Incremental Capacity Transfer Rights
(OATT Att. DD, Section 5.16, OATT Schedule 12A (b) Manual 18, Section 9.3)
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Incremental CTRs are provided to fund for transmission upgrades (not including qualifying transmission upgrades cleared in the Base Residual Auction) that increase import capability into a constrained LDA. Incremental CTRs for Incremental-Rights Eligible Required Transmission Enhancements are determined and allocated as defined in Schedule 12A of the Tariff.
Credits: Incremental CTR MW are priced at the sum of: 1) locational price adder of the sink LDA minus that of the Source LDA from the Base Residual Auction; and 2) locational price adder of the sink LDA minus that of the source LDA from the Second Incremental Auction multiplied by the increase in unforced capacity imported into the sink LDA in the Second Incremental Auction compared to the Base Residual Auction, divided by the base unforced capacity imported into the sink LDA. Incremental CTR credits determined for an Incremental-Rights Eligible Required Transmission Enhancement are allocated to the responsible customers that are assigned cost responsibility for the transmission enhancements in accordance with the cost allocations in the appendix to Schedule 12. Responsible customers include Network customers, Transmission Customers with an agreement for Firm Point-to-Point Service, or Merchant Transmission Facility Owners. Network customers serving load in a responsible zone receive credits in proportion to their network service peak load share in that zone.
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Incremental CTR Credits
Incremental CTR for Required Transmission Enhancement Credits |
Auction
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Bilateral capacity transactions for multi-day durations are settled in the PJM capacity markets.
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Auction Specific MW Transaction Charges and Credits |
Specific MW Transaction
(OATT Att. DD, Section 5.14 Manual 18, Section 9.3)
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Revenues are collected for generators requesting retirement where PJM studies find reliability issues that require the generation to continue operating. Cost allocations to zonal load and firm withdrawal rights are determined by PJM based on the beneficiaries. These responsible customers pay the generation owners a share of the Deactivation Avoidable Cost Rate or the FERC-approved Cost of Service Recovery Rate.
Charges: Sellers are charged for the transaction MW times the transaction’s pricing point for each day for which the transaction is in effect.
Credits: Buyers are credited for the transaction MW times the transaction’s pricing point for each day for which the transaction is in effect.
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Capacity Resource Deficiency
(OATT Att. DD, Section 8 Manual 18, Section 9.1)
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Capacity resources that are unable or unavailable to deliver unforced capacity, and do not obtain replacement unforced capacity to satisfy their cleared sell offer pay this charge which is allocated to eligible LSEs.
Charges: Each capacity resource’s deficiency MW for each day it is deficient pays the daily deficiency rate.
Credits: Total revenues each day are allocated to LSEs that paid a Locational Reliability charge that day based on their daily unforced capacity obligations.
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Non-Compliance Charge Summary
Deficiency Credit Summary
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Generation Resource Rating Test Failure
(OATT Att. DD, Section 7 Manual 18, Section 9.1)
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Generation capacity resources that fail a capacity test pay this charge which is allocated to eligible LSEs. This billing is performed in the June billing cycle after the conclusion of the delivery year.
Charges: Each capacity resource’s installed capacity minus its highest rating in the relevant testing period (on an unforced capacity basis) pays a daily deficiency rate which is the weighted average capacity resource clearing price plus the higher of: 1) 0.2 times the weighted average capacity resource clearing price or 2) $20/MW-day;
Credits: Total revenues each day are allocated to LSEs that paid a Locational Reliability charge that day based on their daily unforced capacity obligations.
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Non-Compliance Charge Summary
Deficiency Credit Summary
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Qualifying Transmission Upgrade Compliance Penalty
(OATT Att. DD, Section 12 Manual 18, Section 9.1)
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Cleared qualifying transmission upgrades delayed in coming into service for the applicable delivery year pay a daily penalty charge which is allocated to eligible LSEs.
Charges: Capacity market sellers with import capability cleared in a base residual auction based on a qualifying transmission upgrade are charged each day that the upgrade is not in service during the applicable delivery year and the seller does not obtain replacement capacity resources. The import capability MW are charged at the higher of the following rates: 1) two times the locational price adder of the applicable LDA; or 2) the Net CONE less the clearing price in the applicable LDA.
Credits: Total revenues each day are allocated to LSEs that paid a Locational Reliability charge that day based on their daily unforced capacity obligations.
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Non-Compliance Charge Summary
Deficiency Credit Summary
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Load Management Test Failure
(OATT Att. DD, Section 11A Manual 18, Section 9.1)
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Sellers with committed Demand Resources that fail performance tests pay a penalty charge which is allocated to eligible LSEs. This billing is performed in the August monthly bill issued in September after the conclusion of the Delivery Year.
Charges: Net capability testing shortfall MW are charged daily at the weighted annual revenue rate for the applicable zone plus the greater of 0.2 times that weighted annual revenue rate or $20/MW-day.
Credits: Total revenues each day are allocated to LSEs that paid a Locational Reliability charge that day based on their daily unforced capacity obligations.
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Load Management Test Failure Charge Summary
Load Management Test Failure Credit Summary
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Non-Performance Charges and Bonus Performance Credits
Manual 18, Section 8.4A
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Charges: Capacity Performance Resource commitments and PRD commitments are exposed to Non-Performance Charges for underperformance during Emergency Actions throughout the entire Delivery Year. A Non-Performance Assessment will compare each Capacity Resource’s Expected Performance against its Actual Performance for each Performance Assessment Interval. Resources that fail to perform to their expected performance are subject to Non-Performance Charge.
Credits: Capacity Performance Resource commitments and PRD commitments are exposed to Non-Performance Charges for underperformance during Emergency Actions throughout the entire Delivery Year. A Non-Performance Assessment will compare each Capacity Resource’s Expected Performance against its Actual Performance for each Performance Assessment Interval. Resources that over-perform may be eligible for Bonus Performance Credit.
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NPA Billing Month Summary
NPA DSR Reg Performance Details
NPA DSR Resource Charge Details
NPA Resource Charge Details
NPA Resource Charge Dist Summ
NPA Resource Outage Details
NPA Unit Performance Details
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PRD Commitment Compliance Penalty
(RAA Schedule 6.1, Section I Manual 18, Section 9.4)
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A PRD Provider with a positive daily commitment compliance shortfall in a sub-zone/zone for RPM or FRR will be assessed a Daily PRD Commitment Compliance Penalty.
Charges: Commitment compliance shortfall MW are charged daily at the Delivery Year Forecast Pool Requirement times the PRD Commitment Compliance Penalty Rate.
Credits: Total revenues each day are allocated to all entities that committed Capacity Resources in the RPM Auction for that delivery year based on their daily revenues from Capacity Market Clearing Prices in such auctions, net of any daily compliance charges incurred.
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PRD Commitment Compliance Penalty Charges
PRD Commitment Compliance Penalty Credits
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Unscheduled Transmission Service
(OpAgr Sch1-5.3a Manual 28, Section 14)
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Charges: Hourly charges to NYISO for any costs incurred due to unscheduled use of the PJM transmission system in accordance with the PJM-NYPP Interconnection Agreement Schedule 6.02.
Credits: Total hourly charges are allocated as credits with monthly excess congestion credits.
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Hourly Transmission Congestion Credits
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Generation Deactivation
(OATT Part V)
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Revenues are collected for generators requesting retirement where PJM studies find reliability issues that require the generation to continue operating. Cost allocations to zonal load and firm withdrawal rights are determined by PJM based on the beneficiaries. These responsible customers pay the generation owners a share of the Deactivation Avoidable Cost Rate or the FERC-approved Cost of Service Recovery Rate.
Charges: Charges are being collected for NRG Power Marketing, LLC resource Indian River Unit 4 based on a Cost of Service Recover Rate for dates June 1, 2022 through December 31, 2026. The monthly charges are allocated on a one-month lag. Based on PJM’s assessment of the contribution to the need for, and benefits expected to be derived from, the facilities, the zonal percentage cost allocation is 100% to DPL.
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Generation Deactivation Charge Summary
Generation Deactivation Refund Charge Summary
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Deferred Tax Adjustment
(OATT Attachments H-7B, H-8A and H-17C)
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Charges: Each Network Customer that serves one or more end-use customers taking distribution service from PPL Electric Utilities Corporation, Duquesne Light Company, or PECO Energy Company under its applicable retail tariff on file with the Pennsylvania Public Utility Commission (“PPL Electric Distribution Customers”, “Duquesne Electric Distribution Customers”, and/or “PECO Energy Company Distribution Customers”) shall pay a Monthly Deferred Tax Adjustment Charge. This charge permits PPL Electric, Duquesne Light and PECO Energy Company to recover a deferred income tax liability that is currently unfunded due to a Pennsylvania Public Utility decision to flow-through to customers certain income tax benefits.
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Deferred Tax Adjustment Charge Summary
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Schedule 11A PJM Net
Manual 29, Section 2.4 OATT Schedule 11A
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PJM Member request to purchase additional PJMnet connection(s) as described in the Open Access Transmission Tariff, Schedule 11A. PJM shall recover the costs of providing secure control center data communication ("PJMnet") in the manner set forth in this Schedule 11A from those Members who request additional PJMnet connections that are not required for reliability in the operation of the LLC or the Office of the Interconnection.
Charges: The costs to be recovered under this Schedule 11A consist of the actual costs of owning, leasing, and operating PJMnet and all of its related assets.
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Miscellaneous Bilateral
Manual 29, Section 2.4
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PJM Settlement administers agreed upon requests between specific PJM Members to bilaterally adjust their billing statement, as either charges or credits.
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PJM Annual Membership Fee
Manual 29, Section 2.4
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Charges: The Primary/Voting Member, as described in PJM Manual 33, is charged an annual fee in for the upcoming calendar year membership.
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PJM Customer Payment Default
(OATT Section 15.2.2)
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The PJM Board of Managers may direct billing Default Allocation Assessment(s) to non-defaulting PJM Members to recover the amount(s) not paid or recovered from any net buyer.
Charges: The default allocation assessment is equal to .1 * (1 / the total number of Members) + .9 * (the Member's gross activity as determined by summing the absolute values of the charges and credits for each of the Activity Line items as accounted for and billed for the month of default and the two previous months / the sum of gross activity for all eligible members)
The assessment value of (0.1*(1 / number of eligible members)) shall not exceed $10,000 per Member per calendar year, cumulative of all defaults, or more than once per Member default if Default Allocation Assessment charges for a single Member default span multiple calendar years.
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