August 4, 2017

By Electronic Delivery

Honorable Kimberly D. Bose, Secretary Federal Energy Regulatory Commission 888 First Street, NE

Washington, DC 20426

Re: New York Independent System Operator, Inc.’s Proposed Tariff

Amendments to Open Access Transmission Tariff Rate Schedule 1 to Remove the Bunce Creek PARs Cost Recovery Mechanism;
Docket No. ER17-___-000

Dear Secretary Bose:

The New York Independent System Operator, Inc. (“NYISO”) submits this filing

pursuant to Section 205 of the Federal Power Act1 to propose amendments to Rate Schedule 1 of
the NYISO Open Access Transmission Tariff (“OATT”). The proposed amendments remove the
language that was added in 2012 to permit the NYISO to recover from its Transmission
Customers2 payments that it made to the Midcontinent Independent System Operator, Inc.
(“MISO”) for charges assessed by the MISO for International Transmission Company’s
(“ITC’s”) replacement Bunce Creek phase angle regulators (“PARs”). Based on the Federal
Energy Regulatory Commission’s (“Commission’s”) September 2016 Order,3 the MISO no
longer assesses charges to the NYISO for the Bunce Creek PARs. Since September 2016, the
MISO has refunded all of the payments that were made subject to refund back to the NYISO and
the NYISO has, in turn, refunded all of the money it received from MISO back to its
Transmission Customers.

1 16 U.S.C. §824d.

2 Capitalized terms not otherwise defined herein shall have the meaning specified Section 1 of the Open Access Transmission Tariff (“OATT”).

3 Midwest Independent Transmission System Operator, Inc., 156 FERC ¶ 61,202 (2016).

Honorable Kimberly D. Bose August 4, 2017

Page 2

I.Background and Justification

In 2012, the Commission accepted NYISO OATT Rate Schedule 1 revisions to permit
the NYISO to recover from its Transmission Customers payments that the NYISO made to the
MISO for ITC’s replacement Bunce Creek PARs.4 The OATT revisions required the NYISO to
include the Bunce Creek PARs charges as NonISOFacilitiesCosts in the allocation formulae set
forth in Sections 6.1.6 of Rate Schedule 1. When the NYISO submitted the OATT revisions to
the Commission in 2012, the NYISO and New York Transmission Owners were vigorously

contesting the propriety, justness and reasonableness of MISO’s and ITC’s Bunce Creek PARs
charges in Docket No. ER11-1844. Given the contested nature of the charges that NYISO was
proposing to recover from its Transmission Customers, the 2012 OATT revisions also specified
how any Commission-ordered refunds would be redistributed to NYISO Transmission
Customers. In general, refunds would be made to NYISO Transmission Customers that paid
Bunce Creek PARs-related charges in proportion to their prior payments. The NYISO’s refund
mechanism did not require the NYISO to reopen closed bills to process and allocate refunds to
its Transmission Customers.

In September 2016, the Commission issued an order concluding that MISO and ITC did not demonstrate that the Bunce Creek PARs cost allocation to NYISO and PJM was just and reasonable (“2016 Order”).5 The order directed MISO to refund to NYISO the funds that
NYISO had previously paid to MISO for the Bunce Creek PARs.6 NYISO received the refund from MISO in October of 2016 and paid the entire refund to its Transmission Customers in accordance with Section 6.1.6 of Rate Schedule 1. The total amount refunded was
approximately $17.6M (i.e., $16.3M plus approximately $1.3M in interest).

The final monthly invoice that could have included outstanding refunds to NYISO

Transmission Customers related to the Bunce Creek PARs was issued on May 5, 2017. At this time, there are no outstanding refunds for the NYISO to issue, or open monthly invoices for
NYISO Transmission Customers to challenge, that include charges or refunds related to the
Bunce Creek PARs.

II.Documents Submitted

1.This filing letter;

2.A clean version of the proposed revisions to the NYISO’s OATT (“Attachment I”);

and

4 New York Independent System Operator, Inc., Docket No. ER12-2260-000 (unpublished letter order issued August 28, 2012); New York Independent System Operator, Inc.’s Proposed Tariff Amendments to Permit Recovery of
Charges for International Transmission Company’s Phase Angle Regulators and Request for Retroactive Effective Date, Docket No. ER12-2260-000 (July 18, 2012).

5 Midwest Independent Transmission System Operator, Inc., 156 FERC ¶ 61,202 (2016).

6 Id. at Ordering Paragraph (C).

Honorable Kimberly D. Bose August 4, 2017

Page 3

3.A blacklined version of the proposed revisions to the NYISO’s OATT

(“Attachment II”).

III.Description of Proposed Revisions to Rate Schedule 1

NYISO proposes to modify Rate Schedule 1 of the OATT, Section 6.1.6, to remove the
entire discussion related to charges assessed by MISO for the cost of ITC’s Bunce Creek PARs.
As discussed above, there are no further charges or refunds for the NYISO to pass through to its
Transmission Customers. In accordance with the 2016 Order, MISO no longer assesses charges
to the NYISO for these facilities and the NYISO has refunded all of the money it received to its
transmission customers.

NYISO also proposes one ministerial cross-reference correction to OATT Section 6.1.6 and three ministerial, clarifying revisions to OATT Section 6.1.15.2. The OATT Section

6.1.15.2 revisions correct typographical errors in the Non-Physical FERC Fee recovery formula, including clarification that the Total TCC Settled is the sum of settled Transmission Congestion Contracts for all Transmission Customers.

IV.Effective Date

The NYISO respectfully requests that the Commission accept the proposed OATT

revisions with an effective date of October 3, 2017, which is 60 days after the date of this filing.

V.Stakeholder Approval

The proposed amendments to OATT Rate Schedule 1 were approved unanimously by the NYISO Management Committee on May 31, 2017. The NYISO Board of Directors approved the filing of these proposed revisions on July 18, 2017.

VI. Communications and Correspondence

All communications and service in this proceeding should be directed to:

Robert E. Fernandez, General Counsel

Raymond Stalter, Director, Regulatory Affairs *James H. Sweeney, Senior Attorney

10 Krey Boulevard

Rensselaer, NY 12144
Tel: (518) 356-6000
Fax: (518) 356-7678
rfernandez@nyiso.com
rstalter@nyiso.com
jsweeney@nyiso.com

*Person designated for receipt of service.

Honorable Kimberly D. Bose August 4, 2017

Page 4

VII. Service

The NYISO will send an electronic link to this filing to the official representative of each
of its customers, to each participant on its stakeholder committees, to the New York State Public
Service Commission, and to the New Jersey Board of Public Utilities. In addition, the complete
filing will be posted on the NYISO’s website at www.nyiso.com.

VIII. Conclusion

The New York Independent System Operator, Inc. respectfully requests that the

Commission accept for filing the proposed OATT revisions that are attached hereto with an effective date of October 3, 2017.

Respectfully submitted,

/s/ James H. Sweeney

James H. Sweeney
Senior Attorney

New York Independent System Operator, Inc.

cc:Michael Bardee

Anna Cochrane
Jette Gebhart
Kurt Longo

David Morenoff
Daniel Nowak
Larry Parkinson

J. Arnold Quinn
Douglas Roe

Kathleen Schnorf Gary Will

6.1Schedule 1 - ISO Annual Budget Charge and Other Non-Budget Charges and

Payments

6.1.1Introduction

The ISO shall bill each Transmission Customer each Billing Period to recover the ISO’s
annual budgeted costs as set forth in Section 6.1.2 of this Rate Schedule 1.
The ISO shall separately bill each Transmission Customer under this Rate Schedule 1 for certain other charges and payments not related to the ISO annual budget charge. Specifically, the ISO shall bill each Transmission Customer on a quarterly basis to recover NERC and NPCC charges and on a Billing Period basis to recover FERC charges as set forth in Sections 6.1.3 and

6.1.15 respectively of this Rate Schedule 1. The ISO shall also bill each Transmission Customer each Billing Period to recover the following costs or allocate the following received payments under this Rate Schedule 1:

(i)bad debt loss charges as set forth in Section 6.1.4;

(ii)Working Capital Fund charges as set forth in Section 6.1.5;

(iii)non-ISO facilities payment charges as set forth in Section 6.1.6;

(iv)charges to recover costs for payments made to Suppliers pursuant to incremental

cost recovery for units that responded to Local Reliability Rules I-R3 and I-R5 as

set forth in Section 6.1.7;

(v)charges to recover and payments to allocate residual costs as set forth in Section

6.1.8;

(vi)charges for Special Case Resources and Curtailment Service Providers called to

meet reliability needs as set forth in Section 6.1.9;

(vii)charges to recover DAMAP costs as set forth in Section 6.1.10;

(viii) charges to recover Import Curtailment Guarantee Payment costs as set forth in
Section 6.1.11;

(ix)charges to recover Bid Production Cost guarantee payment costs as set forth in

Section 6.1.12;

(x)charges to recover and payments to allocate settlements of disputes as set forth in

Section 6.1.13; and

(xi)payments to allocate financial penalties collected by the ISO as set forth in

Section 6.1.14.

Transmission Customers who are retail access customers being served by an LSE shall not pay these charges to the ISO; the LSE shall pay these charges.

6.1.2ISO Annual Budget Charge

The ISO shall charge, and each Transmission Customer shall pay, a charge for the ISO’s
recovery of its annual budgeted costs. The ISO annual budgeted costs that are recoverable
through this Rate Schedule 1 are set forth in Section 6.1.2.1 of this Rate Schedule 1. The ISO
shall calculate the charge for the recovery of these ISO annual budgeted costs from each
Transmission Customer on the basis of its participation in physical market activity as indicated in
Section 6.1.2.2 of this Rate Schedule 1. The ISO shall calculate this charge for each
Transmission Customer on the basis of its participation in non-physical market activity, the
Special Case Resource program, and the Emergency Demand Response program as indicated in
Section 6.1.2.4 of this Rate Schedule 1. The ISO shall use the revenue collected through Section

6.1.2.4 of this Rate Schedule 1 to recover any of its annual budgeted costs for the immediately
preceding calendar year that it has not already recovered under Section 6.1.2.2 of this Rate
Schedule for that year. The ISO shall credit any additional revenue collected through Section

6.1.2.4 of this Rate Schedule 1 for the remainder of the calendar year to each Transmission

Customer on the basis of its physical market activity as indicated in Section 6.1.2.5 of this Rate Schedule 1.

6.1.2.1ISO Annual Budgeted Costs

The ISO annual budgeted costs to be recovered through Section 6.1.2 of this Rate

Schedule 1 include, but are not limited to, the following costs associated with the operation of the NYS Transmission System by the ISO and the administration of the ISO Tariffs and ISO Related Agreements by the ISO:

Processing and implementing requests for Transmission Service including support of

the ISO OASIS node;

 Coordination of Transmission System operation and implementation of necessary

control actions by the ISO and support for these functions;

 Performing centralized security constrained dispatch to optimally re-dispatch the

NYS Power System to mitigate transmission Interface overloads and provide balancing services;

Costs related to the ISO’s administration and operation of the LBMP market and all

other markets administered by the ISO;

Costs related to the ISO’s administration of Control Area Services;

Costs related to the ISO’s administration of the ISO’s Market Power Mitigation

Measures and the ISO’s Market Monitoring Plan;

Costs related to the maintenance of reliability in the NYCA;

Costs related to the provision of Transmission Service;

Preparation of settlement statements;

NYS Transmission System studies, when the costs of the studies are not recoverable

from a Transmission Customer;

Engineering services and operations planning;

Data and voice communications network service coordination;

Metering maintenance and calibration scheduling;

Record keeping and auditing;

Training of ISO personnel;

 Development and maintenance of information, communication and control systems;  Professional services;

 Carrying costs on ISO assets, capital requirements and debts;  Tax expenses, if any;

 Administrative and general expenses;

 Insurance premiums and deductibles related to ISO operations;

 Any indemnification of or by the ISO pursuant to Section 2.11.2 of this ISO OATT or
Section 12.4 of the Services Tariff;

 Regulatory fees; and

 The ISO’s share of the expenses of Northeast Power Coordinating Council, Inc. or its
successor.

6.1.2.2 Calculation of the ISO Annual Budget Charge for Transmission

Customers Participating in Physical Market Activity

The ISO shall charge, and each Transmission Customer that participates in physical market activity shall pay, an ISO annual budget charge each Billing Period as calculated according to the following formula.

Where:

c = Transmission Customer.

P = The relevant Billing Period.

= The amount, in $, of the ISO annual budgeted costs

for which Transmission Customer c is responsible for Billing Period P.

= The sum, in $, of the ISO’s annual budgeted costs for the current

calendar year.

= The Injection Billing Units, in MWh, for Transmission Customer c

in Billing Period P, except for Scheduled Energy Injections at a CTS Enabled Interface with ISO New England resulting from Imports that are not associated with wheels
through New England.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in Billing Period P, except for Scheduled Energy Withdrawals at a CTS

Enabled Interface with ISO New England resulting from Exports that are not associated with wheels through New England.

= The sum, in MWh, of estimated Withdrawal

Billing Units for all Transmission Customers in the current calendar year as determined by the ISO in the summer prior to the current calendar year, except for Scheduled Energy Withdrawals at a CTS Enabled Interface with ISO New England resulting from Exports that are not associated with wheels through New England.

6.1.2.3Review and Modification of the ISO Annual Budget Charge Allocation

Methodology

The current 72%/28% cost allocation methodology between Withdrawal Billing Units
and Injection Billing Units for the ISO annual budget charge shall remain unchanged through at
least December 31, 2016 and shall continue to remain unchanged until such point in time that a
study is conducted and the results of the study warrant changing the 72%/28% cost allocation.
The following provisions prescribe the process and timeline for the review and, if warranted by
the results of a future study, modification of the 72%/28% cost allocation on a going forward
basis:

(i) A vote of the Management Committee will be taken in the third calendar quarter

of 2015 on whether a new study should be conducted during late-2015 and 2016
to allow modification of the 72%/28% cost allocation, if warranted by the results
of the study, to be implemented by January 1, 2017. A positive vote by 58% of
the Management Committee will be required to go forward with the study, but

there will no longer be a “material change” standard as was historically applied to the determination of whether a study should be conducted.

(ii) If the Management Committee vote discussed in (i) above determines that a study

should not be conducted, the 72%/28% cost allocation between Withdrawal

Billing Units and Injection Billing Units shall be extended through at least

December 31, 2017. In the third calendar quarter of 2016, a vote will be taken on
whether a new study should be conducted during late-2016 and 2017 to allow
modification of the percentage allocation, if warranted by the results of the study,
to be implemented by January 1, 2018. Unless a 58% vote of the Management
Committee is registered in favor of declining to go forward with the study, the
study will be conducted.

(iii) If the Management Committee vote in the third calendar quarter of 2016

discussed in (ii) above determines that a study should not be conducted, the

current 72%/28% cost allocation shall remain unchanged until such point in time
as the Management Committee determines that a study shall be conducted and the
results of that study warrant changing the percentage allocation between
Withdrawal Billing Units and Injection Billing Units. If the Management
Committee vote in the third calendar quarter of 2016 discussed in (ii) above
determines that a study should not be conducted, the Management Committee will
revisit the issue of conducting a study annually in the third calendar quarter of
each year using the same voting standard (i.e. the study shall be performed unless
58% of the Management Committee votes not to commission the study) that was

applied to the Management Committee vote in the third calendar quarter of 2016 discussed in (ii) above.

(iv)If, and when, the Management Committee determines a study shall be conducted:

(a)Such study shall be completed, and the results thereof shared with Market

Participants, before the end of the second calendar quarter of the year prior to the date on which a possible change to the then current allocation may become
effective; and

(b) The ISO will present a draft study scope to Market Participants for consideration

and comment before the ISO issues the study scope as part of its Request For

Proposal process to retain a consultant to perform the study. A meeting shall be held with Market Participants to discuss the components (e.g., categories of costs considered, allocation of benefits, unbundling, etc.) that should be included in the draft study scope before the draft is issued by the ISO.

6.1.2.4 Calculation of the ISO Annual Budget Charge for Transmission

Customers Participating in Non-Physical Market Activity, the Special
Case Resource Program, or the Emergency Demand Response Program

6.1.2.4.1 Charge for Transmission Customers Engaging in Virtual Transactions

The ISO shall charge, and each Transmission Customer that has its virtual bids accepted and thereby engages in Virtual Transactions shall pay, a charge for such activity each Billing Period as calculated according to the following formula.

Where:

c = Transmission Customer.

P = The relevant Billing Period.

= The amount, in $, for which Transmission Customer c is responsible for Billing Period P.

VTRate = For calendar year 2012, the applicable rate shall be $0.0871 per cleared MWh
of Virtual Transactions, based on a $2.6 million projected 2012 annual revenue
requirement. For calendar years following 2012, the applicable rate shall be calculated in
accordance with the formula set forth in Section 6.1.2.4.4 of this Rate Schedule 1.

= The total cleared Virtual Transactions, in MWh, for Transmission Customer c in Billing Period P.

6.1.2.4.2 Charge for Transmission Customers Purchasing Transmission
Congestion Contracts

The ISO shall charge, and each Transmission Customer that purchases Transmission

Congestion Contracts - excluding Transmission Congestion Contracts that are created prior to

January 1, 2010 - shall pay, a charge for such activity each Billing Period as calculated according to the following formula.

Where:

c = Transmission Customer.

P = The relevant Billing Period.

= The amount, in $, for which Transmission Customer c is responsible for Billing Period P.

TCCRate = For calendar year 2012, the applicable rate shall be $0.0372 per settled MWh
of Transmission Congestion Contracts, based on a $4.9 million projected 2012 annual
revenue requirement. For calendar years following 2012, the applicable rate shall be
calculated in accordance with the formula set forth in Section 6.1.2.4.4 of this Rate
Schedule 1.

= The total settled Transmission Congestion Contracts, excluding Transmission Congestion Contracts created prior to January 1, 2010, in MWh, for Transmission Customer c in Billing Period P.

6.1.2.4.3 Charge for Transmission Customers Participating in the Special Case
Resource Program or Emergency Demand Response Program

The ISO shall charge, and each Transmission Customer that participates in the ISO’s
Special Case Resources program or its Emergency Demand Response program shall pay, a
charge for such activity each Billing Period as calculated according to the following formula.

Where:

c = Transmission Customer.

P = The relevant Billing Period.

= The amount, in $, for which Transmission Customer c is

responsible for Billing Period P.

= The total Load reduction, in MWh, measured and compensated

during testing or an actual event for Transmission Customer c in Billing Period P.

= The sum, in $, of the ISO’s annual budgeted costs in the current

calendar year.

= The sum, in MWh, of estimated Withdrawal

6.1.2.4.4 Re-setting of Rate for Virtual Transaction and Transmission Congestion
Contracts Related Charges

For each calendar year after calendar year 2012, the ISO shall use the following formula to calculate (i) the rate for the charge to Transmission Customers engaging in Virtual
Transactions as determined in Section 6.1.2.4.1 of this Rate Schedule 1, and (ii) the rate for the charge to Transmission Customers purchasing Transmission Congestion Contracts as determined in Section 6.1.2.4.2 of this Rate Schedule 1.

Where:

ResetRate = For each calendar year after calendar year 2012, this rate will be used for either (i) the VTRate in the formula in Section 6.1.2.4.1 of this Rate Schedule 1, or (ii) the TCCRate in the formula in Section 6.1.2.4.2 of this Rate Schedule 1.

AnnRevRequirement = The product, in $, of (i) the prior year’s annual revenue

requirement for either (A) Virtual Transaction market activity or (B) Transmission

Congestion Contract market activity, and (ii) an escalation factor. The ISO shall

calculate the escalation factor as the percentage change in the ISO budget between (i) the ISO budget for the calendar year two years prior to the current calendar year (“Calendar Year Minus 2”) and (ii) the ISO budget for the calendar year one year prior to the current calendar year (“Calendar Year Minus 1”).

Over/Under Collection = The ISO shall calculate the amount, in $, that it has over or
under collected for the prior year’s annual revenue requirement for either (A) Virtual
Transaction market activity or (B) Transmission Congestion Contract market activity, as
the case may be, as follows: (i) The ISO shall divide the annual revenue requirements
for the applicable market activity for Calendar Year Minus 2 and for Calendar Year
Minus 1 into twelve equal monthly revenue requirements for each of these calendar
years. (ii) The ISO shall then calculate the amount of revenue, in $, that it over or under
collected for each of the months from July of Calendar Year Minus 2 through June of
Calendar Year Minus 1, which shall be calculated as (a) the revenue amount, in $, that
the ISO collected for each month for the applicable market activity, minus (b) the
monthly revenue requirement, in $, for that month as determined above. If the result of
this calculation is positive, then the ISO overcollected for that month. If the result of this
calculation is negative, then the ISO undercollected for that month. (iii) The ISO shall
then calculate the total over or under collection amount, in $, for the period of July of
Calendar Year Minus 2 through June of Calendar Year Minus 1, which shall be equal to

(a) the sum, in $, of the revenue that the ISO overcollected for each month during this

period (i.e., the sum of the positive monthly results determined above), minus (b) the

sum, in $, of the absolute value of the revenue that the ISO undercollected for each month during this period (i.e., the sum of the absolute value of the negative monthly results
determined above).

3YearRollingAvgBillUnits = The ISO shall calculate the three year rolling average of billing units, in MWh, using twelve-month averages of the appropriate billing units for the period between July of the calendar year four years prior to the current calendar year (“Calendar Year Minus 4”) and June of Calendar Year Minus 1.

The annual rate computed through the formula in this Section 6.1.2.4.4 shall be subject to a 25% maximum increase or decrease for each year.

6.1.2.5Credit for Transmission Customers Participating in Physical Market

Activity After Recovery of ISO Annual Budgeted Costs or Actual Costs for the Preceding Year

The ISO shall use the revenue collected each Billing Period pursuant to Section 6.1.2.4 of
this Rate Schedule 1 to recover the lower of: (i) its annual budgeted costs for the immediately
preceding calendar year; or (ii) its actual costs for the immediately preceding calendar year,
which it has not already recovered under Section 6.1.2 of this Rate Schedule for that year. Once
it has recovered its annual budgeted costs or actual costs for the immediately preceding calendar
year, the ISO shall distribute each Billing Period for the remainder of the calendar year any
additional revenue collected pursuant to Section 6.1.2.4 of this Rate Schedule to each
Transmission Customer that participates in physical market activity as calculated according to
the following formula.

Where:

c = Transmission Customer.

P = The relevant Billing Period.

= The amount, in $, that Transmission Customer c will

receive for Billing Period P.

= The sum, in $, of the revenue collected by the ISO for

Billing Period P through the charges to Transmission Customers for non-physical market activity as calculated in Section 6.1.2.4 of this Rate Schedule 1, less the amount the ISO is using to recover the annual budgeted costs or actual costs for the immediately
preceding calendar year that it did not recover 1) under Section 6.1.2.2 of this Rate
Schedule for that year or 2) through NonPhysicalActivityRevenue previously used for this purpose in the current calendar year provided, however,

shall not be less than zero

= The Injection Billing Units, in MWh, for Transmission Customer c

in Billing Period P, except for Scheduled Energy Injections at a CTS Enabled Interface with ISO New England resulting from Imports that are not associated with wheels
through New England.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in Billing Period P, except for Scheduled Energy Withdrawals at a CTS

Enabled Interface with ISO New England resulting from Exports that are not associated with wheels through New England.

= The sum, in MWh, of Injection Billing Units for all

Transmission Customers in Billing Period P, except for Scheduled Energy Injections at a CTS Enabled Interface with ISO New England resulting from Imports that are not
associated with wheels through New England.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in Billing Period P, except for Scheduled Energy Withdrawals at a CTS Enabled Interface with ISO New England resulting from Exports that are not associated with wheels through New England

Following the end of calendar year 2017, the ISO shall review the credits that have been
made to Transmission Customers participating in physical market activity pursuant to this
Section 6.1.2.5 and shall present the results of its review to Market Participants for comment.

6.1.3NERC and NPCC Charges

The ISO receives an invoice from NERC and NPCC (as defined below) on a quarterly basis for the recovery of the upcoming calendar quarter’s costs related to the dues, fees, and related charges of:

(i) the NERC for its service as the Electric Reliability Organization for the United

States (“ERO”), recovered pursuant to FERC Docket Nos. RM05-30-000, RR06-
1-000 and RR06-3-000 and related dockets, and

(ii) the Northeast Power Coordinating Council: Cross-Border Regional Entity, Inc.

(“NPCC”), or its successors, incurred to carry out functions that are delegated by

the NERC and that are related to ERO matters pursuant to Section 215 of the
FPA.

The ISO shall charge on a quarterly basis, and each Transmission Customer taking

service under the ISO Tariffs shall pay, a charge for the recovery of the NERC and NPCC costs in accordance with Section 6.1.3.1 of this Rate Schedule 1.

Notwithstanding any applicable provisions of this ISO OATT or of the ISO Services Tariff, the ISO may supply to NERC the name of any LSE failing to pay any amounts due to NERC and the amounts not paid.

6.1.3.1 Calculation of NERC and NPCC Charges

The ISO shall charge, and each Transmission Customer shall pay, a charge on a quarterly
basis to recover the NERC and NPCC costs invoiced to the NYISO by NERC and NPCC for the
upcoming calendar quarter. This charge shall be calculated according to the following formula.

Where:

c = Transmission Customer.

Q = The relevant calendar quarter, for which the NERC and NPCC costs apply.

= The amount of the NERC and NPCC costs invoiced to the

ISO, in $, for which Transmission Customer c is responsible for calendar quarter Q.

= The NERC and NPCC costs, in $, invoiced to the ISO for

calendar quarter Q.

M = The month in which the ISO charges Transmission Customers to recover NERC and NPCC costs for calendar quarter Q.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in its four-month true-up invoice that is issued with its regular monthly
invoice in month M, except for Withdrawal Billing Units for Wheels Through and
Exports.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in their four-month true-up invoices that are issued with their regular monthly invoices in month M, except for Withdrawal Billing Units for Wheels Through and Exports.

In calculating the Withdrawal Billing Units for this NERC and NPCC charge, the ISO

shall use the LSE bus meter data that have been submitted by the meter authorities for use in the
calculation of the four-month true-up of the Transmission Customer’s monthly invoice pursuant
to Sections 7.4.1.1.2 and 7.4.1.1.3 of the ISO Services Tariff and Sections 2.7.4.2.1(ii) and

2.7.4.2.1(iii) of this ISO OATT. This calculation of the NERC and NPCC charge shall not be subject to correction or adjustment.

6.1.4Bad Debt Loss Charge

The ISO shall charge, and each Transmission Customer shall pay, a charge for the

recovery of bad debt losses in accordance with the methodology established in Attachment U of this ISO OATT.

6.1.5Working Capital Fund Charge

The ISO shall charge, and each Transmission Customer shall pay, a charge for the

collection and maintenance of the Working Capital Fund in accordance with the methodology established in Attachment V of this ISO OATT.

6.1.6Non-ISO Facilities Payment Charge

The ISO shall charge, and each Transmission Customer shall pay, a charge in accordance with Section 6.1.6.5 of this Rate Schedule 1 for the recovery of the costs of the ISO’s monthly payments to the owners of facilities that are needed for the economic and reliable operation of the NYS Transmission System. At present, the ISO makes such payments to:

(i)Consolidated Edison Co. of New York, Inc. for the purchase, installation,

operation, and maintenance of phase angle regulators at the Hopatcong-Ramapo Interconnection between the ISO and PJM Interconnection, LLC (the “Ramapo PARs Charge”), and

(ii) Rochester Gas & Electric Corporation for the installation of a 135 MVAR

Capacitor Bank at Rochester Station 80 on the cross-state 345 kV system.

6.1.6.1 Calculation of the Ramapo PARs Charge

The Ramapo PARs Charge is the Consolidated Edison Co. of New York (“Con Edison”) component of the NonISOFacilitiesCosts defined in Section 6.1.6.5 below. Con Edison shall
calculate the Ramapo PARs Charge using the procedures described in the 1993 PARs Facilities
Agreement that was accepted for filing by FERC in Docket No. ER93-640-000 on May 10, 1993 (the “1993 Agreement”), irrespective of the effectiveness of the 1993 Agreement. The costs Con Edison may include in the Ramapo PARs Charge are limited to the categories of costs that are
eligible for recovery under the 1993 Agreement, and by the rules in this Section.
In order to permit the replacement of the Ramapo 3500 PAR that failed in June of 2016 without further delay, commencing on July 1, 2017 Transmission Customers will begin
reimbursing Con Edison for up to 100% of the costs Con Edison incurred or incurs to purchase
and install a replacement for the 3500 PAR, and up to 100% of the going-forward costs Con
Edison incurs to operate and maintain the 3500 PAR.

Payment Charge for the Installed PAR prior to July 1, 2017. Subject to the foregoing restriction,
in order to permit the continued operation of the Ramapo Installed PAR, commencing on [insert
effective date of tariff revisions] Transmission Customers will reimburse Con Edison for up to
100% of Con Edison’s going-forward cost of purchasing, installing, operating and maintaining
the Installed PAR.

If PJM Interconnection, LLC (“PJM”), on behalf of some or all of its customers, assumes an obligation to pay a portion of the Ramapo PARs Charge, then the obligation of Transmission Customers to pay the Ramapo PARs Charge shall be reduced consistent with the obligation that PJM Interconnection, LLC assumes.

6.1.6.2 Transparency of the Ramapo PARs Charge

The ISO shall post on its web site the itemized monthly bill (for the preceding month) that Con Edison develops and submits to the ISO in accordance with Section 2.4 of the 1993 Agreement. The itemized monthly bill determines the Ramapo PARs Charge.

No later than August 1 of each year Con Edison shall prepare and the ISO shall post on is website an estimate of the monthly costs and expenses associated with the Ramapo PARs for the next calendar year and for each of the four subsequent years.

Con Edison shall maintain books and records related to its calculation of Ramapo PARs Charge, including costs incurred. Such books and records shall be subject to review by any New York Transmission Customer at reasonable intervals during normal business hours.

6.1.6.3 Refund of the Ramapo PARs Charge to Transmission Customers

To the extent Transmission Customers paid more than 50% of the Ramapo PARs Charge for a Billing Period, they shall be eligible to receive a refund if and to the extent Con Edison’s cost recovery exceeds 100% of the Ramapo PARs Charge for that Billing Period.

If PJM, or one or more PJM transmission owners, submit(s) a payment to the ISO

covering Ramapo PARs Charges assessed by Con Edison for a past period that is on or after [insert effective date of tariff revisions] and the conditions set forth in the first paragraph of this Section 6.1.6.3 are satisfied, then appropriate refunds shall be paid to Transmission
Customers in accordance with the rules set forth below.

If PJM or any of the PJM transmission owners submit payments to Con Edison covering
Ramapo PARs Charges assessed by Con Edison on or after July 1, 2017 and the conditions set
forth in the first paragraph of this Section 6.1.6.3 are satisfied, then Con Edison shall refund to
the ISO any amounts it received in excess of 100% of the Ramapo PARs Charge for a Billing
Period and the ISO shall distribute the refund it receives from Con Edison in accordance with the
rules set forth below.

If the ISO receives a refund from Con Edison, or a payment from PJM or from one or
more PJM transmission owners related to the Ramapo PARs Charge, then the ISO shall refund
the amount received to its Transmission Customers as soon as practicable. Refunds shall be
allocated to each Transmission Customer based on its market participation in the Billing Period
during which refunds are issued, using the same load ratio share basis that the ISO uses to
allocate the NonISOFacilitiesCosts charges to Transmission Customers. Interest paid to the ISO
shall be allocated to each Transmission Customer in the same manner as refunds are allocated.

6.1.6.4 Retirement and Replacement of the Ramapo PARs

If either of the Ramapo PARs described in Section 6.1.6.1 fail and are not reparable, or
are retired with the consent of the ISO, then the original cost of the facilities retired shall be
deducted from the gross plant in service and any unrecovered book cost shall be increased by the
cost of removal and reduced by any salvage value, tax benefits, and insurance proceeds. The net

balance shall be billed to the ISO for payment to Con Edison in a lump sum in accordance with
the calculation, transparency, and cost allocation provisions applicable to the Ramapo PARs
Charge.

If either of the Ramapo PARs described in Section 6.1.6.1 are damaged or condemned,
the ISO may direct Con Edison to repair or replace them, provided that: (1) the costs of such
repair or replacement net any insurance proceeds shall be recovered by Con Edison in
accordance with the calculation, transparency, and cost allocation provisions applicable to the
Ramapo PARs Charge; (2) Con Edison shall be the sole party responsible for determining
whether a repair or replacement is in accordance with good utility practice; and (3) the schedule
for any such repair or replacement shall be determined by Con Edison based on reliability
considerations.

6.1.6.5 Calculation of Non-ISO Facilities Payment Charge

6.1.6.5.1 Transmission Customer Charge Based on Withdrawal Billing Units Not
Used to Supply Station Power Under Section 5 of this ISO OATT

The ISO shall charge, and each Transmission Customer shall pay based on its

Withdrawal Billing Units that are not used to supply Station Power as a third-party provider, a non-ISO facilities payment charge for each Billing Period. This charge shall be equal to the sum of the hourly non-ISO facilities payment charges for the Transmission Customer, as calculated according to the following formula, for each hour in the relevant Billing Period.

Where:

c = Transmission Customer.
M = The relevant month.

h = A given hour in the relevant Billing Period in month M. N = Total number of hours h in month M.

-= The amount, in $, for which Transmission

Customer c is responsible for hour h.

= The sum, in $, of the ISO’s bills for month M for the non-

ISO facilities from (i) Consolidated Edison Co. of New York (less the portion, if any, of such bill paid by PJM Interconnection, LLC) and (ii) Rochester Gas and Electric
Corporation.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in hour h, except for the Withdrawal Billing Units to supply Station Power as a third-party provider and except for Scheduled Energy Withdrawals at a CTS Enabled Interface with ISO New England resulting from Exports that are not associated with
wheels through New England.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in hour h, except for the Withdrawal Billing Units to supply

Station Power as third-party providers and except for Scheduled Energy Withdrawals at a CTS Enabled Interface with ISO New England resulting from Exports that are not
associated with wheels through New England.

6.1.6.5.2 Transmission Customer Charge Based on Withdrawal Billing Units to
Supply Station Power Under Section 5 of this ISO OATT.

The ISO shall charge, and each Transmission Customer shall pay based on its

Withdrawal Billing Units used to supply Station Power as a third-party provider, a non-ISO
facilities payment charge for each Billing Period. This charge shall be equal to the sum of the daily non-ISO facilities payment charges for the Transmission Customer, as calculated according to the following formula, for each day in the relevant Billing Period.

Where:

d = A given day in the relevant Billing Period in month M. N = Number of days d in month M.

= The Withdrawal Billing Units, in MWh, of Transmission Customer c

used to supply Station Power as a third-party provider for day d.

The definitions of the remaining variables are identical to the definitions for such

variables set forth in Section 6.1.6.5.1 of this Rate Schedule 1 above, except that the variables in this Section 6.1.6.5.2 shall be determined for day d.

6.1.6.5.3 Non-ISO Facilities Payment Credit

The ISO shall credit each Transmission Customer based on its Withdrawal Billing Units
that are not used to supply Station Power as a third-party provider, an amount of the revenue
collected through the non-ISO facilities payment charge under Section 6.1.6.5.2 of this Rate
Schedule 1 for each Billing Period. This credit shall be equal to the sum of daily payments for
the Transmission Customer, as calculated according to the following formula, for each day in the
relevant Billing Period.

Where:

d = A given day in the relevant Billing Period.

-= The amount, in $, that Transmission

Customer c will receive for day d.

= The sum of non-ISO facilities payment charges, in $, for

all Transmission Customers as calculated in Section 6.1.6.5.2 of this Rate Schedule 1 for day d.

The definitions of the remaining variables are identical to the definitions for such

variables set forth in Section 6.1.6.5.1 of this Rate Schedule 1 above, except that the variables in this Section 6.1.6.5.3 shall be determined for day d.

6.1.7Charge to Recover Payments Made to Suppliers Pursuant to Incremental Cost

Recovery for Units Responding to Local Reliability Rules I-R3 and I-R5

The ISO shall charge, and each Transmission Customer shall pay based on its

Withdrawal Billing Units that are not used to supply Station Power as a third-party provider, a charge for the recovery of the costs of payments to Suppliers pursuant to the incremental cost recovery for units that responded to either (i) Local Reliability Rule I-R3 or (ii) Local Reliability Rule I-R5, as applicable, for each Billing Period. This charge shall be equal to the sum of the daily charges for the Transmission Customer, as calculated according to the following formula, for each day in the relevant Billing Period. The ISO shall perform this calculation separately to recover as applicable either (i) the payment costs related to Local Reliability I-R3, or (ii) the
payment costs related to Local Reliability Rule I-R5.

Where:

c = Transmission Customer.

d = A given day in the relevant Billing Period.

= The amount, in $, for which

Transmission Customer c is responsible for day d.

- The amount, in $, paid in day d to Suppliers pursuant to the incremental cost recovery for units that responded, as applicable, to either (i) Local Reliability Rule I-
R3 in the Consolidated Edison Transmission District or (ii) Local Reliability Rule I-R5 in the LIPA Transmission District.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in day d in either (i) the Consolidated Edison Transmission District (in the

case of Local Reliability Rule I-R3) or (ii) the LIPA Transmission District (in the case of Local Reliability Rule I-R5), except for the Withdrawal Billing Units to supply Station Power as a third-party provider.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in day d in either (i) the Consolidated Edison Transmission

District (in the case of Local Reliability Rule I-R3) or (ii) the LIPA Transmission District

(in the case of Local Reliability Rule I-R5), except for the Withdrawal Billing Units to supply Station Power as third-party providers.

6.1.8Residual Costs Payment/Charge

The ISO’s payments for market transactions by Transmission Customers will not equal
the ISO’s payments to Suppliers for market transactions. Part of the difference consists of Day-
Ahead Congestion Rent. The remainder comprises a residual adjustment, which the ISO shall
calculate and each Transmission Customer shall receive or pay on the basis of its Withdrawal
Billing Units. The most significant component of the residual adjustment is the residual costs
payment or charge calculated in accordance with Section 6.1.8.1 of this Rate Schedule 1.

6.1.8.1 Calculation of Residual Costs Payment/Charge

6.1.8.1.1 Transmission Customers Charge Based on Withdrawal Billing Units Not
Used to Supply Station Power Under Section 5 of this ISO OATT

The ISO shall calculate, and each Transmission Customer shall receive or pay based on
its Withdrawal Billing Units that are not used to supply Station Power as a third-party provider, a
residual costs payment or a residual costs charge for each Billing Period. The payment or charge
for the relevant Billing Period shall be equal to (i) the sum of the hourly residual costs payments
for the Transmission Customer as calculated according to the following formula for each hour in
the relevant Billing Period, minus (ii) the sum of the hourly residual costs charges for the

Transmission Customer as calculated in the following formula for each hour in the relevant

Billing Period. If the result of this determination is positive, the ISO shall pay the Transmission Customer a residual costs payment for the relevant Billing Period. If the result of this
determination is negative, the ISO shall charge the Transmission Customer a residual costs
charge for the relevant Billing Period.

Where:

c = Transmission Customer.

h = A given hour in the relevant Billing Period.

= The amount, in $, for hour h that Transmission

Customer c will receive (if positive) or for which Transmission Customer c is responsible (if negative).

= The Withdrawal Billing Units, in MWh, for Transmission

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in hour h, except for the Withdrawal Billing Units to supply

= The ISO’s receipts, in $, for each hour h from Transmission

Customers that equal the sum of the following components, which could be either positive or negative amounts:

(i) payments of the Energy component and Marginal Losses Component of LBMP

for Energy scheduled in the LBMP Market in hour h in the Day-Ahead Market; (ii) payments of the Energy component, Marginal Losses Component, and
Congestion Component of LBMP for Energy purchased in the Real-Time LBMP
Market for hour h that was not scheduled Day-Ahead;

(iii) payments of the Energy component, Marginal Losses Component, and

Congestion Component of LBMP for Energy by Suppliers that provided less

Energy in the real-time dispatch for hour h than they were scheduled Day-Ahead to provide in hour h for the LBMP Market;

(iv)the Marginal Losses Component of the TUC payments made in accordance with

this ISO OATT for Bilateral Transactions that were scheduled in hour h in the Day-Ahead Market; and

(v) the Marginal Losses Component and Congestion Component of the real-time

TUC payments made in accordance with this ISO OATT for Bilateral

Transactions that were not scheduled in hour h in the Day-Ahead Market.

(vi) the M2M settlement between the ISO and PJM Interconnection, L.L.C. for hour h,

determined in accordance with Section 8 of Schedule D to Attachment CC to this ISO OATT.

= The ISO’s payments, in $, in each hour h to Suppliers that equal the
sum of the following components, which could be either positive or negative amounts:

(i) payments of the Energy component and Marginal Losses Components of LBMP

for Energy to Suppliers that were scheduled to provide in the LBMP Market in hour h in the Day-Ahead Market;

(ii) payments to Suppliers of the Energy component, Marginal Losses Component,

and Congestion Component of LBMP for Energy provided to the ISO in the

Real-Time Dispatch for hour h that those Suppliers were not scheduled to provide Energy in hour h in the Day-Ahead Market;

(iii) payments of the Energy component and Marginal Losses Component of LBMP

for Energy to LSEs that consumed less Energy in the real-time dispatch than those LSEs were scheduled Day-Ahead to consume in hour h; and

(iv) payments of the Marginal Losses Component and Congestion Component of the

real-time TUC to Transmission Customers that reduced their Bilateral Transaction schedules for hour h after the Day-Ahead Market.

6.1.8.1.2 Transmission Customer Charge Based on Withdrawal Billing Units to
Supply Station Power Under Section 5 of this ISO OATT.

The ISO shall calculate, and each Transmission Customer shall receive or pay based on
its Withdrawal Billing Units used to supply Station Power as a third-party provider, a residual
costs payment or a residual costs charge for each Billing Period. The payment or charge for the
relevant Billing Period shall be equal to (i) the sum of the daily residual costs payments for the
Transmission Customer as calculated according to the following formula for each day in the
relevant Billing Period, minus (ii) the sum of the daily residual costs charges for the
Transmission Customer as calculated in the following formula for each day in the relevant
Billing Period. If the result of this determination is positive, the ISO shall pay the Transmission
Customer a residual costs payment for the relevant Billing Period. If the result of this
determination is negative, the ISO shall charge the Transmission Customer a residual costs
charge for the relevant Billing Period.

Where:

d = A given day in the relevant Billing Period.

= The Withdrawal Billing Units, in MWh, of Transmission Customer c

that it used to supply Station Power as a third-party provider for day d.

The definitions of the remaining variables are identical to the definitions for such

variables set forth in Section 6.1.8.1.1 of this Rate Schedule 1 above, except that the variables in this Section 6.1.8.1.2 shall be determined for day d.

6.1.8.1.3 Residual Costs Adjustment

the daily adjustments (positive and negative) for the Transmission Customer, as calculated

according to the following formula, for each day in the relevant Billing Period. If the summed amount is positive for the Billing Period, the ISO shall pay the Transmission Customer the adjustment amount. If the summed amount is negative for the Billing Period, the ISO shall charge the Transmission Customer the adjustment amount.

Where:

d = A given day in the relevant Billing Period.

= The amount, in $, for day d that Transmission

Customer c will receive (if positive) or for which Transmission Customer c is responsible (if negative).

= (i) If Transmission Customers were responsible for a

residual costs charge for day d pursuant to Section 6.1.8.1.2 of this Rate Schedule 1, the (positive) amount, in $, of the costs that the ISO has collected through the residual costs charges for all Transmission Customers for day d. (ii) If Transmission Customers
received a residual costs payment for day d pursuant to Section 6.1.8.1.2 of this Rate Schedule 1, the (negative) amount, in $, of the revenue that the ISO has paid through the residual costs payments to all Transmission Customers for day d.

The definitions of the remaining variables are identical to the definitions for such

variables set forth in Section 6.1.8.1.1 of this Rate Schedule 1 above, except that the variables in this Section 6.1.8.1.3 shall be determined for day d.

6.1.9Recovery of Special Case Resources and Curtailment Services Providers Costs

The ISO shall charge, and each Transmission Customer shall pay, a charge for the

recovery of Special Case Resources and Curtailment Service Providers costs for each Billing Period. This charge shall be equal to the sum of the hourly charges for the Transmission
Customer, as calculated in Sections 6.1.9.1 and 6.1.9.2 of this Rate Schedule 1, for each hour in the relevant Billing Period and, where applicable, for each Subzone.

6.1.9.1Recovery of Costs for Payments for Special Case Resources and

Curtailment Service Providers Called to Meet the Reliability Needs of a

Local System

Pursuant to this Section 6.1.9.1, the ISO shall recover the costs of payments to Special Case Resources and Curtailment Service Providers that were called to meet the reliability needs of a local system. To do so, the ISO shall charge, and each Transmission Customer that serves Load in the Subzone for which the reliability services of the Special Case Resources and
Curtailment Service Providers were called shall pay based on its Withdrawal Billing Units that are not used to supply Station Power as a third-party provider, an hourly charge in accordance with the following formula for each Subzone.

Where:

c = Transmission Customer.

h = A given hour in the relevant Billing Period.

= The amount, in $, for which Transmission

Customer c is responsible for hour h for the relevant Subzone.

= The payments, in $, for hour h in the relevant Subzone made

to Suppliers for Special Case Resources and Curtailment Service Providers called to meet the reliability needs of that Subzone.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in hour h in the relevant Subzone, except for Withdrawal Billing Units for Wheels Through, Exports, and to supply Station Power as a third-party provider.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in hour h in the relevant Subzone, except for Withdrawal Billing
Units for Wheels Through, Exports, and to supply Station Power as third-party providers.

6.1.9.2Recovery of Costs for Payments for Special Case Resources and

Curtailment Service Providers Called to Meet the Reliability Needs of the

NYCA

Pursuant to this Section 6.1.9.2, the ISO shall recover the costs of payments to Special
Case Resources and Curtailment Service Providers called to meet the reliability needs of the
NYCA. To do so, the ISO shall charge, and each Transmission Customer shall pay based on its
Withdrawal Billing Units except for Withdrawal Billing Units for Wheels Through, Exports or
to supply Station Power as a third-party provider, an hourly charge in accordance with the
following formula.

Where:

c = Transmission Customer.

h = A given hour in the relevant Billing Period.

= The amount, in $, for which Transmission

Customer c is responsible for hour h.

= The payments, in $, for hour h made to Suppliers for Special

Case Resources and Curtailment Service Providers called to meet the reliability needs of the NYCA.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in hour h, except for the Withdrawal Billing Units for Wheels Through, Exports or to supply Station Power as a third-party provider.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in hour h, except for the Withdrawal Billing Units for Wheels Through, Exports or to supply Station Power as third-party providers.

6.1.10. Recovery of Day-Ahead Margin Assurance Payment Costs

The ISO shall charge, and each Transmission Customer shall pay, a charge for the

recovery of DAMAP costs for each Billing Period. The charge for the relevant Billing Period

shall be equal to the sum of the charges and credits for the Transmission Customer, as calculated in Sections 6.1.10.1 and 6.1.10.2 of this Rate Schedule 1, for each hour or each day, as
applicable, in the relevant Billing Period and for each Subzone, where applicable.

6.1.10.1 Recovery of Costs of DAMAPs Resulting from Meeting the Reliability
Needs of a Local System

Pursuant to this Section 6.1.10.1, the ISO shall recover the costs for DAMAPs incurred to compensate Resources for meeting the reliability needs of a local system.

6.1.10.1.1 Transmission Customer Charge Based on Withdrawal Billing Units Not
Used to Supply Station Power Under Section 5 of this ISO OATT

The ISO shall charge, and each Transmission Customer that serves Load in the Subzone where the Resource is located shall pay based on its Withdrawal Billing Units that are not used to supply Station Power as a third-party provider, an hourly charge in accordance with the
following formula for each Subzone.

Where:

c = Transmission Customer.

h = A given hour in the relevant Billing Period.

= The amount, in $, for which Transmission

Customer c is responsible for hour h for the relevant Subzone.

= The DAMAP costs, in $, for hour h in the relevant Subzone incurred to compensate Resources meeting the reliability needs of that Subzone.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in hour h in the relevant Subzone, except for Withdrawal Billing Units for Wheels Through, Exports, and to supply Station Power as a third-party provider.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in hour h in the relevant Subzone, except for Withdrawal Billing
Units for Wheels Through, Exports, and to supply Station Power as third-party providers.

6.1.10.1.2 Transmission Customer Charge Based on Withdrawal Billing Units to
Supply Station Power Under Section 5 of this ISO OATT

The ISO shall charge, and each Transmission Customer that serves Load in the Subzone where the Resource is located shall pay based on its Withdrawal Billing Units used to supply
Station Power as a third-party provider, a daily charge in accordance with the following formula for each Subzone.

Where:

d = A given day in the relevant Billing Period.

= The Withdrawal Billing Units, in MWh, of Transmission

Customer c in day d in the relevant Subzone that are used to supply Station Power as a
third-party provider, except for Withdrawal Billing Units for Wheels Through and
Exports.

The definitions of the remaining variables are identical to the definitions for such

variables set forth in Section 6.1.10.1.1 of this Rate Schedule 1 above, except that the variables in this Section 6.1.10.1.2 shall be determined for day d.

6.1.10.1.3 Local Reliability DAMAP Credit

The ISO shall calculate, and each Transmission Customer that serves Load in the

Subzone where the Resource is located shall receive based on its Withdrawal Billing Units that

are not used to supply Station Power as a third-party provider, an amount of the revenue

collected through the charge under Section 6.1.10.1.2 of this Rate Schedule 1. This credit shall
be calculated according to the following formula for each day in the relevant Billing Period.

Where:

d = A given day in the relevant Billing Period.

= The amount, in $, that Transmission Customer c

will receive for day d for the relevant Subzone.

= The sum of charges, in $, for all Transmission Customers in

the relevant Subzone as calculated in Section 6.1.10.1.2 of this Rate Schedule 1 for day d.

The definitions of the remaining variables are identical to the definitions for such

variables set forth in Section 6.1.10.1.1 of this Rate Schedule 1 above, except that the variables in this Section 6.1.10.1.3 shall be determined for day d.

6.1.10.2 Recovery of Costs of All Remaining DAMAPs

Pursuant to this Section 6.1.10.2, the ISO shall recover the costs of all DAMAPs not
recovered through Section 6.1.10.1 of this Rate Schedule 1 from all Transmission Customers.

6.1.10.2.1 Transmission Customer Charge Based on Withdrawal Billing Units Not
Used to Supply Station Power Under Section 5 of this ISO OATT

The ISO shall charge, and each Transmission Customer shall pay based on its

Withdrawal Billing Units that are not used to supply Station Power as a third-party provider, an hourly charge in accordance with the following formula.

Where:

c = Transmission Customer.

h = A given hour in the relevant Billing Period.

= The amount, in $, for which Transmission Customer c

is responsible for hour h.

= The DAMAP costs, in $, for hour h not recovered by the

ISO through Section 6.1.10.1 of this Rate Schedule 1.

= The Withdrawal Billing Units, in MWh, for Transmission

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in hour h, except for the Withdrawal Billing Units to supply

6.1.10.2.2 Transmission Customer Charge Based on Withdrawal Billing Units to
Supply Station Power Under Section 5 of this ISO OATT

The ISO shall charge, and each Transmission Customer shall pay based on its

Withdrawal Billing Units used to supply Station Power as a third-party provider, a daily charge in accordance with the following formula.

Where:

d = A given day in the relevant Billing Period.

= The Withdrawal Billing Units, in MWh, of Transmission Customer c

used to supply Station Power as a third-party provider for day d.

The definitions of the remaining variables are identical to the definitions for such

variables set forth in Section 6.1.10.2.1 of this Rate Schedule 1 above, except that the variables in this Section 6.1.10.2.2 shall be determined for day d.

6.1.10.2.3 Remaining DAMAP Credit

The ISO shall calculate, and each Transmission Customer shall receive based on its

Withdrawal Billing Units that are not used to supply Station Power as a third-party provider, an amount of the revenue collected through the charge under Section 6.1.10.2.2 of this Rate
Schedule 1. This credit shall be calculated according to the following formula for each day in the relevant Billing Period.

Where:

d = A given day in the relevant Billing Period.

= The amount, in $, that Transmission Customer c will

receive for day d.

= The sum of charges, in $, for all Transmission

Customers as calculated in Section 6.1.10.2.2 of this Rate Schedule 1 for day d.

The definitions of the remaining variables are identical to the definitions for such

variables set forth in Section 6.1.10.2.1 of this Rate Schedule 1 above, except that the variables in this Section 6.1.10.2.3 shall be determined for day d.

6.1.11 Recovery of Import Curtailment Guarantee Payment Costs

6.1.11.1 Transmission Customer Charge Based on Withdrawal Billing Units Not
Used to Supply Station Power Under Section 5 of this ISO OATT

The ISO shall charge, and each Transmission Customer shall pay based on its

Withdrawal Billing Units that are not used to supply Station Power as a third-party provider, a
charge each Billing Period to recover the costs of all Import Curtailment Guarantee Payments
paid to Import Suppliers for that Billing Period. The charge for the relevant Billing Period shall
be equal to the sum of the hourly charges for the Transmission Customer, as calculated in
accordance with the following formula, for each hour in the relevant Billing Period.

Where:

c = Transmission Customer.

h = A given hour in the relevant Billing Period.

= The amount, in $, for which

Transmission Customer c is responsible for hour h.

= The costs, in $, for the Import Curtailment Guarantee

Payments to Import Suppliers for hour h.

= The Withdrawal Billing Units, in MWh, for Transmission

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in hour h, except for the Withdrawal Billing Units to supply

6.1.11.2 Transmission Customer Charge Based on Withdrawal Billing Units to
Supply Station Power Under Section 5 of this ISO OATT

The ISO shall charge, and each Transmission Customer shall pay based on its

Withdrawal Billing Units used to supply Station Power as a third-party provider, a charge for each Billing Period to recover the costs of all Import Curtailment Guarantee Payments paid to Import Suppliers for that Billing Period. The charge for the relevant Billing Period shall be
equal to the sum of the daily charges for the Transmission Customer, as calculated in accordance with the following formula, for each day in the relevant Billing Period.

Where:

d = A given day in the relevant Billing Period.

= The Withdrawal Billing Units, in MWh, of Transmission Customer c

used to supply Station Power as a third-party provider for day d.

The definitions of the remaining variables are identical to the definitions for such variables set forth in Section 6.1.11.1 of this Rate Schedule 1 above, except that the variables in this Section 6.1.11.2 shall be determined for day d.

6.1.11.3 Import Curtailment Guarantee Credit

The ISO shall credit each Transmission Customer based on its Withdrawal Billing Units
that are not used to supply Station Power as a third-party provider, an amount of the revenue
collected through the charge under Section 6.1.11.2 of this Rate Schedule 1 above for each
Billing Period. This credit shall be equal to the sum of daily payments for the Transmission
Customer, as calculated according to the following formula, for each day in the relevant Billing
Period.

Where:

d = A given day in the relevant Billing Period.

= The amount, in $, that Transmission

Customer c will receive for day d.

= The sum of charges, in $, for all Transmission Customers as

calculated in Section 6.1.11.2 of this Rate Schedule 1 for day d.

6.1.12Recovery of Bid Production Cost Guarantee Payment and Demand Reduction

Incentive Payment Costs

The ISO shall charge, and each Transmission Customer shall pay, a charge for the

recovery of BPCG and Demand Reduction Incentive Payment costs for each Billing Period. The charge for the relevant Billing Period shall be equal to the sum of the charges and credits for the Transmission Customer, as calculated in Sections 6.1.12.1 through 6.1.12.6 of this Rate Schedule 1, for each day in the relevant Billing Period and for each Subzone, where applicable.

6.1.12.1 Costs of Demand Reduction BPCGs and Demand Reduction Incentive
Payments

After accounting for imbalance charges paid by Demand Reduction Providers, the ISO shall recover the costs associated with Demand Reduction Bid Production Cost guarantee
payments and Demand Reduction Incentive Payments from Transmission Customers pursuant to the methodology established in Attachment R of this ISO OATT.

6.1.12.2 Costs of BPCGs for Additional Generating Units Committed to Meet
Forecast Load

If the sum of all Bilateral Transaction schedules, excluding schedules of Bilateral

Transactions with Trading Hubs as their POWs, and all Day-Ahead Market purchases to serve
Load in the Day-Ahead schedule is less than the ISO’s Day-Ahead forecast of Load, the ISO
may commit Resources in addition to the reserves that it normally maintains to enable it to
respond to contingencies to meet the ISO’s Day-Ahead forecast of Load. The ISO shall recover
a portion of the costs associated with Bid Production Cost guarantee payments for the additional
Resources committed Day-Ahead to meet the Day-Ahead forecast of Load from Transmission
Customers pursuant to the methodology established in Attachment T of this ISO OATT. The
ISO shall recover the residual costs of such Bid Production Cost guarantee payments not

recovered through the methodology in Attachment T of the ISO OATT pursuant to Section

6.1.12.6 of this Rate Schedule 1.

6.1.12.3 Costs of BPCGs Resulting from Meeting the Reliability Needs of a Local
System

Pursuant to this Section 6.1.12.3, the ISO shall recover the costs for Bid Production Cost
guarantee payments incurred to compensate Suppliers for their Resources, other than Special
Case Resources, that are committed or dispatched to meet the reliability needs of a local system.

6.1.12.3.1 Transmission Customer Charge Based on Withdrawal Billing Units Not
Used to Supply Station Power Under Section 5 of this ISO OATT

The ISO shall charge, and each Transmission Customer that serves Load in the Subzone where the Resource is located shall pay based on its Withdrawal Billing Units that are not used to supply Station Power as a third-party provider, a daily charge in accordance with the
following formula for each Subzone.

Where:

c = Transmission Customer.

d = A given day in the relevant Billing Period.

= The amount, in $, for which Transmission

Customer c is responsible for day d for the relevant Subzone.

= The Bid Production Cost guarantee payments, in $, made to Suppliers for Resources for day d in the relevant Subzone arising as a result of meeting the
reliability needs of that Subzone, except for the Bid Production Cost guarantee payments made to Suppliers for Special Case Resources.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in day d in the relevant Subzone, except for Withdrawal Billing Units for
Wheels Through, Exports, and to supply Station Power as a third-party provider.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in day d in the relevant Subzone, except for Withdrawal Billing
Units for Wheels Through, Exports, and to supply Station Power as third-party providers.

6.1.12.3.2 Transmission Customer Charge Based on Withdrawal Billing Units to
Supply Station Power Under Section 5 of this ISO OATT

Where:

= The Withdrawal Billing Units, in MWh, of Transmission

Customer c in day d in the relevant Subzone that are used to supply Station Power as a
third-party provider, except for Withdrawal Billing Units for Wheels Through and
Exports.

The definitions of the remaining variables are identical to the definitions for such variables set forth in Section 6.1.12.3.1 above,

6.1.12.3.3 Local Reliability BPCG Credit

The ISO shall calculate, and each Transmission Customer that serves Load in the

Subzone where the Resource is located shall receive based on its Withdrawal Billing Units that
are not used to supply Station Power as a third-party provider, an amount of the revenue
collected through the charge under Section 6.1.12.3.2 of this Rate Schedule 1. This credit shall
be calculated according to the following formula for each day in the relevant Billing Period.

Where:

= The amount, in $, that Transmission Customer c

will receive for day d for the relevant Subzone.

= The sum of charges, in $, for all Transmission Customers in the

relevant Subzone as calculated in Section 6.1.12.3.2 of this Rate Schedule 1 for day d.

The definitions of the remaining variables are identical to the definitions for such variables set forth in Section 6.1.12.3.1 above.

6.1.12.4 Cost of BPCGs for Special Case Resources Called to Meet the Reliability
Needs of a Local System

Pursuant to this Section 6.1.12.4, the ISO shall recover the costs of Bid Production Cost guarantee payments incurred to compensate Special Case Resources called to meet the reliability needs of a local system. To do so, the ISO shall charge, and each Transmission Customer that serves Load in the Subzone where the Special Case Resource is located shall pay based on its Withdrawal Billing Units that are not used to supply Station Power as a third-party provider, a daily charge in accordance with the following formula for each Subzone.

Where:

c = Transmission Customer.

d = A given day in the relevant Billing Period.

= The amount, in $, for which Transmission

Customer c is responsible for day d for the relevant Subzone.

= The Bid Production Cost guarantee payments, in $, made to Suppliers for Special Case Resources for day d in the relevant Subzone arising as a result of meeting the reliability needs of that Subzone.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in day d in the relevant Subzone, except for Withdrawal Billing Units for
Wheels Through, Exports, and to supply Station Power as a third-party provider.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in day d in the relevant Subzone, except for Withdrawal Billing
Units for Wheels Through, Exports, and to supply Station Power as third-party providers.

6.1.12.5 Cost of BPCG for Special Case Resources Called to Meet the Reliability
Needs of the NYCA

Pursuant to this Section 6.1.12.5, the ISO shall recover the costs for Bid Production Cost
guarantee payments to compensate Special Case Resources called to meet the reliability needs of
the NYCA. To do so, the ISO shall charge, and each Transmission Customer shall pay based on
its Withdrawal Billing Units used except for Withdrawal Billing Units for Wheels Through,
Exports or to supply Station Power as a third-party provider, a daily charge in accordance with
the following formula.

Where:

c = Transmission Customer.

d = A given day in the relevant Billing Period.

= The amount, in $, for which Transmission

Customer c is responsible for day d.

= The Bid Production Cost guarantee payments, in $, made to Suppliers
for Special Case Resources called to meet the reliability needs of the NYCA for day d.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in day d, except for the Withdrawal Billing Units for Wheels Through, Exports or to supply Station Power as a third-party provider.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in day d, except for the Withdrawal Billing Units for WheelsThrough, Exports or to supply Station Power as third-party providers.

6.1.12.6 Costs of All Remaining BPCGs

Pursuant to this Section 6.1.12.6, the ISO shall recover the costs of all Bid Production Cost guarantee payments not recovered through Sections 6.1.12.1, 6.1.12.2, 6.1.12.3, 6.1.12.4, and 6.1.12.5 of this Rate Schedule 1, including the residual costs of Bid Production Cost
guarantee payments for additional Resources not recovered through the methodology in
Attachment T of this ISO OATT, from all Transmission Customers.

6.1.12.6.1 Transmission Customer Charge Based on Withdrawal Billing Units Not
Used to Supply Station Power Under Section 5 of this ISO OATT

The ISO shall charge, and each Transmission Customer shall pay based on its

Withdrawal Billing Units that are not used to supply Station Power as a third-party provider, a daily charge in accordance with the following formula.

Where:

c = Transmission Customer.

d = A given day in the relevant Billing Period.

= The amount, in $, for which Transmission Customer c is

responsible for day d.

= The BPCG costs, in $, for day d not recovered by the ISO

through Sections 6.1.12.1, 6.1.12.2, 6.1.12.3, 6.1.12.4, and 6.1.12.5 of this Rate Schedule
1.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in day d, except for the Withdrawal Billing Units to supply Station Power as a third-party provider and except for Scheduled Energy Withdrawals at a CTS Enabled Interface with ISO New England resulting from Exports that are not associated with wheels through New England.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in day d, except for the Withdrawal Billing Units to supply

Station Power as third-party providers and except for Scheduled Energy Withdrawals at a

CTS Enabled Interface with ISO New England resulting from Exports that are not associated with wheels through New England.

6.1.12.6.2 Transmission Customer Charge Based on Withdrawal Billing Units to
Supply Station Power Under Section 5 of this ISO OATT

The ISO shall charge, and each Transmission Customer shall pay based on its

Withdrawal Billing Units used to supply Station Power as a third-party provider, a daily charge in accordance with the following formula.

Where:

= The Withdrawal Billing Units, in MWh, of Transmission Customer

c used to supply Station Power as a third-party provider for day d.

The definitions of the remaining variables are identical to the definitions for such variables set forth in Section 6.1.12.6.1 of this Rate Schedule 1 above.

6.1.12.6.3 Remaining BPCG Credit

The ISO shall calculate, and each Transmission Customer shall receive based on its

Withdrawal Billing Units that are not used to supply Station Power as a third-party provider, an amount of the revenue collected through the charge under Section 6.1.12.6.2 of this Rate
Schedule 1. This credit shall be calculated according to the following formula for each day in the relevant Billing Period.

Where:

= The amount, in $, that Transmission Customer c will

receive for day d.

= The sum of charges, in $, for all Transmission Customers

as calculated in Section 6.1.12.6.2 of this Rate Schedule 1 for day d.

The definitions of the remaining variables are identical to the definitions for such variables set forth in Section 6.1.12.6.1 of this Rate Schedule 1 above.

6.1.13Dispute Resolution Payment/Charge

The ISO shall calculate, and each Transmission Customer shall receive or pay, a dispute resolution payment or charge in accordance with Section 6.1.13.1 of this Rate Schedule 1 for the distribution of funds received by the ISO or the recovery of funds incurred by the ISO in the
settlement of a dispute.

6.1.13.1 Calculation of the Dispute Resolution Payment/Charge

The ISO shall calculate, and each Transmission Customer shall receive or pay, a dispute resolution payment or a dispute resolution charge for each Billing Period as calculated according to the following formula.

Where:

c = Transmission Customer.

P = The relevant Billing Period.

= The amount, in $, for Billing Period P that

(i) Transmission Customer c will receive if the ISO is distributing funds that it has

collected in the settlement of a dispute, or (ii) Transmission Customer c will be

responsible for if the ISO is recovering funds that it has incurred in the settlement of a
dispute.

= The amount, in $, for Billing Period P that (i) the ISO has

collected in the settlement of a dispute or (ii) the ISO has incurred in the settlement of a
dispute.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c in Billing Period P, except for Scheduled Energy Withdrawals at a CTS

Enabled Interface with ISO New England resulting from Exports that are not associated with wheels through New England.

= The sum, in MWh, of Withdrawal Billing Units for all

6.1.14Credit for Financial Penalties

The ISO shall distribute to each Transmission Customer each Billing Period in

accordance with the following formula any payments that it has collected from Transmission

Customers to satisfy: (i) Financial Impact Charges issued pursuant to Sections 4.5.3.2 and 4.5.4.2
of the ISO Services Tariff; (ii) ICAP sanctions issued pursuant to Section 5.12.12 of the ISO
Services Tariff; (iii) ICAP deficiency charges pursuant to Section 5.14.3.1 of the ISO Services
Tariff, except as provided in Section 5.14.3.2 of the ISO Services Tariff; (iv) market power
mitigation financial penalties pursuant to Section 23.4.3.6 of Attachment H of the ISO Services
Tariff, except as provided in Section 23.4.4.3.2 of Attachment H of the ISO Services Tariff; and

(v) any other financial penalties set forth in the ISO Services Tariff or this ISO OATT. The ISO
will perform this calculation separately for the allocation of the revenue from each financial
penalty.

Where:

c = Transmission Customer.

P = A given day in the relevant Billing Period.

= The amount, in $, that Transmission Customer c will

receive for Billing Period P.

= The sum, in $, of revenue that the ISO has collected for Billing

Period P from a Transmission Customer for one of the financial penalties indicated in Section 6.1.14 of this Rate Schedule 1.

= The Withdrawal Billing Units, in MWh, for Transmission

Customer c for Billing Period P, except for Scheduled Energy Withdrawals at a CTS

Enabled Interface with ISO New England resulting from Exports that are not associated with wheels through New England.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers for Billing Period P, except for Scheduled Energy Withdrawals at a CTS Enabled Interface with ISO New England resulting from Exports that are not associated with wheels through New England.

6.1.15Calculation of FERC Fee Charges

As a public utility the transmission provider under this Tariff is subject to annual charges assessed by the Commission in accordance with Part 382 of the Commission’s regulations
(annual FERC fee). The ISO shall charge, and each Transmission Customer taking service under the ISO Tariffs shall pay, a charge for the recovery of the annual FERC fee, on the basis of its
participation in physical market activity, and on the basis of its participation in non-physical
market activity in accordance with Sections 6.1.15.1 and 6.1.15.2 respectively. The annual
FERC fee shall be allocated ninety-four (94%) to physical market activity and six (6%) to non-
physical market activity respectively. Pursuant to ISO Procedures, the six (6%) of the annual
FERC fee allocated to non-physical market activity shall be further allocated approximately four percent (4%) to Transmission Congestion Contracts and approximately two percent (2%) to
Virtual Transactions. The total charge to each Transmission Customer for recovery of the annual FERC fee shall be the sum of the Transmission Customer’s Physical FERC Fee Charge and the
Transmission Customer’s Non-Physical FERC Fee Charge.

An estimated annual FERC fee shall be recovered over the twelve months of each federal
fiscal year. The ISO will publish the estimated annual FERC fee for each federal fiscal year no
less than one month in advance of the start of that federal fiscal year. Upon receiving the invoice
for the annual FERC fee, the ISO will implement a true-up, a credit or charge, equal to the

difference between the estimated annual FERC fee for the fiscal year and the invoiced amount, in the first Billing Period following receipt of the invoiced annual FERC fee, as is practicable. The ISO shall recover or refund the true-up amount over a six month period.

All funds collected by the ISO for the annual FERC fee shall be deposited in the annual
FERC fee account. The annual FERC fee account shall be an interest-bearing account separate
from all other accounts maintained by the ISO. The ISO shall disburse funds from the annual
FERC fee account in order to pay the FERC any and all annual FERC fee charges assessed
against the ISO.

6.1.15.1 Calculation of Physical FERC Fee Charge for Transmission Customers
Participating in Physical Market Activity

The ISO shall charge, and each Transmission Customer that participates in physical market activity shall pay, a charge for the recovery of the annual FERC fee as calculated according to the following formula:

Where:

c = Transmission Customer.

P = The relevant Billing Period.

= The amount, in $, of the annual FERC fee for which

Transmission Customer c is responsible for Billing Period P.

= The Injection Billing Units, in MWh, for Transmission Customer c in

Billing Period P.

= Ninety-four percent (94%).

= Billing Period P’s proportional allocation of the estimated annual FERC fee for the current FERC fiscal year.

-= Billing Period P’s proportional allocation of the difference between the

invoiced annual FERC fee and the estimated annual FERC fee.

= The sum, in MWh, of Injection Billing Units for all Transmission

Customers in Billing Period P.

= The Withdrawal Billing Units, in MWh, for Transmission Customer c

in the Billing Period P.

= The sum, in MWh, of Withdrawal Billing Units for all

Transmission Customers in the Billing Period P.

6.1.15.2 Calculation of the FERC Fee Charge for Transmission Customers
Participating in Non-Physical Market Activity

The ISO shall charge, and each Transmission Customer that has its virtual bids accepted
and thereby engages in Virtual Transactions or that purchases Transmission Congestion
Contracts shall pay, a charge for the recovery of the annual FERC fee as calculated according to

the following formula:-

Where:

c = Transmission Customer.

P = The relevant Billing Period.

= The amount, in $, of the annual FERC fee for which

Transmission Customer c is responsible for Billing Period P.

= The total cleared Virtual Transactions, in MWh, for Transmission Customer c in Billing Period P.

= Billing Period P’s proportional allocation of the estimated annual FERC fee for the current FERC fiscal year.

= Billing Period P’s proportional allocation of the difference between the

invoiced annual FERC fee and the estimated annual FERC fee.

= Approximately two percent (2%).

= The sum, in MWh, of cleared Virtual Transactions for all Transmission

Customers in Billing Period P.

= The total settled Transmission Congestion Contracts, in MWh, for Transmission Customer c in Billing Period P.

= Approximately four percent (4%).

= The sum of settled Transmission Congestion Contracts, in MWh, for all

Transmission Customers in Billing Period P.