NYISO Tariffs --> Market Administration and Control Area Services Tariff (MST) --> 28 MST Attachment M-1 - Operating Protocol for the Implement --> 28.1 MST Att M-1 Appendices 1-10

Appendix 1- Process Flow

Two Day-ahead Actions:

1.PJM shall post constraint forecast information indicating if there is the potential for off-cost operations, two days prior to the operating day by 9 pm.  (http://oasis.pjm.com/inform.html - sample at Figure 1 in Appendix 8) or a comparable website.

2.PJM shall analyze transmission and generation outages in accordance with Appendix 2B to determine if the 600/400 MW contract flow is expected to be feasible under a security constrained dispatch in PJM.  If any portion of the flow is not expected to be feasible under a security-constrained dispatch, PJM will determine what portion of the flow is expected to be feasible and post that information on the PJM OASIS.  This advance notification is not binding on any party.

3.The NYISO shall post transmission outages on its OASIS, or a comparable website, to identify outages that impact the transfer capability of the ISO Secured Transmission System.[1]

Day Ahead Scheduling:

4.ConEd shall submit a contract election (NY-DAE) in the NYISO’s Day-Ahead Market for the 600/400 MW contracts prior to 5:00 a.m. 

5.The NYISO shall establish New York (aggregate ABC interface and aggregate JK interface) Desired Flow (NYDF) schedules for NYISO Day Ahead Market using the NY-DAE identified in (4). 

6.The NYISO shall establish the distribution of flows for the NYISO DAM in accordance with Appendix 7.

7.The NYISO shall run the New York Day Ahead Market with NYDF schedules determined in (5 and 6).

8.The NYISO shall post DAM results by the deadline established in its market rules (currently prior to 11:00 a.m.).  The NYISO shall provide NYDF schedules and post nodal prices for the JK (Ramapo), BC (Farragut) and A (Goethals) pricing points on the NYISO OASIS, or a comparable website.  (http://www.nyiso.com/oasis/index.html - sample at Figure 2 in Appendix 8).

9.ConEd shall submit a contract election (PJM-DAE) in the PJM Day Ahead Market prior to 12 noon:

a)ConEd shall submit a contract election for the 600 MW contract.

b)ConEd shall submit a contract election for the 400 MW contract.  For the 400 MW contract, ConEd shall specify whether it is willing to pay congestion (WPC) under the following options:[2]

i)ConEd is not willing to pay congestion for any portion of the 400 MW

ii)ConEd willing to pay congestion up to $25

iii)ConEd willing to pay congestion with no redispatch cost limit

10.PJM shall establish the PJM (aggregate ABC interface and aggregate JK interface) Desired Flow (PJMDF) schedules for PJM Day Ahead Market using PJM-DAE identified in (9).

11.PJM shall establish the distribution of flows for the PJM DAM in accordance with Appendix 7.

12.PJM shall run the PJM Day Ahead Market with the PJMDF schedules determined in (11).  The amount of the PJM-DAE which clears will become the PJM Day Ahead Schedule amount (PJM-DAS).  The PJM-DAS may be reduced from the PJM-DAE based on ConEd’s WPC specification or infeasibility under the PJM security-constrained dispatch.

13.PJM Day Ahead results shall be posted by the deadline established in PJM’s market rules (currently at 4:00 p.m.), and shall identify the PJM-DAS.  The PJM posting will include nodal prices for the JK (Waldwick), BC (Hudson) and A (Linden) pricing points, or a comparable website.  (https://esuite.pjm.com/mui/index.htm - sample at Figure 3 in Appendix 8.)

If there is congestion in the PJM Day Ahead Market:

14.If there is congestion in PJM that affects the portion of the wheel that is associated with the 600 MW contract, PJM shall re-dispatch and PSE&G shall pay for re-dispatch.  PSE&G shall be provided Fixed Transmission Rights (FTRs) in an amount equal to the PJM-DAS.

15.If there is congestion in PJM that affects the portion of the wheel that is associated with the 400 MW contract, PJM shall re-dispatch for the portion of the 400 MW contract for which ConEd specified it was willing to pay congestion, and ConEd shall pay for the re-dispatch.[3]  ConEd will be credited back for any congestion charges paid in the hour to the extent of any excess congestion revenues collected by PJM that remain after congestion credits are paid to all other firm transmission customers.  Such credits to ConEd shall not exceed congestion payments owed or made by it.[4]

In Day Operations:

16.Aggregate ABC and aggregate JK Real-Time Market Desired Flow (RTMDF) calculations shall be made in real time, continuous throughout the operating day, by the NYISO and PJM.

17.The desired distribution of flows on the A, B, C, J, and K lines for the in-day markets shall be established by PJM and the NYISO in accordance with Appendix 7.

18.If neither PJM nor the NYISO are off-cost, or if both are off-cost, aggregate actual ABC interface flows shall be within +/- 100 MW of the aggregate RTMDF for the ABC interface and aggregate actual JK interface flows shall be within +/- 100 MW of the aggregate RTMDF for the JK interface.

19.ConEd shall have the option to request a modification in the Real-Time Market from its Day Ahead Market election (NY_DAE and PJM_DAE) for each hour.[5]

a)ConEd must request a Real-Time election (RTE) modification through NYISO at least 75 minutes prior to the dispatch hour (or a shorter notice period that is agreed upon by the NYISO and PJM.).

b)The NYISO shall notify PJM of the RTE.

c)ConEd shall settle with PJM for balancing market costs for deviations between PJM-DAS and RTE.  Con Ed shall settle with the NYISO for balancing market costs for deviations between NY-DAE and RTE.

 

Note - Actions identified in steps 18 and 19 that are taken will be logged, and PSE&G and ConEd will be notified of PAR moves related to these steps.

If there is In-Day congestion:

20.If PJM is off-cost or is expected to go off-cost for two or more consecutive hours in maintaining the RTMDF, and the NYISO is not off-cost, then PJM and NYISO shall consult with each other and shall redirect up to 300 MW (in a mutually agreed upon amount and in mutually agreed upon increments) from the PJM system onto the NYISO system; provided, however, that PJM and the NYISO verify that allowing actual aggregate interface flows to deviate from the RTMDF will not result in violation of applicable PJM or NYISO reliability criteria.  The process of modifying actual interface flows in incremental adjustments will continue until

a)PJM is no longer off-cost, or

b)The NYISO is about to go off-cost (i.e., the NYISO expects that it will have to redispatch in response to transmission constraints in order to maintain the RTMDF), or

c)300 MW have been redirected.

21.If the NYISO is off-cost or expected to go off-cost for two or more consecutive hours in maintaining the RTMDF, and PJM is not off-cost, then PJM and the NYISO shall consult with each other and shall redirect up to 300 MW (in a mutually agreed upon amount and in mutually agreed upon increments) from the NYISO system onto the PJM system; provided, however, that PJM and NYISO verify that allowing actual aggregate interface flows to deviate from the RTMDF will not result in violation of applicable PJM or NYISO reliability criteria.  The process of modifying actual interface flows in incremental adjustments will continue until

a)The NYISO is no longer off-cost, or

b)PJM is about to go off-cost (i.e., PJM expects that it will have to redispatch in response to transmission constraints in order to maintain the RTMDF), or

c)300 MW have been redirected.

Appendix 2 - Transmission Constraints and Outages Associated with the Contracts

A.Constraints

The following transmission constraints are identified as potential constraints that may result in off-cost operation due to transfers associated with the 600/400 MW contracts.  The constraints included in this listing should be considered representative of the kinds of constraints that may exist within PJM or the NYISO.  If such transmission constraints are limiting, then the affected ISO/RTO may be subject to off-cost operation due to transfers associated with the 600/400 MW contracts.  Other constraints, not listed here, may arise that could cause either ISO/RTO to operate off-cost.  This list may be revised by NYISO/PJM to reflect system changes or security monitoring technique changes in their respective Control Areas. 

NYISO

 

PJM

 

B.Outages

The NYISO and PJM will identify critical outages that may impact redispatch costs incurred for the delivery of energy, under the 600/400 MW contracts.  Identified outages may have the following consequences:

The outage of any A, B, C, J, or K facility will result in the NY-DAE, PJM-DAE,  and/or RTE (as appropriate) being limited to a value no greater than the remaining thermal capability of the most limiting of the ABC interface or the JK interface.  The remaining thermal capability of either the ABC interface or the JK interface may be limited by other facilities directly in series with the A, B, C, J, or K lines.

1.600 MW Contract - It is not anticipated that one primary facility outage will preclude PJM from providing redispatch for the 600 MW contract.  However, combinations of two or more outages of the facilities, listed below, could preclude PJM from accommodating all or part of the 600 MW delivery, even with redispatch.  In this case, PJM will provide notification to NYISO.

2.400 MW Contract - The outage of one or more of the facilities in the following list, may impact redispatch costs regarding, or the delivery of all or portions of the 400 MW contract:

Branchburg-Ramapo 500 kV 5018

South Mahwah-Waldwick J 345 kV J-3410/69

South Mahwah-Waldwick K 345 kV K-3411/70

Hudson-Farragut B-3402

Hudson-Farragut C-3403

Linden-Goethals 230 kV A-2253

Athenia-NJT Meadows -Essex-Hudson 230 kV C-2281-P-2216-A-2227

New Milford-Leonia-Bergen-Penhorn-Hudson 230 kV T-2272-X-2250

Waldwick-Hillsdale-New Milford 230 kV F-2258-V-2222

Waldwick- Fairlawn 230 kV O-2267

Waldwick-Hawthorne-Hinchman's Ave-Cedar Grove 230 kV E-2257 – N-2266 – M-2239 – L-2238

Roseland-Cedar Grove-Clifton-Athenia B 230 kV B-2228

Roseland-Cedar Grove-Clifton-Athenia K 230 kV F-2206 – K-2263

Linden-Bayway 230 kV H-2234

Linden-Minue Street R 230 kV R-2218

Linden-Minue Street G 230 kV G-2207

Roseland-Whippany A-941

Branchburg-Readington-Roseland M-2265 - U-2221

Roseland-Montville-Newton-Kittatinny E-2203 – N-2214 - T-2298

Deans – Aldene W-2249

In addition, the forced or maintenance outage of one or more of the following generators may impact redispatch costs regarding, or the delivery of all or portions of the 400 MW contract provided that any such maintenance outage is approved by PJM.  Otherwise, each of these generators will be considered to be available to support the 600/400 MW contracts under a security constrained dispatch in PJM’s Day-Ahead and Real-Time Markets.

Hudson #1

Hudson #2

Bergen #1

Bergen #2

Linden #1

Linden #5, 6, 7, & 8

 

PJM will provide notification[6] of all outages by posting these outages (transmission only) on the PJM OASIS (http://oasis.pjm.com/inform.html).  At a minimum, PJM will identify critical scheduled outages by the first day of the month prior to the month of the start of the outage.

NYISO will provide notification of all outages by posting these outages (transmission only) on the NYISO OASIS (http://www.nyiso.com/oasis/index.html).  NYISO will identify critical scheduled outages by the first day of the month prior to the month of the start of the outage.

PJM and the NYISO will review and revise, as necessary, the list of primary and secondary facilities contained in this Appendix 2 on an annual basis.

 

Appendix 3 - The Day-Ahead Market and Real-Time Market Desired Flow Calculation

The following shall be the formula for calculating Day-Ahead Market (DAM) and Real-Time Market (RTM) desired flows:

 

NYDFABC =  [NY-DAE] + [A]*[PJM-NYISO DAM Schedule] + [B] *[OH-NYISO DAM Schedule] + [C] *[West-PJM DAM Schedule] + [D]*[DAM Lake Erie Circulation]

 

NYDFJK =  [NY-DAE] - [A]*[PJM-NYISO DAM Schedule] - [B] *[OH-NYISO DAM Schedule] - [C] *[West-PJM DAM Schedule] - [D]*[DAM Lake Erie Circulation]

 

PJMDFABC =  [PJM-DAE] + [A]*[PJM-NYISO DAM Schedule] + [B] *[OH-NYISO DAM Schedule] + [C] *[West-PJM DAM Schedule] + [D]* DAM Lake Erie Circulation]

 

PJMDFJK =  [PJM-DAE] - [A]*[PJM-NYISO DAM Schedule] - [B] *[OH-NYISO DAM Schedule] - [C] *[West-PJM DAM Schedule] - [D]*[DAM Lake Erie Circulation]

 

RTMDFABC =  [RTE] + [A]*[PJM-NYISO RTM Schedule] + [B] *[OH-NYISO RTM Schedule]

+ [C] *[West-PJM RTM Schedule] + [D]*[RTM Lake Erie Circulation]

 

RTMDFJK =  [RTE] - [A]*[PJM-NYISO RTM Schedule] - [B] *[OH-NYISO RTM Schedule]

- [C] *[West-PJM RTM Schedule] - [D]*[RTM Lake Erie Circulation]

 

A

13 %

 

Adjustment for NYISO-PJM Schedule

 

B

0 %

 

Adjustment for OH-NYISO Schedule

 

C

0 %

 

Adjustment for West-PJM Schedules

 

D

0 %

 

Adjustment for Lake Erie Circulation

 

 

Other impacts will be part of the real time bandwidth operation – not the desired flow calculation.  These impacts will be reviewed by PJM and the NYISO on an annual basis.

The above distribution factors (A, B, C, D) will be used in the calculation unless otherwise agreed by PJM and the NYISO based upon operating analysis conducted in response to major topology changes or outages referenced in Appendix 2.  Such modifications will be posted by PJM and the NYISO.

Appendix 4 - Market Monitoring and Information Sharing Procedures

A.General Principles

The NYISO and PJM and their Market Monitoring Units shall, to the extent compatible with their respective tariffs and with any other market monitoring procedures that they have filed with the Commission:

1.Conduct such investigations as may be necessary to ensure that gaming, abuse of market power, or similar activities do not take place with regard to power transfers under the 600/400 MW contracts;

2.Conduct investigations that go into the region of the other ISO jointly with the NYISO, PJM and both Market Monitoring Units;

3.Inform each other of any such investigations; and

4.Share information related to such investigations, as necessary to conduct joint investigations, subject to the requirements of Section C, below.

 

The responsibilities of the Market Monitoring Unit that are addressed in Section A of Appendix 4 to the Operating Protocol for the Implementation of Commission Opinion No. 476 (Appendix M-1 to the ISO Services Tariff) are also addressed in Section 30.4.6.5.2 of Attachment O.

B.Information Regarding Transactions Associated with the 600/400 MW Contracts

 

1.General Information

 

a.The NYISO and PJM Market Monitoring Units shall have made available to them by their respective ISOs the Day-Ahead and Real-Time elections made by ConEd in both Control Areas under this protocol.

 

b.The NYISO and PJM Market Monitoring Units shall have available to them such data on transmission conditions in both the Day-Ahead and Real-Time markets in both PJM and NYISO, as is publicly available and posted on the ISOs’ internet sites.

 

2.Information Available upon Request

 

a.On a case-by-case basis, as documented in writing as being necessary to an investigation or to determine if an investigation is necessary or appropriate, the NYISO and PJM shall make available to each other, and to each of their Market Monitoring Units, generator outages and deratings in both the Day-Ahead and Real-Time markets.

 

b.On a case-by-case basis, as documented in writing as being necessary to an investigation or to determine if an investigation is necessary or appropriate, the NYISO and PJM shall make available to each other, and to each of the Market Monitoring Units, the specific FTRs or TCCs in the PSE&G zone or the ConEd Transmission District, respectively, held by ConEd, PSE&G, and any of their affiliates.

 

3.Information Needed To Conduct a Joint Investigation

 

The sharing of information that is necessary or appropriate to facilitate a joint investigation by the PJM and NYISO, and/or by their Market Monitoring Units shall be governed by the terms and conditions of the ISOs’ respective tariffs, operating agreements, and other procedures that they have filed with the Commission, and shall be subject to the limitations in Section C, below.

C.Protection of Confidential Information

1.This Appendix does not present an independent basis for, and shall not be construed to authorize or require the disclosure of, confidential, proprietary or privileged information that the NYISO or PJM are otherwise prohibited from disclosing under applicable laws, regulations, tariffs, or other market monitoring procedures that they have filed with the Commission. 

 

2.The NYISO’s or its Market Monitoring Unit’s disclosure of “Protected Information” to PJM, or to its Market Monitoring Unit are subject to the provisions of Section 30.6.6 of Attachment O. PJM’s, or its Market Monitoring Unit’s disclosure of “confidential information” to the NYISO, or to its Market Monitoring Unit, is subject to the provisions of Section 18.17.5 of the PJM Operating Agreement.

 

3.If the NYISO or PJM, or either of their Market Monitoring Units receives a demand for the disclosure of confidential information that it received under this Appendix 4, it shall notify the other so that the other will have an opportunity to take any legal steps required to protect the information.

 

Appendix 5 - Impairments Impacting Delivery

The procedures for identifying and remedying impairments shall be handled on a planning basis.  The impairment process is not directly applicable to DAM or RT operations under the 600/400 MW contracts.

 

EXISTING IMPAIRMENTS

 

NOTIFICATION PROCEDURES

 

PROCEDURES FOR DETERMINATION OF FUTURE IMPAIRMENTS

Nothing in this Operating Protocol shall modify any planning-related obligations of ConEd or PSE&G set forth in the 600/400 MW contracts.

Appendix 6 – Operation of the PARs

General

This procedure outlines the steps taken to coordinate tap changes on the PARs in order to control power flow on selected transmission lines between New York and New Jersey.  The facilities are used to provide transmission service and to satisfy the 600/400 MW contracts, other third party uses, and to provide emergency assistance as required.  These tie-lines are part of the interconnection between the PJM and NYISO.  These PAR operations will be coordinated with the operation of other PAR facilities including the 5018 PARs.  The 5018 PAR will be operated taking into account this Operating Protocol.  The ties are controlled by PARs at the following locations:

 

This appendix addresses the operation of the PARs at Waldwick, Goethals, and Farragut as these primarily impact the delivery associated with the 600/400 MW contracts between PSE&G and ConEd.

PJM and the NYISO will work together to maintain reliable system operation, and to implement the RTMDF within the bandwidths established by this Operating Protocol while endeavoring to minimize the tap changes necessary to implement these contracts.

RTMDF calculations will be made for the ‘ABC Interface’, and the ‘JK Interface’.  Desired line flow calculations will be made for A, B, and C lines (initial assumption is balanced each 1/3 of the ABC Interface), and for the J and K lines (initial assumption is balanced each ½ of the JK Interface). 

Normal Operations

The desired flow calculation process is a coordinated effort between PJM and the NYISO.  PJM and the NYISO have the responsibility to direct the operation of the PARs to ensure compliance with the requirements of the Operating Protocol.  However, one of the objectives of this procedure is to minimize the movement of PARs while implementing the requirements of the 600/400 MW contracts.  PJM and the NYISO will employ a +/- 100 MW bandwidth at each of the ABC and JK Interfaces to ensure that actual flows are maintained at acceptable levels.

PJM and the NYISO have operational control of the PARs and direct the operation of the PARs, while PSE&G and ConEd have physical control of the PARs.  The ConEd dispatcher sets the PAR taps at Goethals and Farragut at the direction of the NYISO.  The PSE&G dispatchers set the PAR taps at Waldwick at the direction of PJM.

Tap movements shall be limited to 400 per month based on 20 operations (per PAR) in a 24-hour period.  If, in attempting to maintain the desired bandwidth, tap movements exceed these limits, then the bandwidth shall be increased in 50 MW increments until the tap movements no longer exceed 20 per day, unless PJM and the NYISO agree otherwise.  

Emergency Operations

If an emergency condition exists in either the NYISO or PJM, the NYISO dispatcher or PJM dispatcher may request that the ties between New York and New Jersey be adjusted to assist directing power flows in the respective areas to alleviate the emergency situation.  The taps on the PARs at Waldwick, Goethals, and Farragut may be moved either in tandem or individually as needed to mitigate the emergency condition.  Responding to emergency conditions in either the NYISO or PJM overrides any requirements of this Operating Protocol and the appendices hereto.

PAR Movement Scenarios

Case 1 — Aggregate actual flow on the JK interface (at Waldwick) or the ABC interface (at Farragut and Goethals) is higher or lower than RTMDF, but within the bandwidth. 

 

No action taken.  Flows will continue to be monitored, but action will only be taken if the flows get above or below the bandwidth.

 

Case 2 — Aggregate actual flow on the JK interface (at Waldwick) or the ABC interface (at Farragut and Goethals) is higher or lower than the RTMDF, and outside the bandwidth.

 

PJM and the NYISO will coordinate the following procedures:

 

 

 

 

 

 

Case 3 — If PJM or NYISO analysis reveals that future system conditions (within the next several hours)may reasonably be expected to require that a PAR will need to change by more than 3 taps in order to remain within the bandwidth, then PJM and NYISO shall consider pre-positioning the system to address these future conditions.  Both PJM and the NYISO must agree to any decision to re-position the taps to address expected future conditions.

 

PJM and the NYISO will coordinate with each other and may mutually agree to position the respective PARs on each system to be within two tap changes in anticipation of changes to RTMDF for the next several hours to ensure that the PARs are positioned such that they are able to meet the anticipated RTMDF.

 

Appendix 7 – Distribution of Flows Associated with Implementation of Day-Ahead and Real Time Market Desired Flows

In general, the ability to maintain the ABC / JK actual interface flows at their corresponding ABC/JK Day-Ahead and Real Time Market Desired Flow (RTMDF) values should not be impacted by individual line flow constraints.  The Operating Protocol will ordinarily be considered satisfied if the ABC/JK actual interface flows are each equal to the desired flow values plus or minus the 100 MW bandwidth.

The initial estimate of individual line flow distribution for the ABC / JK interfaces shall be based on an equal flow assumption among the lines comprising the interface.  Under outage conditions of the A, B, C, J, or K lines, the initial estimate of individual line flow distribution shall be based on an assumption that flows should be equalized among those remaining lines comprising the interface.  Further, the ISOs shall adjust (from RTMDF) the flow distribution for ABC (move flow from the A line to the B and C lines) upon the NYISO’s request, provided that the adjustment shall not exceed 125 MW if PJM is off-cost or is expected to be off-cost.  Con Ed shall not be responsible for balancing charges resulting from changes in the individual line flow distribution between the PJM Day-Ahead and Real-Time Markets.

 

For example:

 

If the ABC interface RTMDF is 900 MW, then the initial estimate of line flow on A is 1/3 * 900=300 MW, B is 1/3 * 900=300 MW, and C is 1/3 * 900=300 MW.

If the J, K interface RTMDF is 900 MW, then the initial estimate of line flow on J is 1/2 * 900=450 MW, K is 1/2 * 900=450 MW.

 

However, if the ABC/JK actual interface flows cannot be maintained within the 100 MW bandwidth of desired flows due to the following system conditions:  1) insufficient PAR angle capability and an inability to redispatch in response to transmission constraints in PJM; or 2) upon implementing a NYISO request to adjust the distribution of flow on the A line (move flow from the A line to the B and C lines) in excess of 125 MW as described above, then the actual ABC and/or JK interface flow shall be adjusted to be as close as feasible to the interface desired flow values for each of the JK and ABC interfaces.

For example:

Assume the ABC interface RTMDF = 900 MW, then the initial estimate of line flow on A is 1/3* 900=300 MW, B is 1/3 * 900=300 MW, and C is 1/3 * 900=300 MW. 

Further assume that the NYISO requests that the distribution of flow over the A line be limited to 100 MW, then the resulting system conditions are an actual ABC interface flow of 825 MW with individual PAR flows of A=100 MW, B=362.5 MW, C=362.5 MW.

In this example, the actual ABC interface flow is as close as feasible to the ABC RTMDF assuming off-cost operation in the PJM area and the NYISO request that the distribution of flow over the A line be limited to 100 MW, which is in excess of the 125 MW distribution adjustment (300 MW-100 MW = 200 MW). PJM and the NYISO’s obligations under this Operating Protocol will be deemed to be satisfied even though the ABC/JK actual interface flows are not equal to the RTMDF plus or minus the 100 MW bandwidth.

 

 

 

Appendix 8 – References

 

Figure 1 - PJM Constraints

 

Figure 2 - NYISO Day Ahead Results

 

Figure 3 - PJM Day Ahead Market Results

 

 

 

Effective Date: 6/30/2010 - Docket #: ER10-1657-000 - Page 1


NYISO Tariffs --> Market Administration and Control Area Services Tariff (MST) --> 28 MST Attachment M-1 - Operating Protocol for the Implement --> 28.1 MST Att M-1 Appendices 1-10

Appendix 9 – Comparison of Contracts

 

Effective Date: 6/30/2010 - Docket #: ER10-1657-000 - Page 1


NYISO Tariffs --> Market Administration and Control Area Services Tariff (MST) --> 28 MST Attachment M-1 - Operating Protocol for the Implement --> 28.1 MST Att M-1 Appendices 1-10

Appendix 10 – Definitions

1.Off cost – the weighted LMP of JK is less than the weighted LMP of ABC by more than $5 and/or the weighted nodal pricing of Ramapo is less than the weighted nodal pricing of the aggregate of Farragut and Goethals by more than $5 (with a reasonable expectation of the appropriate cost differential continuing for at least two consecutive hours).

2.New York ISO Day Ahead Election (NY-DAE) - election by ConEd – submitted in the NYISO Day-Ahead Market prior to 5 a.m. 

3.NY Desired Flow (NYDF) – desired flow calculation by NYISO based on NY-DAE for input to NYISO Day Ahead Market.

4.PJM Day Ahead Market Election (PJM-DAE) - election by the ConEd – submitted in the PJM Day Ahead Market prior to 12 noon.

5.Willing To Pay Congestion (WPC) – an election made by ConEd based on willingness to pay congestion costs.

6.PJM Desired Flow (PJMDF) – desired flow calculation by PJM based on PJM-DAE for input to PJM Day Ahead Market.

7.ConEd Real-Time election (RTE) – option by ConEd to request Real-Time Market modification from its Day Ahead Market election.

8.Real-Time Market Desired Flow (RTMDF) – Desired flow for real time operations.

9.Impairments – Conditions determined during the NYISO’s and PJM’s respective planning analyses that will cause implementation of the 600/400 MW contracts to result in violations of established reliability criteria. 

10.Active Load Management (ALM) - Active Load Management is end-use customer load which can be interrupted at the request of PJM.  Such PJM request is considered an Emergency action and is implemented prior to a voltage reduction.

11.Pricing points – aggregate nodal points for the ABC interface and JK interface at the respective locations in both PJM and NYISO regions.  These points will be defined and posted.

 

Effective Date: 6/30/2010 - Docket #: ER10-1657-000 - Page 1

[1]The ISO Secured Transmission System is defined in the NYISO’s Transmission and Dispatching Operations Manual.

See <http://www.nyiso.com/services/documents/manuals/pdf/oper_manuals/trans_disp.pdf>.

 

[2]ConEd may submit a series of bids totaling up to 400 MW that employ several or all of the pricing options described in (9).

 

[3]Settlements will be based on the differences in prices between the JK and ABC pricing points.

[4]If ConEd converts the 400 MW contract to firm transmission service (by purchasing PJM firm transmission service, with a credit for payments ConEd has made to PSE&G for non-firm transmission service), then ConEd congestion credits instead will be determined in the same manner as the credits provided to all other PJM firm transmission customers.

 

[5]At all times, however, the ConEd election under the 600/400 MW contracts must be the same in PJM and NYISO in In-Day Operations.  Absent an in-day change in the election by ConEd, the ConEd Real-Time election shall be the PJM-DAS.

 

[6]PJM can also provide the option of automated email outage notification through the PJM eDart tool.

[7]1,000 MW will also be included in the FTR simultaneous feasibility analysis.