3911,572.2$0.5436,354.84,125.8633.9$3.50994.6$3.504,754.8$3.478,977.31,470.030.0$1.2547.7$0.60936.5$0.545,258.3932.1230.6$3.50574.8$3.404,281.9$3.4713,827.11,539.1

Mar-171,624.4$0.752,725.1$0.2011,693.4$0.7136,354.84,049.2633.9$3.50982.5$3.464,796.4$3.308,977.31,499.830.0$1.25127.5$0.20933.7$0.715,258.3896.6230.6$3.50600.1$3.144,278.5$3.3013,827.11,565.0

Apr-171,624.4$0.752,689.9$0.2512,720.6$0.3536,354.84,209.1633.9$3.501,016.3$3.244,826.0$3.258,977.31,500.330.0$1.2579.4$0.30931.6$0.355,258.3929.2230.6$3.50520.7$3.244,585.1$3.2513,827.11,572.8

May-172,235.7$3.002,405.4$3.159,864.2$1.7235,512.83,529.2616.4$11.71594.0$11.834,562.6$10.579,095.4747.978.3$5.7930.3$5.75485.0$6.715,302.5478.7503.1$10.50361.4$10.503,218.6$10.2813,621.8730.8

Jun-172,235.7$3.002,895.2$2.418,775.0$3.8935,512.82,604.4616.4$11.71717.3$10.555,389.7$10.249,095.4776.078.3$5.7933.3$6.50485.9$6.695,302.5480.3503.1$10.50392.9$10.253,227.8$10.0113,621.8765.4

Jul-172,235.7$3.002,956.4$3.1510,314.2$2.2635,512.83,299.0616.4$11.71797.5$10.254,452.4$9.869,095.4807.378.3$5.7930.9$6.55486.1$6.695,302.5480.2503.1$10.50535.5$9.943,489.0$9.7513,621.8798.4

Aug-172,235.7$3.003,375.5$2.2410,152.7$2.1835,512.83,331.5616.4$11.71954.1$9.904,359.9$9.859,095.4808.778.3$5.7960.8$6.68486.8$6.675,302.5482.0503.1$10.50571.1$9.733,473.6$9.6913,621.8806.0

Sep-172,235.7$3.003,640.9$2.0910,006.4$2.1835,512.83,332.7616.4$11.711,067.7$9.854,314.5$10.199,095.4779.578.3$5.7956.9$6.55492.5$6.595,302.5487.6503.1$10.50631.1$9.673,452.7$9.9013,621.8779.2

Oct-172,235.7$3.003,689.6$1.8510,333.9$1.8435,512.83,476.9616.4$11.711,094.8$9.904,276.0$9.559,095.4834.178.3$5.7956.9$6.43491.8$6.605,302.5486.9503.1$10.50620.5$9.683,530.9$9.4713,621.8834.3