DAESR q, r, p, h MW Day-Ahead Energy from Resource per QSE by Settlement Point per Resource by hourThe amount of energy cleared through Three-Part Supply Offers in the DAM for the Resource at the Resource Node Settlement Point represented by the QSE for the hour. 1 / hour MKTINT Yes DASPP p, h $/MWh Day-Ahead Settlement Point Price by Settlement Point by hourThe DAM Settlement Point Price at the Resource Node Settlement Point for the hour. 1 / hour MKTINT No DAEREV q, r, p, h $ Day-Ahead Energy Revenue per QSE per Settlement Point per Resource by hourThe revenue received in the DAM for the Resource at the Resource Node Settlement Point represented by the QSE, based on the DAM Settlement Point Price, for the hour. 1/ hour DAMINT Yes RMR Day-Ahead Energy Revenue Total Description The RMR Energy Revenue Total (RMRDAEREVTOT) is not a charge type, but rather a global bill determinant. This global bill determinant is used by multiple charge types and intermediate calculations, such as the Day-Ahead Congestion Rent and RMR Service Charge. RMRDAEREVTOT is the ERCOT-wide summation of the DAEREV data cut for all RMR units. Calculation Calculate the RMR Day-Ahead Energy Revenue Total for each Operating Hour in the Operating Day, using the DAEREV data calculated for RMR Units only, for that Operating Day. Variable Unit Description Interval Frequency Extract Source RMRDAEREVTOT $ RMR Day-Ahead Energy Revenue Total - The total of the RMR Day-Ahead Energy Revenue for all RMR Units for the hour. 1 / hour DAMINT Yes DAEREV q, r, p $ Energy Revenue per QSE per Settlement Point per Resource by hourThe revenue received in the DAM for the Resource at the Resource Node Settlement Point represented by the QSE, based on the DAM Settlement Point Price, for the hour. 1/ hour DAMINT Yes Day-Ahead Make-Whole Payment able
PR 4.4.7.1 (1) indicates that a QSE cannot self-arrange Non-Spin Service in excess of its Non-Spin obligation. The QSE’s obligation may also be reduced after the Operating Day, in effect making the self arranged quantity greater than the obligation. However, this will not occur until after the settlement process for the Operating Day obtains new load values and therefore this is not an issue for the DA settlements process. Payment is calculated by QSE for each hour of the Operating Day within the Day Ahead Market. Calculation Variable Unit Description Interval Frequency Extract Source DANSAMT q $ Day-Ahead Non-Spin Amount per QSE—QSE q’s share of the DAM cost for Non-Spin, for the hour. 1 / hour DAMINT Yes DANSPR $/MW per hour Day-Ahead Non-Spin Price—The Day-Ahead Non-Spin price for the hour. 1 / hour MKTINT No DANSQ q MW Day-Ahead Non-Spin Quantity per QSE—The portion of QSE q’s net Day-Ahead Ancillary Service obligation that is not self-supplied with its Resources capacity, for the hour. 1 / hour DAMINT Yes PCNSAMTTOT $ Procured Capacity for Non-Spin Amount in DAM—The total of the DAM Non-Spin payments for all QSEs for the hour. 1 / hour DAMINT No PCNSAMT q $ Procured Capacity for Non-Spin Amount per QSE in DAM—The DAM Non-Spin payment for QSE q for the hour. 1 / hour DAMINT Yes DANSQTOT MW Non-Spin Quantity Total—The sum of every QSE’s portion of its net Day-Ahead Ancillary Service obligation that is not self-supplied with its Resource, for the hour. 1 / hour DAMINT No q MW Non-Spin Obligation per QSE—The Non-Spin capacity obligation for QSE q for the DAM for the hour. 1 / hour MKTINT Yes DASANSQ q MW Self-Arranged Non-Spin Quantity per QSE—The self-arranged Non-Spin quantity submitted by QSE q before 1000 in the Day-Ahead. 1 / hour MKTINT Yes Pre-settlement and Shadow Settlement Activity for Ancillary Service Charges
Description A PTP Obligation with refund is only available to a NOIE and is pre-assigned at the CRR Auction and non-tradable. Settlement of PTP Obligations with Refund in DAM is described as follows: (PR7.9.1.5) Except as specified otherwise in paragraph (2) below, ERCOT shall pay the owner of a PTP Obligation with Refund the difference in the Day-Ahead Settlement Point Prices between the sink Settlement Point and the source Settlement Point, subject to a charge for refund, when the price difference is positive. The payment of PTP Obligations with Refund may be further reduced due to transmission elements that are oversold in previous CRR auctions. Calculation Variable Unit Description Interval Frequency Source DAOBLRAMT o, (j, k) $ Day-Ahead Obligation with Refund Amount per CRR Owner per pair of source and sinkThe payment to CRR Owner o for the PTP Obligation with Refund with the source j and the sink k, settled in the DAM, for the hour. 1 / hour Calculated Yes DAOBLRTP o, (j, k) $ Day-Ahead Obligation with Refund Target Payment per CRR Owner per source and sink pair—The target payment for CRR Owner o’s PTP Obligations with Refund, with the source j and the sink k, settled in the DAM, for the hour. 1 / hour Calculated Yes
(2) The payment of PTP Options with Refund may be further reduced due to transmission elements that are oversold in previous CRR auctions. (3) The payment to each CRR Owner for a given Operating Hour of its PTP Options with Refund with each pair of source and sink Settlement Points settled in the DAM is calculated as follows: Calculation Variable Unit Description Interval Frequency Source DAOPTRAMT o, (j, k) $ Day-Ahead Option with Refund Amount per CRR Owner per pair of source and sinkThe payment to CRR Owner o for its PTP Options with Refund with the source j and the sink k, settled in the DAM, for the hour. 1 / hour Calculated Yes DAOPTRTP o, (j, k) $ Day-Ahead Option with Refund Target Payment per CRR Owner per source and sink pair—The target payment for CRR Owner o’s PTP Options with Refund, with the source j and the sink k, settled in the DAM, for the hour. 1 / hour Calculated Yes DAOPTRHV o, (j, k) $ Day-Ahead Option with Refund Hedge Value per CRR Owner per source and sink pair—The hedge value of CRR Owner o’s PTP Options with Refund, with the source j and the sink k, settled in the DAM, for the hour. 1 / hour Calculated Yes DAOPTRDA o, (j, k) $ Day-Ahead Option with Refund Derated Amount per CRR Owner per source and sink pair—The derated amount of CRR Owner o’s PTP Options with Refund, with the source j and the sink k, settled in the DAM, for the hour. 1 / hour Calculated Yes DAOPTRPR (j, k) $/MW per hour Day-Ahead Option Price with Refund per pair of source and sinkThe DAM price of the PTP Option with Refund with the source j and the sink k, for the hour. NOTE: The value of DAOPTPR shall always be equal to or greater than zero (0). 1 / hour Calculated Yes
Variable Unit Description Interval Frequency Source Shadow With RTPCRDAMT q, m $ Procured Capacity for Reg-Down Amount by QSE by market—The payment to QSE q for the Ancillary Service Offers cleared in the market m to provide Reg-Down, for the hour. 1 / hour Calculated Yes MCPCRD m $/MW per hour Market Clearing Price for Capacity for Reg-Down by market—The MCPC for Reg-Down from the market m, for the hour. 1 / hour No RTPCRD q, m MW Procured Capacity for Reg-Down by QSE by market—The portion of QSE q’s Ancillary Service Offers cleared in the market m to provide Reg-Down, for the hour. 1 / hour Yes PCRDR r, q, m MW Procured Capacity for Reg-Down from Resource per Resource per QSE by market—The Reg-Down capacity quantity awarded to QSE q in the market m for Resource r for the hour 1 / hour Yes Responsive Reserve Description If a SASM is executed for one or more Operating Hours for any reason, ERCOT shall pay QSEs for their Ancillary Service Offers cleared in the SASM, based on the MCPC for that SASM and that service. By service and by SASM, the payment to each QSE for a given Operating Hour is calculated as follows: (PR 6.7.1(1)) These particular bill determinants, PCRUAMT and PCRU, will need to be calculated and recorded on a per Supplemental Ancillary Service Market basis. This is necessary to maintain Market Integrity and allow for multiple market situations. Payment is calculated by QSE for each hour of the Operating Day within the Market. Calculation Variable Unit Description Interval Frequency Source RTPCRRAMT q, m $ Procured Capacity for Responsive Reserve Amount by QSE by market—The payment to QSE q for the Ancillary Service cleared in the market m to provide Responsive Reserve, for the hour. 1 / hour Calculated Yes
MCPCRR m $/MW per hour Market Clearing Price for Capacity for Responsive Reserve by market—The MCPC for Responsive Reserve from the market m, for the hour. 1 / hour No RTPCRR q, m MW Procured Capacity for Responsive Reserve by QSE by market—The portion of QSE q Ancillary Service Offers cleared in the market m to provide Responsive Reserve, for the hour. 1 / hour Yes PCRRR r, q, m MW Procured Capacity for Responsive Reserve from Resource per Resource per QSE by market—The Responsive Reserve capacity quantity awarded to QSE q in the market m for Resource r for the hour. 1 / hour Yes Non-Spin Description If a SASM is executed for one or more Operating Hours for any reason, ERCOT shall pay QSEs for their Ancillary Service Offers cleared in the SASM, based on the MCPC for that SASM and that service. By service and by SASM, the payment to each QSE for a given Operating Hour is calculated as follows: (PR 6.7.1(1)) These particular bill determinants, PCRUAMT and PCRU, will need to be calculated and recorded on a per Supplemental Ancillary Service Market basis. This is necessary to maintain Market Integrity and allow for multiple market situations. Payment is calculated by QSE for each hour of the Operating Day within the Market. Calculation Variable Unit Description Interval Frequency Source RTPCNSAMT q, m $ Procured Capacity for Non-Spin Amount by QSE by market—The payment to QSE q for Ancillary Service Offer cleared in the market m to provide Non-Spin, for the hour. 1 / hour Calculated Yes MCPCNS m $/MW per hour Market Clearing Price for Capacity for Non-Spin by market—The MCPC for Non-Spin from the market m, for the hour. 1 / hour No RTPCNS q, m MW Procured Capacity for Non-Spin by QSE by market—The portion of QSE q’s Ancillary Service Offer cleared in the market m to provide Non-Spin, for the hour. 1 / hour Yes PCNSR r, q, m MW Procured Capacity for Non-Spin from Resource per Resource per QSE by market—The Non-Spin capacity quantity awarded to QSE q in the market m for Resource r for the hour. 1 / hour Yes
RRRP q, m MW Responsive Reserve Replacement per QSE per market—The Responsive Reserve capacity that was a portion of the Ancillary Service Supply Responsibility of QSE q but is replaced in the market m, for the hour. 1 / hour Yes RTRRAMT q $ Real-Time Responsive Reserve Amount per QSE—The adjustment to QSE q’s share of the costs for Responsive Reserve, for the hour. 1 / hour Calculated Yes DARRAMT q $ Day-Ahead Responsive Reserve Amount per QSE—QSE q’s share of the DAM cost for Responsive Reserve, for the hour. 1 / hour Calculated Yes Non-Spin Description Each QSE, on whose behalf ERCOT purchases Ancillary Service capacity in the DAM and SASMs (if any), is charged for its net share of the costs ERCOT incurred for each service. For each such QSE, its share of the DAM costs has been calculated in Section 4.6.4, Settlement of Ancillary Services Procured in the DAM; its share of the net total costs incurred in both DAM and SASMs less its DAM charge is calculated in the following three sections. The net total costs for Non-Spin for a given Operating Hour is calculated as follows: The Procured Capacity for Non-Spin Amount Total per Market is summed across all markets, including the Day-Ahead Market and the Supplemental Ancillary Service Markets, and then summed with the Failure to Provide Non-Spin Capacity Amount Total to determine the total cost, ERCOT-Wide for each hour of the Operating Day. Calculation Variable Unit Description Interval Frequency Source NSCOSTTOT $ Non-Spin Cost net total costs for Non-Spin for the hour. 1 / hour Yes PCNSAMTTOT m $ Procured Capacity for Non-Spin Amount Total by market—The total payments to all QSEs for the Ancillary Service Offers cleared in the market m for Non-Spin, for the hour. 1 / hour Yes PCNSAMT q, m $ Procured Capacity for Non-Spin Amount per QSE by market—The payment to QSE q for its Ancillary Service Offers cleared in the market m for Non-Spin, for the hour. 1 / hour Yes
Calculation Variable Unit Description Interval Frequency Source VSSVARAMT q, r $ Voltage Support Service var Amount per QSE per Generation Resource - The payment to QSE q for the VSS provided by Generation Resource r, for the 15-minute Settlement Interval. 4 / Hour Calculated Yes VSSVARPR Voltage Support Service var - The price for instructed Mvar beyond a Generation Resource’s URL currently is $2.65/Mvarh (based on $50.00/installed kvar). 4 / Hour No VSSVARLAG q, r Mvarh Voltage Support Service var Lagging per QSE per Generation Resource - The instructed portion of the Reactive Power above the Generation Resource’s lagging URL for Generation Resource r represented by QSE q, for the 15-minute Settlement Interval. 4 / Hour Yes VSSVARLEAD q, r Mvarh Voltage Support Service var Leading per QSE per Generation Resource - The instructed portion of the Reactive Power below the Generation Resource’s leading URL for Generation Resource r represented by QSE q, for the 15-minute Settlement Interval. 4 / Hour Yes VSSVARIOL q, r Mvar Voltage Support Service var Instructed Output per QSE per Generation Resource—The instructed Reactive Power output level of Generation Resource r represented by QSE q, lagging Reactive Power if positive and leading Reactive Power if negative, for the 15-minute Settlement Interval. 4 / Hour Yes RTVAR q, r Real-Time var per QSE per Resource—The netted Reactive Energy measured for Generation Resource r represented by QSE q, for the 15-minute Settlement Interval. 4 / Hour Yes URLLAG q, r Mvar Unit Reactive Limit Lagging per QSE per Resource—The Unit Reactive Limit for lagging Reactive Power of the Generation Resource r represented by QSE q as determined in accordance with these Protocols. Its value is positive. 4 / Hour Yes URLLEAD q, r Mvar Unit Reactive Leading per QSE per Resource—The Unit Reactive Limit for leading Reactive Power of the Generation Resource r represented by QSE q as determined in accordance with these Protocols. Its value is negative. 4 / Hour Yes VSSEAMT q, r $ Voltage Support Service Energy Amount per QSE per Generation Resource—The lost opportunity payment to QSE q for ERCOT-directed VSS from Generation Resource g for the 15-minute Settlement Interval. 4 / Hour Yes
Payments and Charges for PTP Obligations Settled in Real-Time Description ERCOT shall pay or charge the QSE of each PTP Obligation acquired in the DAM the difference in Real-Time Settlement Point Prices between the sink Settlement Point and the source Settlement Point. The payment or charge to each QSE for a given Operating Hour of its cleared PTP obligations with each pair of source and sink Settlement Points is calculated as follows: Calculation Variable Unit Description Interval Frequency Source RTOBLAMT q, (j, k) $ Real-Time Obligation Amount per QSE per pair of source and sink—The payment or charge to QSE q for its PTP Obligations with the source j and the sink k settled in Real-Time, for the hour. 1 / Hour Calculated Yes RTOBLPR (j, k) $/MW per hour Real-Time Obligation Real-Time price of the PTP Obligation, for the hour. 1 / Hour Calculated Yes RTSPP j, i $/MWh Real-Time Settlement Point Price at source per interval—The Real-Time Settlement Point Price at the source j for the 15-minute Settlement Interval i. 4 / Hour No k, i $/MWh Real-Time Settlement Price at sink per interval—The Real-Time Settlement Point Price at the sink k for the 15-minute Settlement Interval i. 4 / Hour No RTOBL q, (j, k) MW Real-Time Obligation per QSE per pair of source and sink—The number of QSE q’s PTP Obligations for the source j and the sink k settled in Real-Time for the hour. 1 / Hour Yes q $ Real-Time Obligation Amount QSE Total per QSE—The net total payment or charge to QSE q of all its PTP Obligations settled in Real-Time, for the hour. 1 / Hour Calculated Yes Payments and Charges for PTP Obligations Settled in Real-Time in the Event the DAM is not Executed
Charges for PTP Option Bids Awarded Description shall charge each CRR Account Holder of its PTP Option bids awarded in each CRR Auction. (PR 7.5.6.2 (2)) Calculation Variable Unit Description Interval Frequency Source OPTPAMT crrh, (j, k), a $ PTP Option Purchase Amount per CRR Account Holder per source and sink pair per CRR charge calculated for CRR Account Holder crrh of the MW quantity that represents the total PTP Option bids with the source j and the sink k awarded in CRR Auction a, for the hour. 1 / Hour Calculated Yes OPTPR (j, k), a $/MW per hour PTP Option per source and sink pair per CRR Auction—The clearing price of a PTP Option with the source j and the sink k in CRR Auction a, for the hour. 1 / Hour No OPTP crrh, (j, k), a MW PTP Option Purchase per CRR Account Holder per source and sink pair per CRR Auction—The MW quantity that represents the total of CRR Account Holder ccrh’s PTP Option bids associated with the source j and the sink k awarded in CRR Auction a, for the hour. 1 / Hour ZaiNet Yes Charges for FGR Bids Awarded Description ERCOT shall charge each CRR Account Holder of its flowgate bids awarded in each CRR Auction. (PR 7.5.6.2 (3)) Calculation Variable Unit Description Interval Frequency Source
Charges for PCRR Options (OOS) Description For pre-assigned PTP Options allocated before each CRR Auction (annual or monthly auction), ERCOT shall charge each CRR Account Holder. (PR 7.5.6.3 (2)) Calculation Variable Unit Description Interval Frequency Source PCRROPTAMT crrh, (j, k), a, tech $ PCRR PTP Option Amount per CRR Account Holder per source and sink pair per CRR Auction by resource technology—The charge calculated for CRR Account Holder crrh of the MW quantity that represents its PTP Options associated with the source j and the sink k allocated before CRR Auction a based on Resources of the technology tech, for the hour. 1 / Hour Calculated Yes PCRROPTF tech PCRR PTP Option pricing Factor per resource technology—The pricing factor of pre-allocated PTP Options based on Resources of the technology tech. See Section 7.4.2, PCRR Allocation Terms and Conditions, item (f) (i). 1 / Hour ERCOT No OPTPR (j, k), a $/MW per hour PTP Option per source and sink pair per CRR Auction—The clearing price of a PTP Option with the source j and the sink k in CRR Auction a, for the hour. 1 / Hour ERCOT No PCRROPT crrh, (j, k), a, tech MW PCRR PTP Option per CRR Account Holder per source and sink pair per CRR Auction by resource technology—The MW quantity that represents the total of CRR Account Holder crrh’s PTP Options with the source j and the sink k allocated before CRR Auction a based on Resources of the technology tech, for the hour. 1 / Hour ZaiNet Yes Monthly CRR Zonal Revenue Description ERCOT shall determine, for each month, the CRR Monthly Revenues (CMR). The net CRR Auction Revenue produced from CRRs cleared and paid for in each CRR Auction that source from a Settlement Point within a 2003 ERCOT CMZ and sink at a Settlement Point located within the same 2003 ERCOT CMZ shall be distributed on a zonal Load Ratio Share basis. (PR 7.5.7 (5))
Additional Refunds to DA CRR Account Holder Description On a monthly basis, additional refunds may be paid to the CRR Owners due to the charges that are caused by Real-Time CRR shortfall, as described in paragraph (4) of Section 7.9.3.3, Shortfall Charges to CRR Owners. (PR 7.9.3.4 (2)) Calculation Variable Unit Description Interval Frequency Source DACRRRAMT o $ CRR Refund Amount per owner—The additional refund to the Day-Ahead CRR Owner o due to Real-Time shortfall charges for the month. 1 / Hour Calculated Yes RTCRRSAMTMTOT $ Real-Time CRR Shortfall Amount Monthly total Real-Time shortfall charge for CRRs settled in Real-Time for the month. 1 / Hour Calculated Yes RTCRRSAMTTOT h $ Real-Time CRR Shortfall Amount Total—The total Real-Time shortfall charge for CRRs settled in Real-Time for the hour. 1 / Hour Calculated Yes DACRRSAMTRS o none Day-Ahead CRR Short Amount Ratio Share per owner—The ratio of the Day-Ahead CRR Owner o’s additional total shortfall-charge to the total of all the Day-Ahead CRR Owners’ additional shortfall charges, for the month. 1 / Hour Yes o $ Day-Ahead CRR Short Ratio Real-Time Amount Total per owner—The total of shortfall charges to CRR Owners for all Operating Hours in the Month. 1 / Hour Calculated Yes