| # | Title | Description | Date Posted | Sponsor | Urgent | Protocol Sections | Current Status | Effective Date(s) |
|---|---|---|---|---|---|---|---|---|
| PRR211 | Balancing Energy Bid Curves for RPRS | Software unable to support unit specific BE bid curves by June 1, 2001. The software can support 1 UBES bid curve per zone per QSE & 1 DBES bid per zone per QSE. There is no manual work-around. | 03/12/2001 | ERCOT | No | 4.4.16(3) | Approved | |
| PRR212 | Surety Bond | Required by PUCT. Allows a QSE to post a surety bond as an alternative to meeting ERCOT creditworthiness requirements. | 03/12/2001 | ERCOT | No | 16.2.5.1.2(3) | Approved | |
| PRR213 | Dynamic Schedules Generation | Requests that a QF have a choice of QSE to maintain dynamic flexibility. | 03/28/2001 | Calpine | Yes | 4.9.2 | Withdrawn | |
| PRR214 | EPS Meter Communication | Allows a TDSP to provide other ERCOT approved communication technology for ERCOT to use in acquiring data from EPS Meters. | 03/28/2001 | TXU | Yes | 10.12.1(2) | Approved | |
| PRR215 | Revision of Availability for Responsibility Transfers | PIP151, Responsibility Transfers will be available on January 1, 2002. | 03/29/2001 | Calpine | Yes | 4.9.4 | Approved | |
| PRR216 | Bid Clearing | Clarifies that unselected bids are cleared when a market closes & specifies that bids must be resubmitted if reconsideration is desired. | 04/06/2001 | ERCOT | Yes | 4.4.11 | Approved | |
| PRR217 | Distribution Loss "K" Factors | Revises the K-factor range from 0.0-0.1 to 0.0-1.2. | 04/10/2001 | ERCOT | Yes | 13.3.1.1 | Approved | |
| PRR218 | Responsibility Assignment for RPC & AVR | Change the responsibility for reactive power capability & automatic voltage regulator (AVR) testing from the QSE to the Generation Entity. | 04/16/2001 | FPL Energy | No | 6.10.3.5 | Approved | |
| PRR219 | Frequency Level Deviation | Change the level of frequency deviation at which ERCOT measures & records various system operating data from 0.375 to 0.175 Hz. | 04/16/2001 | FPL Energy | No | 6.10.5.4 | Approved | |
| PRR220 | Section 17 Language Clarification | Change a description of the Protocols as including the Operating Guides. | 04/16/2001 | FPL Energy | No | 17.6 | Approved | |
| PRR221 | Responsive Reserve Resources (Hydro) | Required by PUCT. Removes the limits the limits on the provision of Responsive Reserve Service by hydroelectric resources. | 04/16/2001 | LCRA | Yes | 6.1.4 | Approved | |
| PRR222 | Amend Market Solution Definition | Required by PUCT. Amends the "Market Solution" definition. | 04/16/2001 | ERCOT | Yes | 2.1 | Approved | |
| PRR223 | Agreements & Protocols Deviations | Required by PUCT. Establishes the requirement that "known" deviations between Agreements & the Protocols are to be expressly stated & terms are effective only upon ERCOT BOD approval. | 04/16/2001 | ERCOT | Yes | 1.1 | Approved | |
| PRR224 | Changes to Load Profiles Based on Disputes | Required by PUCT. Requires TDSPs to change the assignment of a Load Profile or Weather Zone based on the outcome of a dispute. | 04/16/2001 | ERCOT | Yes | 18.4.4.1 | Approved | |
| PRR225 | TOU Metering | Required by PUCT. Language addition: "within ever investor-owned TDSP territory, additional TOU schedules may be implemented if approved by the PUCT." | 04/16/2001 | ERCOT | Yes | 18.7.1.4(2) | Approved | |
| PRR226 | Interim Manual Switching Deadlines | Required by the PUCT. Clarifies that deadlines for the interim manual switching process are the same as those for the automated process. | 04/16/2001 | ERCOT | Yes | 11.1.10 | Approved | |
| PRR227 | ERCOT Sole Discretion | Required by PUCT. Clarifies the extent of ERCOT's sole discretion. | 04/17/2001 | ERCOT | Yes | 1.2 | Approved | |
| PRR228 | Non-ERCOT LSE Fee | Clarifies the application of the Non-ERCOT LSE fee by replacing the CR reference with LSE. | 04/16/2001 | ERCOT | Yes | 9.7.3 | Approved | |
| PRR229 | Pre-Assigned TCRs | Required by PUCT. Establishes that pre-assigned TCRs are subject to change or elimination upon ERCOT BOD approval or PUCT order. | 04/16/2001 | ERCOT | Yes | 7.5.4.4 | Approved | |
| PRR230 | REC Administrative Fee | Required by PUCT. Deletes paragraph 9.7.2 & designates as "reserved." | 04/16/2001 | ERCOT | Yes | 9.7.2 | Approved | |
| PRR231 | Sect 9.5.5 Language Clarification | Required by PUCT. Replaces "proven" with "alleged." | 04/16/2001 | ERCOT | Yes | 9.5.5 | Approved | |
| PRR232 | PUCT Notification | Required by PUCT. Establishes that ERCOT is to notify the PUCT if a TDSP fails to meet its customer switch responsibilities. | 04/16/2001 | ERCOT | Yes | 15 | Approved | |
| PRR233 | Balancing Energy Offer Cap | Required by PUCT. Establishes an offer cap on Balancing Energy of $1,000. | 04/17/2001 | ERCOT | Yes | 6.5.2 | Approved | |
| PRR234 | RMR | Required by PUCT. This revision gives the RMR unit owner the option of receiving 10% of positive margins for energy generated in excess of the amount that the unit is obligated to produce under its RMR contract. The RMR owner has the choice of selecting 1 of 2 options no more frequently than on a yearly basis, prior to the time in which the selected option will be in effect. | 04/17/2001 | ERCOT | Yes | 6.8.3.7, 22F | Approved | |
| PRR235 | Adj. Of Unselected AS bids | Required by PUCT. Defines an activity rule that permits only downward adjustments of unselected Ancillary Service bids & allows unselected bids by a QSE to be withdrawn only in descending order of bid price. | 04/17/2001 | ERCOT | Yes | 4.5.9, 6.6.2 | Approved | |
| PRR236 | Loss Compensation Outside the IDR Meter Permitted | Provides a mechanism to perform distribution loss compensation outside the IDR meter. | 04/16/2001 | ERCOT | Yes | 13.1.1 | Approved | |
| PRR237 | Federal Resources | Required by PUCT. Gives ERCOT the authority to grant waivers to federally owned & operated hydroelectric facilities from registration requirements & execution of Resource Agreements. | 04/20/2001 | Tex-La | Yes | 4.4.5, 16.5.1.1 | Approved | |
| PRR238 | Meter Read Data | Required by PUCT. Provides a deadline for ERCOT to present meter-read data to CRs for the interim period before the system vendor can ensure meeting deadlines. | 04/17/2001 | ERCOT | Yes | 15.1.1.10 | Approved | |
| PRR239 | Reg. Of Texas Non-ERCOT TDSPs | Requires Non-ERCOT TDSPs operating in the state of Texas where Customer Choice is in effect to register with ERCOT. | 04/20/2001 | ERCOT | Yes | 16.4 | Approved | |
| PRR240 | Trans. Billing Determinant Calc | Entirely removes Section 9.8.2 - Monthly Determinant Data From ERCOT & clarification edits to 9.8.1 - item#3. | 04/24/2001 | ERCOT | Yes | 9.8 | Approved | |
| PRR241 | UFE Analysis | 1) Revises the beginning date for UFE analysis in Section 11.5.1 to January 2002. 2) Modifies the language in 11.5.2.1 to accommodate a December 1, 2001 implementation timeline. 3) Adds language in 11.5.2.1 to require TDSPs to leave "old control area" boundary meters in place until UFE analysis zones are defined. Definition of zones to take place after June 1, 2001 but supporting December 1, 2001 deadline. | 04/24/2001 | ERCOT | Yes | 11.5 | Approved | |
| PRR242 | Waiver for Existing Contracts | TNMP requests that Protocol Section 10.3.2.3 be amended for existing netting agreements which terminate between June 1, 2001 & December 31, 2001 by allowing an exception for generation netting which TNMP states does not otherwise affect ERCOT or competition. | 04/27/2001 | TNMP | Yes | 10.3.2.3 | Withdrawn | |
| PRR243 | Acceptance of Non-ERCOT Transactions | An impact analysis was done by Accenture and it was determined that it would be costly and time consuming (in terms of system performance) to validate and reject pass through usage transactions for Non-ERCOT TDSP 867_03 transactions. Therefore, the systems will not reject transactions from Non-ERCOT TDSPs who choose to send the 867_03 to ERCOT. | 05/03/2001 | ERCOT | Yes | 15.1 | Approved | |
| PRR244 | Provisional Qualification for AS Providers | Allows ERCOT to grant a ninety (90) day Provisional Qualification period during which additional testing may be rescheduled for QSEs that have encountered non-critical technical issues during Ancillary Services testing. | 05/11/2001 | ERCOT | Yes | 6.10.3 | Approved | |
| PRR245 | Ratcheting Down of OOME Up Payments | Apply a ratcheting down mechanism for OOME Up energy payment. | 05/17/2001 | TXU | Yes | 6.8.2.2 | Approved | |
| PRR246 | Protocol Effective Date | Change the effective date so that it reflects the actual start of the market. | 05/22/2001 | ERCOT | Yes | 1.7 | Approved | |
| PRR247 | Ratcheting of OOME Payments | Apply a ratcheting down mechanism for OOME Up energy payment and a ratcheting up mechanism for OOME Down energy payments. | 05/25/2001 | LCRA | No | 6.8.2.2 | Approved | |
| PRR248 | TX Non-ERCOT LSE Registration | Creates new Protocol Section 16.11 to require Non-ERCOT Load Serving Entities operating in the state of Texas to register with ERCOT. | 05/31/2001 | AEP/ Entergy | Yes | 16.11 (new) | Approved | |
| PRR249 | QSE Creditworthiness Monitoring | Update creditworthiness monitoring requirements. | 06/13/2001 | ERCOT | Yes | 16.2.8 | Approved | |
| PRR250 | NOIE Consumption by ESI-ID | Allows the QSE for a NOIE to see the consumption data for an ESI-ID for that NOIE. | 06/20/2001 | LCRA | No | 15.2 & 15.3 | Withdrawn | |
| PRR251 | Update Texas SETs | Update the Protocols to match SET transactions. These are Non-ERCOT transaction updates. | 06/29/2001 | ERCOT | No | 19.3.1 | Approved | |
| PRR252 | Protocol Effective Date | Revise the Protocols to reflect the actual single control area operation start date of the market. | 07/03/2001 | ERCOT | Yes | 1.7 | Approved | |
| PRR253 | EPS Meter Clock Time Maintenance | The proposed language allows TDSP and EPS Meters to stay on another time reference with the meter data adjusted to Central Prevailing Time. | 07/06/2001 | STEC | No | 10.9.1(7), 10.9.2(5) | Approved | |
| PRR254 | New Protocol Chapter - Texas Test Plan Team Market Testing | To define the Market Testing Process. | 07/06/2001 | Reliant | No | 23 [new] | Approved | |
| PRR255 | VEE Standard for TDSP Metered Entities | The Metering Subcommittee is requesting a language modification to section 10.11.3. The language modification will incorporate a specific reference to the Uniform Business Practices standard for Validation, Estimation, and Editing. | 07/09/2001 | ERCOT | No | 10.11.3 | Approved | |
| PRR256 | REC Protocols Revisions from PUCT Order in Docket N. 23802 | The PUCT ordered these changes in its final order issued in Docket No. 23802, Proceeding to Consider Section 14 of the ERCOT Protocols (Severed From Docket No. 23220). | 07/10/2001 | ERCOT | No | 14.9, 14.10.2 | Approved | |
| PRR257 | Provision of passwords to the Resource Entity for EPS metered Facilities | Provision of passwords to the Resource Entity for EPS metered Facilities | 07/10/2001 | ERCOT | No | 10.1 | Approved | |
| PRR258 | Notification Automation if Permit Required | To facilitate Move-ins where a permit is required. | 07/13/2001 | Green Mountain Energy/ RMS | Yes | 15.1.1.2, 15.1.1.7, 15.1.4.7.1-4 | Approved | |
| PRR259 | Process Automation for Un-executable Move-ins | To facilitate completion of Move-ins that are unexecutable. | 07/13/2001 | Green Mountain Energy/ RMS | Yes | 15.1.4.5 | Approved | |
| PRR260 | Auto Purge Process If Permits Not Received | To facilitate purging of Move-ins that require a permit, but the permit is not received by the TDSP. | 07/13/2001 | Green Mountain Energy/ RMS | Yes | 15.1.1.7, 15.1.4.5 | Approved | |
| PRR261 | CR Notification | Add a notifying element for the CRs to identify when date changes have created a gap in time. | 07/13/2001 | Green Mountain Energy/ RMS | Yes | 15 | Approved | |
| PRR262 | CSA CR Continuity of Service | To provide the CSA CR with continuity of service. | 07/13/2001 | Green Mountain Energy/ RMS | Yes | 15.1.5.1 | Approved | |
| PRR263 | Update Move-in Reject Reasons | Add new rejection for following reason: "There is already a move in request in progress, not first in for the same requested date." | 07/13/2001 | Green Mountain Energy/ RMS | Yes | 15.1.4.9 | Approved | |
| PRR264 | Move-in W/O Meter Installed | Allows the TDSP to return as much premise info as possible to the CR in the 2 day window. | 07/19/2001 | Green Mountain Energy/ RMS | Yes | 15.1.4.5, 15.1.4.6 | Approved | |
| PRR265 | Priority Move-in | To facilitate passing critical info to the TDSP so the Move-in can be expedited and scheduled as requested. | 07/19/2001 | Green Mountain Energy/ RMS | Yes | 15.1.4.1, 15.1.4.3, 15.1.4.4, 15.1.4.5 | Approved | |
| PRR266 | Concurrent Processing | Update Concurrent Processing procedures. | 07/20/2001 | ERCOT | Yes | 15.1.1.9, 15.1.3, 15.1.3.4 | Approved | |
| PRR267 | Black Start Basic Startup Test Interval | Clarifies requirements for annual testing of black start units. | 07/26/2001 | LCRA | No | 6.10.3.6 | Approved | |
| PRR268 | Day Ahead Scheduling Process Time Line Change Request | Extends the time line for Day Ahead Scheduling Process to 1830 from 1630. The extension to start at 1400. | 07/26/2001 | TXU | Yes | 4.1.1, 4.4.14 to 4.4.17 | Approved | |
| PRR269 | Small Renewable Production Facilities Metering Requirement | Relax the requirement for IDR meters and the provision of generation meter data to ERCOT for renewable energy production facilities that are less than 50 kW and are interconnected to operate in parallel with a NOIE TDSP distribution system. | 07/30/2001 | City Public Service of San Antonio | No | 10.2.2, 10.9 | Approved | |
| PRR270 | Unit Specific Dec Premiums | Revise the Protocols to reflect that the system selects and deploys Resources for unit-specific deployments based on the price that results from subtracting the premium from the MCPE. | 08/02/2001 | ERCOT | Yes | 6.7.1.2 (5) | Approved | |
| PRR271 | Local Congestion | Revise the Protocols to reflect that ERCOT is using OOME Up and OOME Down for settlement of energy deployed to relieve Local Congestion. | 08/02/2001 | ERCOT | Yes | 6.7.1.2 (10) | Approved | |
| PRR272 | Add Distribution Zone to Data Query | The addition of the Distribution Zone (DZ) field is needed to identify which power pool an ESI ID is located. | 08/17/2001 | AEP | No | 15.2 | Approved | |
| PRR273 | Post MCPC at Award Time | Remove no earlier than 1430 from 4.4.13. | 08/20/2001 | ERCOT | Yes | 4.4.13 | Approved | |
| PRR274 | Remove Expiration Time for BES & Unit Premium Bids | Remove expiration time of bids for hourly BES bid curves and unit specific bid premiums entered in the hourly resource plan. | 08/20/2001 | ERCOT | Yes | 4.5.3(5), 4.5.11.4.1(5) | Approved | |
| PRR275 | AS Mismatch Language Revision | Revise to reflect that AS mismatches will be adjusted to match the Resource. Software acquires AS based on AS scheduled by Resource and is unable to adjust to match the Obligation because of multiple inter-QSE trades. | 08/20/2001 | ERCOT | Yes | 4.7.2(3)(b) | Approved | |
| PRR276 | Adjust BENA Computation | Adjust the computation of the Balancing Energy Neutrality Adjustment to more accurately assign the payments and charges to Load Serving Entities. | 08/20/2001 | Austin Energy/ CPS San Antonio | Yes | 9.6.1 | Withdrawn | |
| PRR277 | Clarify SCF Fee Determination | Sec. 7.3.3.1(2) of the ERCOT Protocols states that Any shortages, not covered by ERCOTs line of credit, will be uplifted to all QSEs representing Load on a Load Ratio Share. This PRR clarifies that such uplift should occur by adjusting the Forecasted Fee in the System Congestion Fund calculation, rather than uplifting congestion costs in excess of congestion fund revenues through the Balancing Energy Neutrality Adjustment, as is current practice by ERCOT. | 08/20/2001 | CPS-San Antonio | Yes | 7.3.3.1 | Withdrawn | |
| PRR278 | RMR, Synchronous Condenser, Black Start Revisions | Resolve conflicts between Protocol language and contract language. Revise Protocol formulas to be consistent with contract language and add clarifying language to the Protocols. | 08/28/2001 | ERCOT | Yes | 6.8.3 & 6.8.5 | Approved | |
| PRR279 | Responsibility Transfers for Capacity Auction Products | The PUCT has required IOUs to sell at auction 15% of their capacity in 25 mw blocks. One of the products from these blocks is balancing energy through the use of a Responsibility Transfer. Over 200 possible RspT will place a burden on ERCOT as well as the seller. This is a simpler method for the buyer to bid in the balancing energy market but have the seller receive a message rather than a continuous signal. | 08/28/2001 | TXU | Yes | 4.9.5 | Approved | |
| PRR280 | Zonal Congestion Costs | Clarification that costs for resolving Zonal Congestion should be counted toward the $20 million threshold for the transition for the direct assignment of CSC Congestion resolution costs. | 08/31/2001 | Dynegy | Yes | 7.3 | Approved | |
| PRR281 | Allowance for Aggregated Site-Specific Resource Dispatch Instructions (v2) | This is version 2 of the original PRR submitted on 9/10/2001. This revision is intended to allow for site-specific dispatch of resources & would not be mandatory for all resource owners. V2 redefines sections of the Protocols where change is necessary & requests a Normal timeline for implementation. This PRR was originally entitled, Change ERCOT Deployment Instructions to Settlement Meter Specific. Due to the emergence of split metering, netting behind meters, & other factors the reference to instructions to the settlement meter was dropped in favor of the more accurate description of aggregated site-specific dispatch of resources. | 05/24/2002 | Calpine | No | various | Withdrawn | |
| PRR282 | Define OOME as an Instructed Deviation | 09/11/2001 | Enron | Yes | Withdrawn | |||
| PRR283 | ERCOT Read Meter Data | Changes PIP 204 to provide Market Participants Data for ERCOT Populated ESI IDS via a data extract instead of 867_03 EDI transactions and adds the requirement to provide Market Participants EPS Meter Recorder (RIDs) level data via a data extract. | 09/06/2001 | ERCOT | Yes | 11.1.10 | Approved | |
| PRR284 | Adjusted Computation of BENA | Adjust the computation of the Balancing Energy Neutrality Adjustment to more accurately assign the payments and charges to Load Serving Entities. This PRR, combined with PRR277 (to be modified consistent with PRR280 such that all zonal congestion is collected via the SCF) will be effective during the CSC uplift period. | 09/12/2001 | Austin Energy/ CPS San Antonio | Yes | 9.6.1 | Withdrawn | |
| PRR285 | OOMC Premium | Clarify the language regarding payment when the OOMC payment is not sufficient to cover the cost of providing RPRS service and provide a reasonable premium. The proposed language will make the form of the OOMC language consistent with the form of the OOME payment. | 09/12/2001 | AEP | Yes | 6.8.2.1(6) | Approved | |
| PRR286 | Smoothing Algorithm | This revision will change the calculation of the Schedule Control Error equation. | 09/12/2001 | AEP | No | 6.10.4.2 | Withdrawn | |
| PRR287 | Responsibility Transfers (Dynamic Scheduling) | These revisions clarify that dynamic scheduling of resources between QSEs is to be allowed, as well as clarify details of responsibility transfers to conform with ERCOT systems capability. | 01/25/2002 | Dynegy | No | 4.9 | Approved | |
| PRR288 | TDSP Metered Entities | This PRR is similar to PRR269. It modifies 269PRR as follows, Relax the requirement for IDR meters and the provision of generation meter data to ERCOT for renewable energy production facilities that are less than 50 kW & not wanting compensation for net output. These customers are interconnected to operate in parallel with a NOIE or OIE TDSP distribution system. Resource facilities wanting compensation will need to follow standard protocol requirements of generation entities (IDR metering, an assigned Resource Identifier (RID), need to complete a Resource Application, etc.). | 09/24/2001 | TXU | No | 10.2.2; 10.9 | Approved | |
| PRR289 | Block Load Transfers | Simplify the way ERCOT protocols accommodate Block Load Transfers and make the treatment of ERCOT and Non-ERCOT loads similar. Removed boxed text (pip 209) as the language should be capable of being implemented immediately with no changes to the system design. | 11/05/2001 | AEP | Yes | 5.7 | Approved | |
| PRR290 | Balancing Energy Down Bids | An across-the-board mandatory balancing down requirement can prevent QFs such as Gregory from providing contracted service to their thermal host. This reduces the reliability of QF service, threatens the thermal hosts service, potentially violates PURA §39.151 (l) by interrupting an internal process operation associated with an industrial generation facility, and is opposed to federal policies favoring QF development. | 10/04/2001 | Gregory Power Partners, L.P. | No | 4.4.5 | Withdrawn | |
| PRR291 | Section 16 Testing Requirements | Adds language for Retail Market testing. | 10/09/2001 | TXU | No | 16.2.1, 16.3.1, 16.4 & 16.6 | Approved | |
| PRR292 | Revise Resource Specific Payment Formula | Revise the formulas to reflect the language. | 10/10/2001 | ERCOT | Yes | 7.4.3.1 & 7.4.3.2 | Approved | |
| PRR293 | Uncontrollable Renewable Resources | Request Boxing of Existing Language since functionality does not exist to provide for this functionality and there is no viable manual work-around. | 10/10/2001 | ERCOT | Yes | 6.8.1.15.1 | Withdrawn | |
| PRR294 | Clarify LSE Load Ratio Share Data Requirements | Clarifies the requirements of PIP 144. | 10/12/2001 | ERCOT | No | 6.3.1 & 4.4.4 | Approved | |
| PRR295 | Obligation Default Charges | Provide formulas to reflect the language for the treatment of default QSE financial responsibility. | 10/15/2001 | ERCOT | Yes | 6.9.1 | Approved | |
| PRR296 | Zonal Congestion Implementation Date | The BOD voted to approve a date of 2/15/02 for the implementation of direct assignment of zonal congestion costs. The availability of auctioned and pre-assigned TCRs may be on or after January 1, 2002. | 10/19/2001 | CPS-San Antonio | Yes | 7.3.3; 7.3.4; 7.5.1 & 7.5.4.4 | Approved | |
| PRR297 | LaaR & BULs Provisional Qualification | This revision provisionally qualifies certain loads that were served on an interruptible tariff, participated in a group load curtailment tariff, or participated in a direct load control program on August 1, 2001 to act as a load acting as a resource (LaaR) or a balancing up load (BUL), provided the load can meet the metering and performance criteria outlined in the Protocols. | 10/25/2001 | Demand Side Task Force | Yes | New language to be added after 6.10 | Approved | |
| PRR298 | Revise Settlements Calendar | This PRR requests changes to the Settlement Payment Calendar for Initial Statements and Final Statements only. The payment dates are kept the same according to the settlement calendar by changing the due dates of invoices from net-30 to either net-16 or net-9, depending on the preferred 2 or 3-week change approved. | 10/29/2001 | ERCOT | Yes | 9.2.3; 9.2.4; 9.2.5; 9.3 | Approved | |
| PRR299 | TCR Congestion Management | Changes the 60-day notice requirement to 30-days for the initial annual TCR auction only. | 11/06/2001 | Enron | Yes | 7.5.4.2.1 | Approved | |
| PRR300 | TCR Congestion Management | Establish Congestion Management guidelines and requirements for February 15, 2002. Strike System Congestion Fund upon conversion to direct assignment of Zonal Congestion costs. Strike Zonal Congestion Tracking upon conversion to direct assignment of Zonal Congestion costs. | 11/15/2001 | Dynegy | Yes | 2; 6; 7; 9; 16 | Approved | |
| PRR301 | Over scheduling Load Imbalance Limits | Provides an upper limit for Load Imbalance credits to QSEs when the QSEs load is significantly overscheduled. | 11/28/2001 | CPS-San Antonio | No | 6.9.5.2 | Withdrawn | |
| PRR302 | BUL Capacity Payment Calculation | This revision establishes a baseline approach for calculating the BUL capacity payment based on historical data. The baseline would be based on a 10-day average of actual metered load. The baseline will be adjusted to actual load in the two hours prior to notice to reflect temperature sensitive load and to address gaming concerns. | 11/29/2001 | Demand Side Task Force | No | 6.8.1.14 & 6.10.5.2 | Approved | |
| PRR303 | Move-in Rejections | The stacked move in resolution modified the Not First In validation to allow a Move In when another Move In is pending, but only when the requested Move In is LATER than the pending Move In. | 12/07/2001 | Reliant | Yes | 15.1.4.9 | Approved | |
| PRR304 | Unexecutable Move-in | The new 814_28 and 814_29 notification request/response will be used to communicate that the service order is unexecuted. The header will include the permit flag, the un-executable flag, and the same Reason codes as on the 650_02. | 12/10/2001 | Green Mountain Energy | Yes | 15.1.4.5; 15.1.4.7.1-4 [new] | Withdrawn | |
| PRR305 | Inter-QSE Trades Under DA Cost Allocation | Clarifies language and formulae in Section 7.3.4 to indicate the recognition of Inter-QSE trades | 12/19/2001 | CPS-San Antonio | Yes | 7.3.4 | Approved | |
| PRR306 | TCR Ownership Limitation | Minor revision to existing Protocol 7.5.7 referencing new section 7.5.9 regarding limitation and ownership of TCRs to create an effective market for TCRs and adding new Section 7.5.9 to limit TCR ownership. | 01/14/2002 | TXU | No | 7.5.9 | Approved | |
| PRR307 | Controllable Resources | This revision defines Load which can provide Regulation Service. | 01/03/2002 | Ridge Energy Storage | No | 2.1, 5.6.7, 6.1.2, 6.1.3, 6.1.4, 6.5.1.1, 6.5.2, 6.5.3 6.5.4, 6.5.6, 6.7.3, 6.8.1.12, 6.10.4.4 | Approved | |
| PRR308 | Settlements Calendar Revision | This Protocol revision is written to request changes to the Settlement Payment Calendar for Initial Statements and Final Statements only. The payment dates are kept the same according to the settlement calendar by changing the due dates of invoices from net-30 to either net-16 or net-9, depending on the preferred 2 or 3-week change approved. | 01/09/2002 | TAC | Yes | 9.2.3, 9.2.4, 9.2.5 & 9.3 | Approved | |
| PRR309 | TDSP Demand Reporting Requirement | Wording changes in demand reporting requirements that better reflect the intent of the current Protocol language. | 01/07/2002 | Load Profiling Working Group | No | 10.3.3.1(3); 18.6.6 | Approved | |
| PRR310 | Estimating Usage Applied to Profiles | Revise formulas to estimate usage when no actual meter read data is available for the day being estimated. | 01/07/2002 | Load Profiling Working Group | Yes | 11.3.2 & 11.3.4.1 | Approved | |
| PRR311 | DLC to BUL Transition | Permits load control or load management programs involving small energy consumers (under 1 MW) to provide a balancing-up load (BUL) without the requirement that interval data recorders (IDRs) be installed on all of the participating energy consumers. A sampling approach, consistent with ERCOTs load profiling requirements for direct load control programs, shall suffice. | 01/08/2002 | Task Force on Demand Side Resources & Demand Responsive- ness | No | 6.10.5.2, 6.10.2, & 6.8.1.14 | Approved | |
| PRR312 | Enhance ESI ID Look-up Function | Provide additional information for an ESI ID to include Station ID, Power Region, Premise Type, status (active/de-energized/inactive) for an ESI ID. | 01/14/2002 | Entergy Solutions Supply LTD | No | 15.2 | Approved | |
| PRR313 | TCR Transfer Deadline | This revision specifies a time limit on the transfers of TCRs in the ERCOT TCR database. | 01/14/2002 | PUCT | Yes | 7.5.7 | Approved | |
| PRR314 | Minimum Time Unit for Resource Availability | XML documentation states that the LEAD-TIME value has to be entered in minutes. Protocols need to be revised to state the correct time interval, currently "hours." | 01/23/2002 | ERCOT | Yes | 4.4.16 (6) | Approved | |
| PRR315 | Cost Recovery for OOM Down | (1) Allow for the recovery of Production Tax Credits. This is particularly important for Wind resources since the provision of energy at no cost, as is provided by the current pricing structure, does not provide the ability to recover the lost production tax credits that would have been earned had the Wind resource generated the electricity. (2) Clarify RODP for Wind Resources,. the change will clarify that the RODP found in paragraph 6.8.2.2 (4) for Wind Resources will be zero (same as Nuclear & Hydro). | 02/04/2002 | AEP | Yes | 6.8.2.2 | Rejected | |
| PRR316 | CR Switch Cancellation | Add language in section 15.1.1.4 of the protocols to say specifically that a CR does have the ability to cancel a pending switch. | 02/04/2002 | ERCOT (RMS) | Yes | 15.1.1.4 | Approved | |
| PRR317 | Revise Computation Procedure for TCRs | Clarify and modify determination of CSC limits and TCRs. | 02/05/2002 | ERCOT | Yes | 7.5.2, 7.5.2.1, 7.5.2.2 | Withdrawn | |
| PRR318 | Two Zone Adjustment | Add methodology to alleviate the situation of one station having transmission busses assigned to two different transmission congestion zones. | 02/22/2002 | TXU | No | 7.2.1.2 | Approved | |
| PRR319 | Load Ratio Share Used to Determine AS Obligation | Revised the language in Section 6.3.1 to reflect that the Load Ratio Share used to determine AS Obligation will be for the same hour and day of the week and from the initial settlement data that is available. | 02/28/2002 | ERCOT | Yes | 6.3.1 | Approved | |
| PRR320 | Loads Participation in AS Market | The testing and monitoring requirements for responsive reserves and non-spinning reserves prohibit a QSE from delivering such services at levels above defined limits. For testing, the QSE cannot deliver more than 105% of the requested reserves. For monitoring, the QSE cannot deliver more than 120% of the requested reserves. The proposed revisions eliminate these upper limits on testing and deployment for loads acting as a resource. | 03/01/2002 | PUCT-MOD | Yes | 6.10.3.2(4); 6.10.3.3(4); 6.10.5.4 & 6.10.5.5 | Withdrawn | |
| PRR321 | Uninstructed Resource Charge Process | States that a QSE is subject to the uninstructed charge for over-generation when the MCPE is positive, when regulation is determined to be over or under the defined bandwidth. | 03/14/2002 | QSE Project Managers WG | Yes | 6.8.1.15; 6.8.1.15.1-3 | Approved | |
| PRR322 | RPRS Award Performance | Current Protocols language potentially could allow a QSE receiving an RPRS award/ deployment to be paid without starting the awarded unit. This is possible because the performance measures only require that the QSE submit balancing bids in an amount equal to the RPRS award and do not specifically require that the QSE start the unit. | 03/21/2002 | AEP | No | 6.10.8 | Approved | |
| PRR323 | TCR Creditworthiness Monitoring | Update creditworthiness language to match the TCR Agreement. | 03/22/2002 | CPS-San Antonio | Yes | 16.8.1.5.3 & 16.8.1.6-10 | Approved | |
| PRR324 | EPS Meter Polling Timeline | Revises requirements for polling of EPS meters based upon change in timeline for initial settlement. | 03/26/2002 | ERCOT | Yes | 10.3.2; 11.1.1; 11.1.2; 11.1.4 | Approved | |
| PRR325 | Sub-QSEs Partition Limit | Revise the Protocols to increase the maximum number of Sub-QSEs an Entity can implement from three to ten. | 04/15/2002 | Dynegy | Yes | 16.2.1 | Approved | |
| PRR326 | Day Ahead Schedule | Update the definition for the Day Ahead Scheduling Process to end at 1800 instead of 1630. | 04/19/2002 | TXU | No | 4.4.1 | Approved | |
| PRR327 | Confidentiality | (1) Revise the definition of "Protected Information" and conform the provisions of §1.3.1.2 to reflect changes made to the definition of "Protected Information." (2) Impose a time limit on confidentiality of information. (3) Clarify that the PUCT, after notice and opportunity for hearing, may declassify information. | 04/24/2002 | PUCT-MOD | No | 1.3; 1.3.1.1; 1.3.1.2; 1.3.1.3 & 1.3.7 [new] | Approved | |
| PRR328 | Customer Service Establishment Notice | Eliminates the protocol language requiring that Move-In service establishment notices be sent to all Customers. | 04/29/2002 | ERCOT | Yes | 15.1.4.3 | Approved | |
| PRR329 | TCR Simultaneous Combinatorial Auction | This revision was drafted by the Congestion Management Working Group of the Wholesale Market Subcommittee to implement the Public Utility Commission of Texas order to convert the simple auction to a combinatorial auction of TCRs (Transmission Congestion Rights). | 05/07/2002 | TXU | Yes | 7.5.3.2 & 7.5.3.2.2 | Approved | |
| PRR330 | IDR meter data for True-Up settlement | Require that 95% of the IDR meter data be available for true-up settlement to take place. | 05/06/2002 | TXU | Yes | 9.2.6 | Approved | |
| PRR331 | OOMC Floor Price | Revise OOMC Payment calculations so that such deployments are not pay as bid & establish the OOMC floor payment as discussed in the PRS recommendation of PRR285. | 05/06/2002 | AEP | Yes | 6.8.2 | Withdrawn | |
| PRR332 | Unit Resource Testing | This revision recognizes prudent operating practices by prohibiting the ISO from issuing resource-specific dispatch instructions while the resource is in the process of pre-COD testing, required seasonal real and reactive testing, and testing necessary prior to and returning from annual planned maintenance | 05/13/2002 | Calpine | No | 4.5.2; 5.4.3; 5.6.7; 6.10.2 & 6.10.3 | Approved | |
| PRR333 | OOM Down Cost Recovery | Develop a methodology for compensating uncontrollable renewable Resources that incur costs greater than the OOME Down payment. | 05/23/2002 | ERCOT | Yes | 6.8.2 | Approved | |
| PRR334 | Generator Ratio Share | This PRR is one of a group of PRRs [#s 334-340] that the submitter requested be considered as a single vote. Specifically, this PRR modifies the process of uplifting local congestion charges so that generators pay for local congestion costs. | 05/20/2002 | TXU | Yes | 2.1 & 6.9.7 | Rejected | |
| PRR335 | Generic Costs | This PRR is one of a group of PRRs [#s 334-340] that the submitter requested be considered as a single vote. Specifically, this PRR adds a new section to incorporate generic costs associated with resources that will be used to calculate payments when a resource provides Out-of-Merit Service. The generic resource costs added are: generic fuel cost, generic startup costs, and generic operating costs. | 05/20/2002 | TXU | Yes | 6.8.2 | Approved | |
| PRR336 | OOM Down | This PRR is one of a group of PRRs [#s 334-340] that the submitter requested be considered as a single vote. Specifically, this PRR revises the OOME Down pricing to a cost-based mechanism. | 05/20/2002 | TXU | Yes | 2.1 & 6.8.2.2 | Approved | |
| PRR337 | OOM Up Pricing Method | This PRR is one of a group of PRRs [#s 334-340] that the submitter requested be considered as a single vote. Specifically, this PRR revises the OOME Up pricing to a more conservative cost-based pricing mechanism. | 05/20/2002 | TXU | Yes | 2.1 & 6.8.2.2 | Approved | |
| PRR338 | OOMC Pricing Method | This PRR is one of a group of PRRs [#s 334-340] that the submitter requested be considered as a single vote. Specifically, this PRR revises the OOMC from bid/premium-based pricing to cost-based pricing. | 05/20/2002 | TXU | Yes | 2.1, 6.6.3.2.1 & 6.8.2.1 | Approved | |
| PRR339 | REC for OOM Down | This PRR is one of a group of PRRs [#s 334-340] that the submitter requested be considered as a single vote. To be fair to renewable resources without increasing the costs of Local Congestion, this PRR credits renewable resources that provide OOME Down service by awarding the resource RECs for energy not generated by the renewable resource due to providing the OOME Down service. This solution will also require an amendment to PUCT Substantive Rule 25.173. | 05/20/2002 | TXU | Yes | 14.7 | Withdrawn | |
| PRR340 | Remove Market Solution Definition | This PRR was originally part of a group of PRRs [#s 334-340] that the submitter requested be considered as a single vote. Remove the Market Solution concept as part of the mechanism for resolving Local Congestion. Renamed: Define OOME as an Instructed Deviation. The revised PRR allows for the deployment of dispatch instructions for OOME and does not remove the Market Solution definition. | 05/20/2002 | TXU | Yes | 2.1, 4.1.2, 4.5.3, 6.1.10, 6.1.11, 6.3.1, 6.4.2, 6.6.3.2.1, 6.7.1.2, 6.7.1.3, 6.7.8, 6.8.1.11, 7.1, 7.2.1.1, 7.3.2, 7.4.2, 7.4.3.1, 7.4.3.2, 7.4.3.3, 7.4.4, & 7.6 | Withdrawn | |
| PRR341 | Transmission Facility Status Change Notification | Add language that allows flexibility in maintaining specific equipment that currently does not exist with ERCOT Outage Coordination efforts. | 05/23/2002 | LCRA | Yes | 5.5.2 | Approved | |
| PRR342 | AS Simultaneous Selection | Modification of ancillary service bid selection process to allow simultaneous occurrence of Regulation Up, Responsive Reserve and Non-Spinning Reserve. | 05/24/2002 | TXU | No | 4.4.11; 4.4.12; 6.6.2 & 6.6.3 | Approved | |
| PRR343 | BES Ramp Rate | Add language to describe a typical ramp duration & clarify the deployment period as the operating interval. WMS requested clarification of the current Protocol text. | 06/04/2002 | ERCOT | Yes | 6.5.2(18) | Approved | |
| PRR344 | Bid Clearing | Revises language to comply with the implementation of PIPs 147 & 148; bids will be carried over to the next market if there is one. | 06/13/2002 | ERCOT | Yes | 4.4.11 | Approved | |
| PRR345 | Multi-Settlement | This revision pays all providers the highest clearing price for the market they were awarded and all subsequent markets. Thus if a subsequent market cleared lower than an earlier market, the providers in the subsequent market will not get the benefit of the earlier clearing price. | 06/20/2002 | WMS | Yes | 6.6.3 & 6.8 | Approved | |
| PRR346 | MVA Data Calculation Responsibility | Eliminate redundant requests for data, specifically MVA. | 07/01/2002 | LCRA | No | 12.4.4.1.1 | Approved | |
| PRR347 | OOMC Pricing Formula Clarification | This PRR clarifies the equations originally proposed by PRR338. | 07/02/2002 | ERCOT | Yes | 6.8.2.1(5) | Approved | |
| PRR348 | Confidentiality Cleanup | Limits the time that REC account information is protected from disclosure to 1 year after the end of the applicable Compliance Period. | 07/25/2002 | PUCT MOD | Yes | 1.3.3(1)(c) | Approved | |
| PRR349 | UBES-DBES Ramp Rates | Incorporates the QSE's bid ramp rates when ERCOT issues instructions for a QSE to change its Balancing Energy service deployment from the previous Settlement Interval to the target Settlement Interval. | 07/25/2002 | Reliant Energy | Yes | 6.5.2(16), (17), (18), (19) & add new (22) | Approved | |
| PRR350 | Smoothing Algorithm Revision | This revision will change the calculation of the Schedule Control Error equation in real time. | 07/31/2002 | AEP | No | 6.10.4.2 | Approved | |
| PRR351 | Load Imbalance Balancing Energy Settlement | Revises load unit from MW to MWh. | 08/06/2002 | ERCOT | Yes | 6.9.5.2 | Approved | |
| PRR352 | Proxy Day Determination Extension | This PRR changes the Non-Weather Sensitive (NWSIDR) Proxy Day determination method to use the most recent historical ESI-ID interval data from the last 12 months. | 08/07/2002 | Dynegy, IDR Default Profile Chair | Yes | 11.3.3.3 | Approved | |
| PRR353 | Change Control Classification Update | Eliminates the Transaction Inventory from Section 19. The Transaction Inventory is maintained on the Texas SET website. Updates the change control classification to reflect the current priority classification used by the Texas SET Working Group. | 08/13/2002 | Center Point Energy | No | 19 | Withdrawn | |
| PRR354 | Amend POLR Process | Replaced references to POLR with Affiliate REP where appropriate in 15.1.2, 15.1.3, and 19.3.1. Added language to 15.1.2 for process used when dropping a customer to the POLR for contract non-renewal. Added language to 15.1.2.9 for ERCOT process of notifying the POLR to submit switches on mass drop in the event of a CR default. | 08/16/2002 | PUCT-MOD | Yes | 15.1.2, 15.1.3 & 19.3.13 | Approved | |
| PRR355 | OOME BLT Generic Costs | Establishes Resource Category Generic Cost for Block Load Transfers. Correct the payment equation for start up operational cost. Insert protocols reference to complete the sentence found in protocols section 6.8.2.2 (4) (a) (iv). | 08/21/2002 | AEP | No | 6.8.2 | Approved | |
| PRR356 | SCE Performance Requirement | To cause QSEs to make better efforts to follow their Resource schedule so that ERCOT can accurately procure Balancing Energy, and to change the allocation of Ancillary Service capacity costs from pure load ratio share to a method that assigns costs to causation. Both reasons are currently of increased importance to assure the operationally smooth implementation of Relaxed Balanced Schedules. | 08/22/2002 | City of Garland | No | 6.10.5.1, 6.10.5.2, 6.10.5.3, 6.10.5.4, 6.10.5.5, 6.10.5.6 | Rejected | |
| PRR357 | Market Solution Definition Revision | The current definition requires that at least three unaffiliated resources be available for solving a circumstance of local congestion. It is possible to have bids from three unaffiliated bidders that could independently solve an instance of local congestion, except for the fact that one or more of these solutions may not be feasible because of constraints that do not permit the physical dispatch of the resources to resolve the congestion. The proposed definition corrects this by specifying that a market solution only exists when each of the required three bids from unaffiliated bidders has sufficient capacity available to physically solve the congestion. | 09/03/2002 | PUCT - MOD | No | 2.1 | Approved | |
| PRR358 | Negative Impact SCE | Replaces the Uninstructed Deviation settlement scheme with a new methodology, called Negative Impact Schedule Control Error Charges (NISCE) that penalizes QSEs that fail to adhere to their schedules, which cause additional Schedule Control Error (SCE) and rewards QSEs that are dispatched to compensate for the SCE caused by non-performing QSEs. | 09/03/2002 | TXU | No | 2.1, 2.2, 6.8.1.15, 6.8.1.15.1-8 | Rejected | |
| PRR359 | Improve Resource Plan | Requires the provision of additional information in the Resource Plan and allows updates after the Adjustment Period. | 09/06/2002 | ERCOT | No | 2.1, 4.4.15, 4.5.10 & 6.7.1.2 | Approved | |
| PRR360 | Relaxed Balanced Schedules | Allows for the use of relaxed Balanced Schedules. | 09/06/2002 | Relaxed Balanced Schedules TF | Yes | 2.1, 4.1.1, 4.3.2, 4.4.15, 6.4.2, 6.5.10, 6.6.3.2.1 & 6.10.8 | Approved | |
| PRR361 | Section 15 Update | Updates Section 15: (1) to use the 814_82/29 for both Unexecutable and permit Required for move-ins and move-outs only; (2) Special Needs Indicators; and (3) to reflect Implementation Guide language. | 09/13/2002 | Reliant | No | Section 15 [several] | Approved | |
| PRR362 | Load Profiling Guide - Correction Procedure to Profile ID Type | Remove procedural details from Protocols and refer Market Participants to Load Profiling Guides. | 09/17/2002 | ERCOT | No | 18.4.4.2 | Approved | |
| PRR363 | IDR Data Start-Stop Times | Add language to require TDSPs (and future Meter Reading Entities) to send only whole days of data for all IDR ESI IDs. | 09/20/2002 | ERCOT | Yes | 10.9.2 | Approved | |
| PRR364 | RPRS Payment and Charge Calculations | Modify the RPRS settlement calculations to assure proper performance. | 09/23/2002 | TXU Energy | No | 6.8.1.10, 6.9.2.1.1 | Rejected | |
| PRR365 | Replace Resource Specific Premium Bid with Price Bid | Replace resource specific bid premium with a single resource specific bid price. | 09/25/2002 | PUCT-MOD | Yes | 4.1.2, 4.5.3, 6.1.11, 6.7.1.2, 6.7.1.3, 6.7.9, 6.8.2.3, 7.4.3.1, 7.4.3.2 | Rejected | |
| PRR366 | Changes to Pre-Assigned TCRs | These changes are intended to reflect the changes ordered by the PUCT in its Order No. 15 in Docket No. 24770. | 10/09/2002 | CPS-San Antonio | Yes | 4.1.2, 6.6.3.2.1, Section 7 [several] | Approved | |
| PRR367 | IDR Installation & Use | Re-word Section 18.6.1(4) to address two substantive changes:1) Change wording to reflect, IDRs installed at the request of ERCOT, a TDSP, , instead of IDRs installed by ERCOT, a TDSP, .2) Change demand calculation to coincident demand calculation | 10/14/2002 | ERCOT | No | 18.6.1 | Approved | |
| PRR368 | Section 18 References | Delete the word Operating (and the following space) from all occurrences of Load Profiling Operating Guides in all of Section 18. In Section 18.5.1, replace as set forth in the Operating Guides to as set forth in the Load Profiling Guides. | 10/14/2002 | ERCOT | No | 18.5.1 | Approved | |
| PRR369 | Proposal to Address Dispatching Issues for Combined Cycle Units Through Settlement Aggregation | Change the way instructions to combined cycle plants are settled to more accurately reflect the operational interdependencies of these plant technologies. | 10/17/2002 | Constellation | Yes | 6.5.10, 6.8.2.2 & 6.8.2.4 [new] | Approved | |
| PRR370 | Process for Application and Approval of RMR Contracts | Formalizes the process for application and approval of RMR contracts, including requirement for notice, opportunity for comment, availability of data, and approval by ERCOT Board. These provisions reflect that RMR is essentially a regulated service provided to the market and therefore calls for greater market scrutiny than other services provided to ERCOT. The PRR is intended to maximize the information available to market participants, while minimizing the constraints on ERCOTs ability to enter into RMR Agreements it determines are needed. | 10/17/2002 | Austin Energy | Yes | 1.3.1.2, 6.5.9, 6.5.9.1 [new] | Approved | |
| PRR371 | Minimum Energy OOME When OOMC Issued | Language implements a mandatory minimum OOME instruction for the same intervals that OOMC instructions are issued to a unit. | 10/28/2002 | Exelon | No | 6.8.2.1 & 6.8.2.2 | Approved | |
| PRR372 | Backup Plan Requirement | This revision adds the requirement for a backup plan in the event of a loss of the QSEs or Transmission Operators scheduling center. | 10/30/2002 | ERCOT | No | 16.2.1; 16.2.2 & 16.4 | Approved | |
| PRR373 | OOME as Instructed Deviation | This PRR provides a method to define Out Of Merit Energy Service as Instructed Deviation. | 10/31/2002 | TXU | Yes | 6.7.7 and new sections 6.7.7.1 & 6.7.7.2 | Approved | |
| PRR374 | RMR Text Changes | Reflects previous changes in the Day Ahead timeline, clarifies the use of RMR energy & corrects typos. | 12/09/2002 | ERCOT | No | 4.5.11.1; 4.5.11.3; 6.7.8, 22F.1.H & 22F.8 | Approved | |
| PRR375 | AS Schedule Times | Clarifies when AS schedules may be modified. | 12/23/2002 | ERCOT | No | 4.3.5; 4.4.8 & 4.4.14 | Withdrawn | |
| PRR376 | Procure Total AS from ERCOT | Allows a QSE to purchase ancillary services to cover both their ERCOT allocated ancillary service obligation as well as obligations scheduled to other Sub-QSEs or QSEs. | 12/23/2002 | AEP | Yes | 4.7.1 | Approved | |
| PRR377 | ERCOT Canceled RMR Unit Start | Provides that RMR units are to be partially compensated for start up expenses when ERCOT request a start and then subsequently cancels the start after start up has been initiated. | 01/03/2003 | AEP | No | 6.8.3.5 | Approved | |
| PRR378 | RMR Units Mandatory Down Balancing Bids | Exclude energy schedules from RMR units from the requirement to provide mandatory down balancing bids. | 01/03/2003 | AEP | Yes | 4.4.5 & 4.5.2 | Approved | |
| PRR379 | BLT Waiver [renamed] | Provides that resources receiving a waiver from signing the Resource agreement must designate a load serving entity to serve their auxiliary load when the generator is not operating. And adds a new section giving ERCOT the ability to grant a waiver for Block Load Transfer point Resources. | 01/03/2003 | AEP | No | 16.5.1.1 & 16.5.1.2 [new] | Approved | |
| PRR380 | Black Start Service | (1) Provides RFP evaluation criteria as an appendix to the RFP; (2) Clarifies that the procurement of Black Start Services are annual and that testing is a simulation and not an actual event; (3) Adds criteria for revocation of certification for actual event default; and (4) Defines an additional default criterion. | 01/13/2003 | LCRA | Yes | 6.5.8, 6.6.2; 6.10.3.6; 22.7 & 22.10.A.2.e | Approved | |
| PRR381 | Update QSE Designation | Outlines the steps necessary for an LSE or Resource Entity to designate a new QSE when their existing QSE terminates its commercial relationship with the Entity. | 01/14/2003 | ERCOT | No | 16.2.5.1, 16.3.2, 16.5.3, 16.2.4.2 [new], 16.2.13 [new] | Approved | |
| PRR382 | Settlement Statement Suspension | Allows the Board to direct ERCOT to suspend the issuance of Settlement Statements. | 01/31/2003 | ERCOT | No | 9.2.7 [New] | Approved | |
| PRR383 | RMR Resource Maintenance Outage Approval | Adds a requirement for ERCOT to respond within a specific time period on maintenance outage requests for RMR units. | 01/21/2003 | AEP | No | 8.1.4.1; 22-F.8 | Approved | |
| PRR384 | Protocol Preamble and Process for Advisory Opinion | The first revision creates a preamble to the Protocols that outlines the expectations of market participants as they apply Protocols in the course of their wholesale activities. The second creates an opportunity for market participants to seek guidance regarding potential ambiguities or uncertainties in the application of the Protocols to wholesale activities by obtaining an opinion from an ERCOT Director. The opinion would be binding and could be relied upon unless or until the PUC or an ERCOT TAC or Board action dictated otherwise. | 02/06/2003 | ANP for the Code of Conduct Task Force | Yes | Preamble [new],1.5 [new], 1.6, 1.7, 1.8 | Withdrawn | |
| PRR385 | DLC Implementation | This PRR will allow the DLC programs to be appropriately profiled and ERCOT systems to properly process DLC programs. | 02/05/2003 | Reliant Energy for Profiling WG | No | 18.7.2.1; 18.7.2.2.2-5 | Approved | |
| PRR386 | Scheduling Information | Adds text where applicable to indicate that not all services are deployed by zone and the services that are deployed by zone will be reported by zone. | 02/07/2003 | ERCOT | No | 12.4.1(3) | Approved | |
| PRR387 | Mismatch Inter QSE Schedules Settlement | Clarifies, automates & simplifies the settlement of Mismatched Inter-QSE Schedules. Inserts formulas in the Protocols that are needed to settle mismatches. | 02/12/2003 | ERCOT | Yes | 4.7.2; 6.9.8 [new]; 9.6.1 | Approved | |
| PRR388 | BUL Capacity Payment | Revise the i variable for the formula calculation from an interval equal to one hour to interval. Make two cleanup changes to references to Load Ratio Share in 6.9.6 and 6.9.7. | 02/12/2003 | ERCOT | Yes | 6.9.6 | Approved | |
| PRR389 | Winter Weather Events Requirement | Incorporates revisions that require QSEs to project actual interval Obligations during winter weather events that impact resources and can jeopardize the reliability and/or security of the ERCOT System. | 02/18/2003 | Garland P&L | No | 2.1; 4.1.1; 4.3.2; 4.3.5 | Approved | |
| PRR390 | Transmission Interconnect Notification Requirements | Creates transmission interconnection notification requirements that will establish a timetable for addressing the risks associated with local transmission congestion. | 02/19/2003 | Cielo Wind | No | 6.8.2.3 | Rejected | |
| PRR391 | Waiver Recipients Must Designate an LSE | Clarifies that resources receiving a waiver from signing the resource agreement must designate a Load Serving Entity to serve their auxiliary load when the generator is not operating. | 02/21/2003 | Reliant Resources for PRS | No | 16.5.1.1(3) [New] | Approved | |
| PRR392 | Posting BE Forecast-PIP138 | Deletes the box for PIP138 which requires the Posting of BE Forecast. | 02/21/2003 | ERCOT | No | 6.7.1.1(6) | Approved | |
| PRR393 | Balancing Energy Bid Expiration Time-PIP147 | Deletes the PIP147 box, which allows for expiration time of balancing energy bids. | 02/21/2003 | ERCOT | No | 4.5.2(5) | Approved | |
| PRR394 | Balancing Energy Ramps as Instructed Deviations | Revise Subsection 6.5.2(17) to state that, Energy provided outside of the target Settlement Interval as a result of ramping at the specified rate will be considered an Instructed Deviation. | 02/27/2003 | ERCOT | No | 6.5.2(17) | Approved | |
| PRR395 | Declare Backup Plans Protected Information | Clarifies that QSE and TO backup plans are Protected Information. | 02/28/2003 | AEP | Yes | 1.3.1.1 | Approved | |
| PRR396 | RMR Issues | This PRR revises the guidelines and compensation of Reliability Must Run Service. | 04/11/2003 | Reliant for RMR Task Force | Yes | 6.5.9; 6.5.9.1; 6.7.8; 6.8.3; 22F; 22I | Approved | |
| PRR397 | McCamey Area Congestion Management | This revision is designed to minimize uplifted congestion costs while attempting to reliably maximize the use of the transmission system in the McCamey area where numerous wind turbine generators are currently located and additional wind generators may be constructed. | 03/19/2003 | TXU Energy | No | 7.8 [new]; 7.8.1-10 | Approved | |
| PRR398 | Combined Cycle Settlement | Amends the equations originally revised by 369PRR - Proposal to Address Dispatching Issues for Combined Cycle Units Through Settlement Aggregation, to clarify how the ERCOT system will process this functionality. | 04/11/2003 | ERCOT | Yes | 6.8.2.3; 7.4.3.1 & 7.4.3.2 | Approved | |
| PRR399 | IDR Replacement with Non-IDR Meter Requirements | This revision allows 1) IDR installations where they are needed or required and provide the most effective utilization of this type of reporting to ERCOT; and 2) Removal of IDR installations that are no longer valid for a premise or ESI ID because of reduced load or consumption based upon 12-month consecutive usage data. | 04/15/2003 | Center Point Energy | Yes | 18.6.1 & 18.6.6 | Withdrawn | |
| PRR400 | LaaR Provisional Qualification | Allows loads to begin participating in the market as soon as their loads meet all telemetry and calibration testing until such time as an actual load interruption test can be scheduled with ERCOT and the load facilities. | 04/15/2003 | Reliant/ Demand Side WG | Yes | 6.10.1 | Approved | |
| PRR401 | Partial Payments & Credit | Updates ERCOTs calculation of each QSEs Total Estimated Liability and Estimated Aggregate Liability; and clarifies that ERCOT has the ability to offset amounts owed to and from a QSE that does not remit a payment in a timely manner. | 04/16/2003 | ERCOT | Yes | 9.4.4; 16.2.5-9 | Approved | |
| PRR402 | Delete Good Friday Holiday | This PRR deletes Good Friday from the list of observed holidays in the definition of a Business Day. | 04/17/2003 | ERCOT | No | 2.1 | Approved | |
| PRR403 | URC Update Due to Smoothing Algorithm Revision | Clarifies and describes in detail the changes to the URC equation as a result of the implementation of PRR 350. Specifically describes how to treat DC Tie Schedules when calculating the schedule to be used in the URC calculation. | 04/16/2003 | ERCOT | Yes | 6.8.1.15 | Approved | |
| PRR404 | Energy Procured from ERCOT | Expands the functionality of Relaxed Balanced Schedules by allowing Market Participants to schedule up to 500MW of generation from ERCOT. | 04/17/2003 | Tractebel | No | 4.3.2 | Approved | |
| PRR405 | RPRS Under Scheduled Capacity (PIP132) | This PRR inserts the boxed text in 6.9.2.1.1 to reflect the implementation of PIP132, which was implemented on May 23, 2002, and revises text in 6.10.4.3 to match wording changes made by PRR394. | 04/17/2003 | ERCOT | No | 6.9.2.1.1 & 6.10.4.3 | Approved | |
| PRR406 | Two Year CSC & Zone Selection | Revises the current one year forward establishment of CSCs and zones to a two year forward approach. | 04/18/2003 | Constellation | Yes | 7.2 | Withdrawn | |
| PRR407 | Sunset Date Removal for RBS | This change removes the sentence that would restrict ERCOT from initiating a limitation or suspension of relaxed Balanced Schedules and clarifies that ERCOT may consider financial integrity issues in such limitation or suspension. | 04/24/2003 | ERCOT | Yes | 4.3.5 | Approved | |
| PRR408 | HVDC Tie Schedule Data | Clarifies that ERCOT is responsible for the accurate accounting of all generation produced and delivered within ERCOT; clarifies that in addition to providing the necessary data for the 4CP calculation, ERCOT must provide the necessary data for TDSP billing under FERC tariffs as they apply to the HVDC interconnections. | 04/24/2003 | Center Point Energy | No | 1.2(4); 1.3.1.1; 9.1; 9.8.2 [new] | Approved | |
| PRR409 | Voltage Support Service | The current Protocols allow for excessive reactive dispatching on the part of TSPs without compensation to generation owners. This PRR changes the power factor envelope from +-.95 to +-.98, and allows for payment to generators. | 04/28/2003 | Calpine | No | 6.5.7, 6.8.4 | Approved | |
| PRR410 | Resource Obligations During BLT | Specifically addresses generators' right to decide availability based on concerns of Jurisdiction, tariffs, or increase risk of assets when the transmission area the resource is connected to, is tied to a non-ERCOT system other than through a D.C. Tie. | 04/28/2003 | STEC | No | 5.7.3 | Approved | |
| PRR411 | Protocol Clarification Process (original title: Advisory Opinion) | Provides a clarification process for interpretation of the Protocols. This PRR was severed from PRR384 Code of Conduct & Advisory Opinion. | 04/29/2003 | ANP | No | 21.1 | Approved | |
| PRR412 | Distributed Generation With No Energy Export | The revision would clarify that, for distributed generation resources that do not export energy to the ERCOT System, and are located on the Customers side of the Service Delivery Point of the retail customer of a NOIE or on the Customers side of the Service Delivery Point of a Premise with an IDR meter, separate resource metering, scheduling, data submission and settlement is Not required | 04/01/2003 | CPS | No | 10.2.2 | Withdrawn | |
| PRR413 | Optimization for the whole operating day in RPRS procurement process | Modify RPRS procurement process so that RPRS procurement process is an optimum solution for the whole operating day. | 05/13/2003 | ERCOT | No | 4.4.16, 6.3.1, 6.5.9, 6.6.3.2.1, 6.7.8, 6.8.1.10, 6.8.1.11, 6.8.2.2, 7.4.2 | Approved | |
| PRR414 | Sunset Date on BE Bid Cap | Remove July 4, 2003 sunset date for Balancing Energy bid caps per PUCT order. | 05/15/2003 | ERCOT | Yes | 4.4.11, 6.5.2 | Approved | |
| PRR415 | Establish 50% as Limit for LaaRs Providing RRS and NSRS | Removes reference to Operating Guides and establishes 50% as the maximum limit for the quantity of Loads acting as Resources that can provide Responsive Reserve Service (RRS) and also allows ERCOT to adjust the 50% limit monthly on a planned basis and daily on an emergency basis if such a limit could adversely impact reliability or deployment of Regulation. This PRR also specifies how the total ERCOT quantity would be divided among QSEs. | 05/21/2003 | TXU | Yes | 4.4.3, 4.5.2, 6.4.1, 6.5.4(8), 6.7.1.1(9)(11), 6.7.4(11) | Approved | |
| PRR416 | Amendment to Posting of Balancing Energy Information | New subsection establishes reporting requirements for QSEs that posts the name of any QSE submitting bid for Up Balancing Energy Service with the last price/volume bid being a volume less than three (3%) of the QSE's total volume in that bid curve and is greater than three times the price of the immediately preceding price/volume pair included in that bid curve. | 05/21/2003 | Reliant | Yes | 1.3.3(2)(c) | Approved | |
| PRR417 | Changes to 814_06, Handling Move Ins | Changes to transmission of 814_06, New handling of Move-Ins that reject for ESI ID invalid, Change in requirement for Start and Eligibility dates, and reference to new 'Ignore CSA' flag. | 05/22/2003 | ERCOT | Yes | 15.1.1.9, 15.1.4.2, 15.1.4.7, 15.1.5.1, 15.1.5.7, 15.1.5.8, 15.4.1.4 | Approved | |
| PRR418 | Creation of New CSC | Modify Section 7.2.1.3, create new section 7.2.1.4, Approval Process and add language related to a new CSC effective July 1, 2003 through the remainder of 2003. | 05/23/2003 | ERCOT | Yes | 7.2.1.3 | Withdrawn | |
| PRR419 | Transfer of BUL Qualification Testing Responsibility from ERCOT to QSEs | This revision transfers the responsibility for qualification testing for BUL from ERCOT to the QSE representing the BUL. | 05/23/2003 | Reliant | Yes | 6.10.2, 6.10.5.2 | Approved | |
| PRR420 | MCSM | Implements PUCT's order to ERCOT to adopt an interim automatic mitigation procedure for balancing energy prices. | 05/23/2003 | PUCT-MOD | Yes | 6.5.2.(22) [new], 6.9.5.1(2) [new] | Approved | |
| PRR421 | Conformance with New PUCT Substantive Rule 25.362 | Revise Protected Information requirements to conform with new P.U.C. SUBST. R. 25.362. | 05/27/2003 | ERCOT | No | 1.3.4, 1.3.5, 1.3.6, 1.3.8 | Approved | |
| PRR422 | OOM Zonal Dispatch Instructions | Provides detail on deployment and settlement of Zonal OOME Dispatch Instructions in command and control conditions | 05/29/2003 | ERCOT | Yes | 6.1.12, 6.2.1, 6.3.1, 6.5, 6.5.9, 6.5.11, 6.6.5, 6.7.7.1, 6.7.7.2, 6.7.7.3, 6.7.8, 6.8.2, 6.8.2.5, 6.9.7.2 | Approved | |
| PRR423 | Dispatch of QFs Below Minimum Generation Levels | This PRR would limit ERCOT's ability to dispatch QFs to a value no lower than their Minimum Generation Level, except in the case of an imminent Emergency. | 06/06/2003 | Calpine | Yes | 4.4.15 | Approved | |
| PRR424 | Elimination of Resource Specific Deployment Used for Energy Balance Purpose | This PRR will eliminate the Resource specific deployments for energy balance purposes and will reduce the cost of Local Congestion that is currently uplifted to all Loads. | 06/13/2003 | ERCOT | Yes | 6.7.1.2, 7.3.2, 7.4.3.1, 7.4.3.2 | Approved | |
| PRR425 | Section 8 Outage Coordination | It moves subsections pertaining to Transmission so they are together and makes minor changes to Transmission Outage requirements. Adds some requirements for RMR and Black Start Outages. | 06/13/2003 | ERCOT | No | 2.1, 6.8.2.2, 8 | Approved | |
| PRR426 | URC for Uncontrollable Resources | Defines an Uncontrollable Renewable Resource and allows wind resource to elect to use their Renewable Production Potential in lieu of their schedule as the basis for URC charges and OOME Down payments. | 06/13/2003 | Cielo Wind | No | 2.1, 6.8.1.15.1 | Approved | |
| PRR427 | RMR General Clarifications | This PRR would clarify the changes to the RMR provisions adopted in May by the ERCOT Board. | 06/17/2003 | AEP | No | 6.8.3.1, 6.8.3.3, 9.4.4 | Approved | |
| PRR428 | RMR Scheduling Clarifications | This PRR would document/clarify the scheduling process for energy from RMR Units. | 06/17/2003 | AEP | Yes | 4.5.11.3.1, 4.5.11.3.2, 4.9.4.3 | Approved | |
| PRR429 | ERCOT Disclosure of Information to TDSPs | This PRR would add instructions to ERCOT to disclose and share with a TDSP any confidential information it has received or has knowledge of that would affect the operation and security of a TDSP. | 06/18/2003 | Brazos Electric | Yes | 1.3.6 | Approved | |
| PRR430 | Historical Usage | This PRR would add language that specifies usage provided for conversion/opt-in be reported in time intervals no longer than thirty-eight days. | 06/18/2003 | ERCOT | No | 19.3.1 | Withdrawn | |
| PRR431 | Collateral Requirements for RBS and EAL | This PRR would add a new section to calculate additional collateral requirements for QSEs intending to utilize the Balancing Energy Service more than 20%; excludes certain portions of the EAL calculation from the 60-day "look back" provision; reduces the number of days in which collateral must be posted from 3 to 2; and allows ERCOT to accelerate the due date on all outstanding amounts owed in the event of a late payment. | 06/19/2003 | ERCOT on behalf of Credit Workgroup | Yes | 16.2.7, 16.2.8, 16.2.9 | Approved | |
| PRR432 | Liability for LSE Default | This PRR would allocate responsibility for LSE default among Generation Entities, LSEs, and TDSPs. | 06/19/2003 | Green Mountain | No | 2.1, 9.4.4 | Withdrawn | |
| PRR433 | Change Percent Deficit Banking of Renewable Energy Credits | This PRR would change the deficit banking amount from 5% to 10% for the first two compliance periods. | 06/25/2003 | TXU Energy | No | 14.11.1, 14.11.3 | Approved | |
| PRR434 | Adjustment to Allocation of REC Purchase Requirement | This PRR would make adjustments to the annual allocation of REC purchase requirements to reflect changes in retail energy sales for a Competitive Retailer resulting from a final true-up or resettlement completed after the ERCOT notification deadline. | 06/25/2003 | TXU Energy | No | 14.1 | Withdrawn | |
| PRR435 | Confidentiality of LSE Transaction Data | This PRR would add transaction information submitted by an LSE to ERCOT or received by an LSE from ERCOT as a new category of protected REP specific information | 06/30/2003 | Green Mountain | No | 1.3.1 | Withdrawn | |
| PRR436 | Enhance LaaR/BUL Ability to Participate in Balancing Energy Up Service, Non-Spinning Reserve Service, and Responsive Reserve Service Markets | This PRR would include the changes proposed by the Demand Side Working Group to clarify the role of Loads in the Ancillary Service and BUL markets. | 06/30/2003 | Demand Side Task Force | Yes | 6.5.2, 6.5.4, 6.10.3.2, 6.10.3.3, 6.10.5.2, 6.10.5.4, 6.10.5.5, 6.10.8 | Approved | |
| PRR437 | 867_03 Timeline Change | ERCOT Protocols Chapter 15, Section 3, Monthly Meter Reads contains no timeline for the TDSP to send the 867_03 to ERCOT. Add verbiage to the first paragraph to add 867_03 TDSP to ERCOT timeline verbiage. | 07/01/2003 | RMS | No | 15.3 | Approved | |
| PRR438 | REC Timelines | Revises reporting, issuing and mandated retirements requirements based upon change for final settlement. | 07/02/2003 | ERCOT | No | 14.2, 14.4.2, 14.6.2, 14.7, 14.10, 14.10.5, 14.11.1, 14.13, 14.14 | Withdrawn | |
| PRR439 | Clarification on Defining OOME as Instructed Deviation | To clarify two exceptions on defining OOME as Instructed Deviation for the implementation of 373PRR. | 07/08/2003 | TXU for QSE Mgrs WG | Yes | 6.7.7 | Approved | |
| PRR440 | Interim Removal of Market Solution | This PRR would remove the consideration of a Market Solution for local congestion under any circumstance on an interim basis until December 31, 2003. | 07/16/2003 | City Public Service of San Antonio | Yes | 7.4.3 | Approved | |
| PRR441 | Protocol Revision Implementation | Requires estimated implementation dates to be developed for PRRs that are approved by the PRS. | 07/22/2003 | Constellation | No | 21.4.5, 21.6 [New] | Approved | |
| PRR442 | Profile Development Cost Recovery Fee/Approval of a Profile Segment Change Request | This is a new section to specify the reimbursement process required per the PUCT related to a Non-ERCOT Sponsored Load Profile and to implement a procedure to allow provisional approval of a profile segment change request. | 07/22/2003 | Reliant Energy | Yes | 9.9 [New]; 18.2.9 | Approved | |
| PRR443 | Competitive Metering Ownership Implementation | Define the requirements of Competitive Meter Ownership and establish a reference to the fact that Competitive Metering Guides will exist. | 07/23/2003 | COMET | Yes | 10.1 | Approved | |
| PRR444 | Move In Move Out (MIMO) Stacking | Market Participant solution for handling multiple non-sequential transactions on a single ESI ID. | 07/30/2003 | ERCOT | No | 15.1 | Approved | |
| PRR445 | Amendment to Protocol Revision Request Designation and Review Time Period for those PRR’s deemed as “Urgent” and the Urgent Review Timeline | Establishes new Protocol 21 guides under sections 21.4.3 and 21.5 regarding the Protocol Revision Request Designation for those PRRs deemed as Urgent, minimum Urgent Review Timeline in relation to those PRRs initiated by the market or by PUC activity to allow adequate review and comment time for market participants and justification requirements for those PRRs being submitted for "Urgent" status. | 07/31/2003 | TEAM | No | 21.4.3; 21.5 | Rejected | |
| PRR446 | Disclosure of OOMC Deployments | Provides for disclosure on the date of Initial Settlement, but no sooner than day 14, of each unit receiving an OOMC Dispatch Instruction, intervals for which the instruction was received, intervals for which and quantity of energy deployed by ERCOT from units receiving an OOMC Dispatch Instruction. | 07/31/2003 | Austin Energy | Yes | 1.3.1.1; 6.5.10 | Approved | |
| PRR447 | TCR Credit Limit Constraint Based on Clearing Prices | The first revision (Change wording in ( c ) to express Credit Limit constraints) reflects the enhancement to the TCR auction engine design to apply credit limit constraints based on auction clearing prices instead of bid prices. This revision becomes effective on December 1, 2003. The other revisions are representing corrections and/or embellishments to existing wording. | 07/31/2003 | ERCOT | No | 7.5.3.2.2; 7.5.6 | Approved | |
| PRR448 | Changes to implement Balancing Up Loads (BULs) and Block Deployment of LaaRs | Clarification of Balancing Up Load (BUL) calculations, removal of BUL Resource Plan language, and inclusion of BUL capacity payment calculations in Section 6.8. | 08/05/2003 | ERCOT | Yes | 6.8.1.14; 6.8.1.15.3; 6.10.4.4 | Approved | |
| PRR449 | Successful Data Validation Response for 867s | ERCOT will provide a response to TDSPs when data has been loaded or cancelled successfully based on system changes in PR-30125 (Data Loading Project). | 08/05/2003 | ERCOT | No | 11.2.2 | Approved | |
| PRR450 | BLT Generic Cost Fix Again | During the course of approving 371 the resource generic cost for Block Load Transfers were inadvertently omitted. This simply maintains the BLT category generic fuel cost that is currently in effect when the language from 371 is removed from the box. | 08/07/2003 | AEP | No | 6.8.2.1 | Approved | |
| PRR451 | Clarification of Ancillary Services Obligation Calculation | Clarification that ERCOTs calculated AS Obligations for its Day Ahead Operating Day Ancillary Services are based on Initial Settlement data only for the purpose of setting up the Day Ahead plan. After the Operating Day, the AS Obligation calculations are to be adjusted according to actual Metered Load Ratio Share throughout the entire settlement process, in the same manner as Load Imbalance, BENA, etc. | 08/12/2003 | Republic Power | No | 6.3.1, 6.9.1, 6.9.1.1, 6.9.1.2, 6.9.1.3, 6.9.1.4 | Approved | |
| PRR452 | Unavailable Units and RMR Agreements | Adds requirement for ERCOT to follow the RMR evaluation and notice requirement for units unavailable for an extended period due to non-Outage reasons. Adds requirement for Resources to remain available during RMR Agreement negotiations. | 08/18/2003 | ERCOT | Yes | 8.1.4.1 | Approved | |
| PRR453 | Black Start Service Voice Communication | Changing the Black Start Service Bid date from October to June of each year conforms current expectations of Black Start Services bidding. Provides ERCOT an avenue to assess and possibly specify certain communication facilities deemed necessary to restore the ERCOT System during a blackout. | 08/18/2003 | BSTF | No | 6.4.2; 6.5.8 | Approved | |
| PRR454 | OOME Off-line | When a generation unit receives an OOME instruction that would force it off-line, ERCOT must provide OOME instructions until the unit was scheduled to come off-line, or an OOMC instruction when the unit is requested to return. | 08/18/2003 | Constellation | Yes | 2.1, 6.5.10, 6.7.7.4 [new], 6.8.2.6 [new] | Approved | |
| PRR455 | Liability for QSE default on obligations to ERCOT and Responsibility for ERCOT Administration Fee | Spreads risk of default of a QSE and ERCOT costs among both Loads and Resources. | 08/25/2003 | Green Mountain Energy | No | 9.4.4; 9.7.1 | Withdrawn | |
| PRR456 | Disclosure of Identity of Short Paying QSEs | Requires disclosure of the identity of short paying QSEs. | 08/25/2003 | Green Mountain Energy | No | 9.4.4 | Approved | |
| PRR457 | Balancing Energy Down Requirement Revision | PRR will change the Balancing Energy Down Requirement to apply to MWh capability above the QSEs Low Operating Limit for the units in operation in their portfolio. | 08/25/2003 | Constellation | No | 6.5.2 | Approved | |
| PRR458 | LaaR OOMC and OOME Deployment and Payments | The purpose of this PRR is to clarify how ERCOT is currently handling OOME and OOMC with regards to LaaRs. | 08/26/2003 | Reliant | No | 4.4.15; 6.5.10; 6.8.2.1; 6.8.2.2; 6.8.2.3(6) [new] | Rejected | |
| PRR459 | EPS Meter Data Transmittal | ERCOT has implemented some of the requirements of PIP204 and PRR283; as a result the content and the order of some of the text previously shown as boxed has been altered. This PRR clarifies the features currently implemented and identifies within the boxed Protocol language those features which are still pending implementation. | 08/27/2003 | ERCOT | No | 11.1.10; 11.1.11 | Approved | |
| PRR460 | CSC Exemption Criteria | Currently, requests are made for exemption; however, there is no criterion in the protocols for evaluation of the request. This revision provides criteria for TAC and the Board to consider when evaluating the merits of an exemption request. | 08/29/2003 | American National Power | Yes | 7.2.1.1 | Approved | |
| PRR461 | Confidentiality Exceptions for Reliability Analysis | Revises the exception of 1.3.6(9) to allow Market Participants Protected Information for the purposes of developing analysis of system events; Adds an exception for limited public reporting of the status of facilities in significant events | 09/02/2003 | ERCOT | No | 1.3.6 | Approved | |
| PRR462 | Market Solution Definition | Revises the definition of Market Solution to allow for submittal of bids in circumstances including reliability needs other than local Congestion. | 09/04/2003 | ERCOT | No | 2.1 | Rejected | |
| PRR463 | PCR Allocation Regarding the 25% TCR Ownership Limit | Clarifies that the allocation of PCRs shall not exceed 25% of the total available TCRs on any CSC for any single direction. Also, clarifies that the 25% ownership limitation applies to TCRs and/or PCRs at a CSC interface. | 09/04/2003 | ERCOT | Yes | 7.5.6; 7.5.9 | Approved | |
| PRR464 | Confidentiality of LSE Transaction Data | This PRR would add transaction information submitted by an LSE to ERCOT or received by an LSE from ERCOT as a new category of protected REP specific information | 09/05/2003 | TXU | No | 1.3.1.1 | Approved | |
| PRR465 | Customer Service Satisfaction Survey | Requires ERCOT Staff to perform a survey of Market Participants to gain feedback on their performance. | 09/10/2003 | Constellation | No | 17.7 [new] | Rejected | |
| PRR466 | Extension of No Market Solution | This revision would extend the current expiration date for the suspension of Market Solution from December 31, 2003 to July 1, 2004. | 09/15/2003 | CPS | No | 7.4.3 | Approved | |
| PRR467 | Elaboration on the Notice of Resettlement | This PRR would request ERCOT to elaborate on the Notice of Resettlements and provide formality and structure to the Notices. | 09/15/2003 | CPS | No | 9.2.5.1 | Approved | |
| PRR468 | Frequency Response Requirements and Monitoring | Adds Section 5.8, establishing requirements for QSE portfolio generator governor response, and establishing performance monitoring criteria. | 09/22/2003 | Garland P&L (on behalf of ROS) | No | 5.8, 5.8.1, 5.8.1.1, 5.8.1.2, 5.8.2, 5.8.2.1, 5.8.2.2, 5.8.2.3, 5.8.3, 5.8.3.1, 5.8.3.2 [all sections new] | Approved | |
| PRR469 | Compliance for Competitive Metering and 25516 Rulings to Load Profiling | Changes to address responsibilities of TDSPs, ERCOT and Competitive Retailers related to sampling, TOU schedules and DLC. Additionally, some out of date wording has been updated or removed. | 09/26/2003 | Reliant (on behalf of PWG) | No | 18.2.5, 18.2.8.1, 18.2.11.1, 18.2.11.2, 18.3.3, 18.4.2, 18.4.3, 18.5.1, 18.5.3, 18.6.3, 18.7.1.1, 18.7.1.2, 18.7.1.4, 18.7.2.2.1, 18.7.2.2.2, 18.7.2.2.3, 18.7.2.2.5, 18.8 [new] | Approved | |
| PRR470 | System Fuel Availability | Inserts new wording to the existing language in Section 5 to include fuel availability as a concern for an emergency condition.. | 10/03/2003 | STEC | No | 5.6.3, 5.6.4, 5.6.6 | Approved | |
| PRR471 | NIDR to IDR Default Profile Scaling | When an ESI ID changes meters and profile ID assignment when changing from a NIDR to IDR meter, the IDR data is likely to be unavailable for at least the Initial Settlement. Currently the IDR default profile would be used and is likely to be an over statement of the Load for the ESI ID. By scaling the IDR default profile based on the Load of the last NIDR readings would greatly reduce the variance. | 10/08/2003 | Reliant (on behalf of PWG) | No | 11.3.3.3 | Approved | |
| PRR472 | ERCOT Meter Read Transaction Validation Reinstatement | Ensures that meter read transactions received by ERCOT from the TDSP or any 3rd party service provider have been completely validated for technical, business and data set points prior to ERCOT's submittal of the transaction to the Market Participant(s) designated to receive the information | 10/29/2003 | TEAM | No | 10.12.1, 15.3 | Rejected | |
| PRR473 | Reactive Standards | This PRR is intended to make the Protocols conform to the Reactive Standards adopted by TAC. Those portions of the standards that are most appropriately contained in the Protocols are included while other sections are judged to be best located in the Operating Guides. The PRR also includes a specific payment mechanism for induction generators that elect to make a payment in lieu of meeting the installed standard. | 10/30/2003 | WMS | No | 2.1, 5.1.3, 5.2, 5.2.1 [new], 5.2.2, 5.2.3, 5.5.1, 5.5.2, 6.1.7, 6.4.2, 6.5.7, 6.5.7.1-3 [new], 6.7.6, 6.8.4, 6.10.3.5, 6.10.9, 12.4.3 | Approved | |
| PRR474 | Short Pay Payment Plan | The knowledge of short payment plans are essential for QSE(s) and the Entities they represent to ensure proper allocation and tracking of funds owed. Without this knowledge it is extremely difficult for QSE(s) to manage their respective accounting processes. Urgent status is requested due to this information being essential to year-end account book closing and therefore the plans must be made available to QSEs by the end of the year. | 11/10/2003 | American National Power | Yes | 9.4.4 | Approved | |
| PRR475 | Unit Specific Deployment based on Generic Costs | Currently, units are deployed based on the up and down bid premiums submitted in the Resource Plan. With the removal of Market Solution, units are paid based on generic cost for all instructions. Implementing this PRR would bring deployment in line with settlement, deploy the more economical units in instances of Local Congestion, and result in lower Uplift cost. | 11/13/2003 | WMS | Yes | 4.4.20 [new], 6.7.1.2 | Approved | |
| PRR476 | Ramp Rate Adherence During Local Congestion | Currently, the ramp rates on individual resources are ignored during Local Congestion. This leads to Dispatch Instructions that are impossible to adhere to, especially when every unit running for a QSE is getting a unit specific instruction. Although a QSE may ignore category 4 instructions, they must still follow the category 1. In the event that every unit running for a QSE in a zone is getting a category 4, they all make up the category 1. As a result of the ramp rates being violated, SCE cannot be followed, which puts a strain on frequency which leads to regulation and balancing instructions. Further, the QSE can potentially be penalized with imbalance charges for not keeping SCE at 0. | 11/13/2003 | Exelon | Yes | 6.7.1.2, 6.10.7 | Withdrawn | |
| PRR477 | Section 19 Texas Standard Electronic Transaction (SET) | Updated verbiage to better understand the transactions and bring Section 19 inline with the current ERCOT change control release for new transactions and transaction that were removed. | 11/19/2003 | TXU | No | 19 | Approved | |
| PRR478 | Use of Lagged Dynamic Samples for New Load Profiles | This is a change to the method for creating Load Profiles allowing for the use of lagged dynamic samples for new profiles adopted subsequent to market open. | 11/19/2003 | Reliant | No | 18.2.2, 18.2.7 | Approved | |
| PRR479 | IDR Optional Removal Threshold | Allow the removal of an IDR meter for settlement under certain conditions when load drops below a minimum threshold. | 12/04/2003 | Reliant | No | 18.6.1, 18.6.7 [new], 18.6.8 [new] | Approved | |
| PRR480 | Reporting of Switch and Move-In Data | This PRR would require ERCOT to post on a monthly basis the number of residential and commercial customers served by the AREP and by all CRs combined, as well as the levels of switches and move-ins completed during the month by the AREP and CRs for residential and commercial customers. | 12/04/2003 | GMEC | No | 15.6 [new] | Withdrawn | |
| PRR481 | Liability for QSE default on Obligations to ERCOT | This revision would allocate responsibility for default of a QSE among Resources and Loads. Currently, only Loads bear the risk for default of an a QSE. This provision would allocate liability across both the generation and load sectors of the market in recognition of the fact that both load and generation engage in market behaviors and make decisions and policies that affect the viability of LSEs in the market. This broader sharing of risk of default of a QSE is a feature of the PJM market and will likely be a feature of the MISO market. Both of these markets have recognized the need to ensure that Market Participants have an incentive to behave in a manner and to promote decisions and policies that are in the best interests of the market as a whole. | 12/22/2003 | GMEC & ERCOT | Yes | 9.4.4 | Rejected | |
| PRR482 | Responsibility for ERCOT Administration Fee | This revision would allocate the ERCOT administrative charge equally between Resources and Loads consistent with the requirements of PURA §39.151(e). This allocation is appropriate because both Load and Generation impact ERCOT costs. | 12/22/2003 | GMEC & ERCOT | Yes | 9.7.1 | Rejected | |
| PRR483 | Interruptible LaaR Response to Instructions | The Load Response to Instructions has always been a requirement from LaaRs, so this just adds it to the list. For reliability reasons, ERCOT feels the Load Resource Response to Instructions should be a Real Time signal telemetered from the QSE and not a calculation based on information provided in the Resource Plan. | 12/24/2003 | ERCOT | No | 6.5.1.1, 6.10.4.4 | Approved | |
| PRR484 | Changes for Implementation of Direct Load Control (DLC) | The requested changes will facilitate and specify how DLC programs participate in the BUL market. | 12/29/2003 | DSWG | Yes | 6.10.2, 6.10.5.2 | Approved | |
| PRR485 | Revision to Unit-Specific Deployment Based on Generic Cost | This revision includes RMR Units in the list of exceptions and would avoid the bids for certain types of units exceeding the $1,000/MW bid cap. | 01/13/2004 | WMS | Yes | 4.4.20 | Approved | |
| PRR486 | Fuel Oil Inventory Service | This PRR adds Fuel Oil Inventory Service as an Ancillary Service that can be provided by Generating Resources. | 01/14/2004 | TXU | No | 1.3.1.2, 2.1, 4.5.11, 4.5.11.1, 4.5.11.2, 4.5.11.5 [new], 5.6.1, 5.6.7, 6.1.13 [new], 6.2.1, 6.3.1, 6.4.2, 6.5.12 [new], 6.6.2, 6.8.6 [new], 6.9.4, 6.9.4.4 [new], 6.10.3.7 [new], 12.4.2, 12.4.4 | Rejected | |
| PRR487 | Black Start Resources | Changes Black Start Ancillary Services language to allow an ERCOT Resource with a firm standby supply contract with an adjacent power pool supplier to bid as an ERCOT Black Start Resource. | 01/15/2004 | AEP | No | 6.1.8, 6.10.3.6 | Approved | |
| PRR488 | Weather Responsiveness Determination | Amend the weather responsiveness determination to reflect the requirement for TDSPs to submit profile code changes, to prevent changing the weather responsiveness based on missing data, to establish a threshold for the amount of missing data and to set up a process to re-test ESI IDs with insufficient data. | 01/15/2004 | PWG | No | 11.3.3.1 | Approved | |
| PRR489 | Ancillary Service Deployment Performance Conditions | Revises the requirement that ERCOT remove from consideration of average performance of a QSE any interval or group of intervals in which any one of several specific events (e.g., OOME deployments to the QSE) has occurred. | 01/19/2004 | TXU | No | 6.10.6 | Approved | |
| PRR490 | LaaR Annual Testing Description | This revision changes LaaR seasonal testing to an annual test consisting of a telemetry check and includes a biennial test of the under frequency relay for LaaRs providing Responsive Reserve Service. | 01/19/2004 | ERCOT | No | 6.10.2 | Approved | |
| PRR491 | Clarification to PRR 413 RPRS Market | This PRR separates the RPRS bid price used to resolve Local Congestion from that used to resolve Zonal Congestion and capacity insufficiency. For procurement of local capacity, the solution uses the Resource Category Generic Cost. For procurement of zonal or system capacity, the solution uses the submitted RPRS bids. The Market Solution concept is removed. PRR 466 has extended the current expiration date for the suspension of Market Solution for Local Balancing Energy from December 31, 2003 to February 1, 2005. | 01/22/2004 | ERCOT | Yes | 6.6.3.2.1, 6.8.1.11, 7.4.2 | Approved | |
| PRR492 | Plan to Alleviate Chronic Local Congestion | The PRR requires ERCOT and the associated TDSP to identify and implement feasible alternatives to local transmission once certain dollar thresholds are met. | 01/29/2004 | ERCOT | Yes | 7.4.5 [new] | Approved | |
| PRR493 | Induction Generator Exemption | Revise section to clarify the mechanism an induction generator may use to receive an exemption from the generator and the level of the payment to be made. | 02/12/2004 | AEP | Yes | 6.5.7.1 | Approved | |
| PRR494 | Revise Forecasted Load Profile Post time | ERCOT will publish forecasted Load Profiles for the next three business days no later that 5:30 a.m. in addition to there current posting at 10:00 a.m. This PRR also Clarifies that ERCOT will provide historical Load Profile data for up to the previous two years. | 02/24/2004 | Cirro Energy | No | 18.3.3 | Withdrawn | |
| PRR495 | Effect of Short Payments Owed on Estimated Aggregate Liability (EAL) | Modify the determination of Estimated Aggregate Liability (EAL) to include the effects of short payment amounts owed to QSEs by ERCOT. | 03/03/2004 | CenterPoint Energy | Yes | 16.2.7.3 | Rejected | |
| PRR496 | Block Bidding and Deployment of LaaRs providing Responsive Reserve Service and Non-Spinning Reserve Service | Include provisions for LaaRs to have the option to bid Responsive Reserve Service and Non-Spinning Reserve Service as a block. | 03/03/2004 | DSWG / ERCOT | No | 4.4.11, 6.6.3.1, 6.7.3, 6.7.4 | Approved | |
| PRR497 | Unavailable Units and RMR Agreements | Restores the evaluation and notice requirement until alternate Protocol language can be developed. The language included in this PRR is identical to the language in PRR452 approved by the Board in October 2003. The March 31, 2004 expiration date of the PRR452 language was intended to allow time for a new PRR that enhances the process in the PRR452 language. Good progress has been made on a new PRR. The RMR Task Force has almost finalized a draft for PRS consideration. Failure to reinstate the language from PRR452 that expires on March 31 could adversely impact ERCOTs ability to prevent critical generation units from exiting the system. | 03/04/2004 | ERCOT | Yes | 8.1.3.2 | Approved | |
| PRR498 | Exclusion of Payment For Black Start Service from Short Payment Obligation | Revise Section 9.4.4, Partial Payments, to exclude payments for Black Start Service from the calculation of reduced payments to Invoice Recipients when ERCOT incurs short payments. | 03/11/2004 | CenterPoint Energy | No | 9.4.4 | Rejected | |
| PRR499 | Eliminate Fuel Shortage Notice | Eliminates the requirement for ERCOT to issue an Emergency Notice for fuel shortage. | 03/15/2004 | Constellation | No | 5.6.3, 5.6.4, 5.6.6 | Approved | |
| PRR500 | OOME Down Payments - Verifiable Costs | The OOME Up payment mechanism provides for verifiable costs in excess of normal OOME Up payment. Having this same mechanism in the OOME Down payment structure provides fairness to Market Participants. | 03/17/2004 | Brazos Electric Cooperative | No | 6.8.2.3 | Withdrawn | |
| PRR501 | A/S Revision to Down Balancing Requirement | Revise the Down Balancing Requirement to account for Regulation Down obligations. | 03/17/2004 | Constellation | No | 4.5.2, 6.5.2 | Approved | |
| PRR502 | Aggregation of Combined Cycle Units Providing RRS | Allows RRS obligations awarded to combined cycle plants to be aggregated for all units in a block for consideration of compliance. | 03/17/2004 | Constellation | Yes | 6.10.5.4 | Approved | |
| PRR503 | Section 8 Coordination of Resource Outage Due to TSP | Resource Entities that have arranged for redundant interconnection onto the ERCOT Transmission Grid, during the construction and interconnection phase, shall not be exposed to interruption of both interconnections at the same time, without the TSP arranging for station service and ERCOT taking on the responsibility of serving the Resource Entitys obligations. | 03/19/2004 | PSEG Texgen | No | 8.2.4 | Withdrawn | |
| PRR504 | Resource Derating Clarification | Provides an explanation of what constitutes a Resource deration. | 03/23/2004 | ROS | No | 8.6.3 | Approved | |
| PRR505 | Elimination of OOME Down Payments | This revision would eliminate the compensation currently provided for all Resources called upon for OOME Down and/or Local Balancing Energy Down (generic costs or generic bid limits would still be used as a deployment selection criteria, but not for settlement). Because the language changes desired for this PRR are in the same subsections of Section 6 & 7 as changes currently proposed in PRR485, a request currently in-flight, specific Protocol Section edits are not provided at this time (see Protocols Section 21.4.1(5), providing that suggested language for requested revisions is optional). Once PRR485 is considered by TAC and the BOD, the applicable baseline language will be redlined and submitted as comments to this PRR. | 03/24/2004 | City Public Service of San Antonio | No | 6 & 7 | Withdrawn | |
| PRR506 | Revision to Short Payment Process | Revises the timeline for uplift of partial payments. | 03/29/2004 | Constellation | No | 9.4.4 | Withdrawn | |
| PRR507 | RMR Process enhancements | The proposed revisions to Sections 2, 6.5.9.1, 6.8.3.1, 8.1.3.2 and 22(I) streamline and clarify the RMR initiation process timeline and add incentives for Resource Owners to negotiate RMR agreements. | 03/30/2003 | ERCOT | No | 6.5.9.1, 6.8.3.1, 8.1.3.2, 22(I) | Approved | |
| PRR508 | Date of Congestion Zone Changes | Currently, the Protocols require that changes to CSCs and Congestion Zones are effective on January 1st. This PRR proposes to modify the date that changes to CSCs and Congestions Zones will become effective on April 1st, if required. It also proposes a modification to the monthly TCR auction for the months of January through March 2005, the annual auctions for 2005 and 2006. | 04/01/2004 | ERCOT | No | 7.2.1.1, 7.2.1.3, 7.5.1, 7.5.2, 7.5.2.1, 7.5.3.1 | Rejected | |
| PRR509 | Initiation, Procedure, and Settlement of Disputes through ADR | The changes describe the process for initiating the ADR process, deadlines for prosecuting ADRs, and implementing ADR resolutions in the Settlement process. | 04/01/2004 | ERCOT | No | 20.1; [new] 20.1.1; [new] 20.1.2; 20.2; [new] 20.6; [new] 20.6.1; [new] 20.6.2; [new] 20.7; [new] 20.8; [new] 20.8.1; [new] 20.8.2; [new] 20.8.3 | Approved | |
| PRR510 | Remove PIP134 and PIP158 Boxed Language | This PRR removes changes due to PIP134 and PIP158, which will not be supported. PIP134 required ERCOT System and Zonal Load forecasts to be distributed through the Message System and PIP158 added information contained in Dispatch Instructions. | 04/01/2004 | ERCOT | No | 5.4.2.2; 6.4.2 | Approved | |
| PRR511 | Clarification of PCR Eligibility | The change is a forward-looking clarification of the eligibility for PCRs. The existing language is ambiguous regarding contractual changes between NOIEs and full requirement suppliers. The new wording has been vetted through the TNT Congestion Management Concept group and approved for inclusion in the CRR Whitepaper by the full TNT.In no case will the proposed change create new PCR eligible transactions. | 04/05/2004 | LCRA | No | 7.5.6 | Withdrawn | |
| PRR512 | OOMC and OOME of LaaRs | This PRR clarifies that LaaRs will not be given OOMC and will be limited to a capped amount of verifiable cost recovery. | 04/16/2004 | TXU | Yes | 6.1.10, 6.5.10, 6.8.2.1, 6.8.2.2, 6.8.2.3, 6.10.8 | Approved | |
| PRR513 | Verification of Operational Model after Recurring Local Congestion Event | This PRR makes it mandatory for ERCOT to verify the transmission model after Local Congestion occurs repeatedly. | 04/16/2004 | Brazos | Yes | 7.4.1 | Approved | |
| PRR514 | Twelve Month Window for Non-IDR Scaling | Change the window used in data aggregation for estimating non-IDR meter reads when data for a trade day is not present in ERCOT systems. | 04/16/2004 | PWG | No | 11.3.2 | Approved | |
| PRR515 | Disclosure of Local Congestion | This PRR provides for the disclosure of information on each unit receiving OOMC/OOME, the intervals and amount of OOMC/OOME provided as well as the transmission studies that lead to OOMC/OOME/RMR deployments. This PRR also provides for disclosure of the contingency and/or overloaded element(s) causing the Local Congestion deployments ASAP. | 04/29/2004 | TXU | No | 1.3.1.1, 1.3.1.2, 6.5.10, 6.7.8 | Approved | |
| PRR516 | Curtailment Prioritization for Wind Generators Introduces the concept of using in-service date to determine curtailment priority in situations where only wind generators are needed to resolve local congestion | Requires new WPGRs locating in the McCamey area to install Special Protection Schemes to limit their output. | 04/30/2004 | FPL Energy | No | 7.4.2, 7.8.8 | Withdrawn | |
| PRR517 | Reduce the Number of Annual TCRs Sold to 40% from 60% | This PRR wants to reduce the number of annual TCRs being sold from 60% to 40%. | 05/17/2004 | ERCOT | No | 7.5.3.1 | Approved | |
| PRR518 | Clarification of Requirements Relating to Retail Transactions | Improve retail market transaction processing by clarifying requirements and timelines. | 05/18/2004 | GMEC | No | 2, 15 | Approved | |
| PRR519 | ERCOT and TDSP Acceptance of Customer Cancellation of Switch Request | Revise current Protocol language to clarify that ERCOT and the TDSP will accept cancellations (814_08s) until five (5) Business Days preceding the effectuating meter read date. | 05/18/2004 | ERCOT | Yes | 15.1.1.4 | Approved | |
| PRR520 | Resource Plan Performance Metrics | Establishes Resource Plan performance metrics which are needed for ERCOT to accurately monitor compliance with the Protocols. This revision also defines acronyms for High/Low Operating Limit and High/Low Sustainable Limit. | 05/24/2004 | ERCOT | No | 2.1, 2.2, 4.4.15, 4.10 [new] | Approved | |
| PRR521 | Add Fleet/Zonal OOME instruction to SCE Calculation | For Release 4, ERCOT is planning on partially implementing PRR 422. It is not within the scope of Release 4 to include Fleet/Zonal OOME instructions in market clearing, thus an addition to the SCE equation is necessary to aid a QSE who receives a fleet deployment in following its SCE. | 05/25/2004 | ERCOT | No | 6.10.4.4, 6.7.7.1 | Approved | |
| PRR522 | Collateral Requirements and Credit Changes | Changes are proposed to strengthen ERCOTs ability to enforce collateral and offset appropriately in bankruptcy situations. Changes also will adjust collateral requirements for known or estimated potential liability, Other clean up language is also incorporated. | 06/01/2004 | ERCOT | No | 2.1, 9.4.1, 9.4.2, 9.4.3, 9.4.4, 9.4.5, 16.1, 16.2 | Approved | |
| PRR523 | Revisions to Protocol Section 21 | This PRR modifies the process for revising the Protocols, including: establishing timelines for ERCOT to complete Impact Analyses for all PRRs submitted, standardizing certain provisions, correcting grammatical errors; and formalizing the process for submitting and approving System Change Requests. | 06/02/2004 | ERCOT | No | 21 | Approved | |
| PRR524 | Clarification of Timeline for Cost Submission | Most disputes of the Initial Settlement Statements must be initiated, negotiated and resolved by the issuance of Final Settlement Statements. This PRR will extend the same requirements to the submission of verifiable costs. | 06/07/2004 | Direct Energy | No | 6.8.1.11, 6.8.2.2, 6.8.2.3, 6.8.3.1, 6.8.3.3 | Withdrawn | |
| PRR525 | SCE Performance and Monitoring | Frequency control has been an on-going issue and concern with Market Participants and ERCOT. PRR 356 (SCE Performance Requirement) and PRR 358 (Negative Impact Schedule Control Error) were submitted, respectively, in August and September of 2002 with the intent of providing incentives to QSEs to more closely follow SCE, thereby resulting in improved frequency control and reliability. These two PRRs have been languishing for nearly two years, with no resolution expected. | 06/10/2004 | TXU | No | 6.10.4, 6.10.4.1, 6.10.5, 6.10.5.1, 6.10.5.3, 6.10.5.6, 6.10.6 | Approved | |
| PRR526 | OOMC Verifiable Cost Documentation | Section 6.8.2.2 requires that for recovery of actual cost associated with OOMC instructions specific documentation standards be outlined in the protocols. This new section 6.8.2.2(iv) defines the documentation standards required when ERCOT cancels or delays units planned & approved maintenance outage via an OOMC instruction, with insufficient time to avoid additional costs. | 06/15/2004 | AEP | No | 6.8.2.2 | Approved | |
| PRR527 | Clarify OOM Definition | Current interpretation is that OOM only includes operator manual entry of unit specific deployment. | 06/21/2004 | TXU | Yes | 2.1 | Approved | |
| PRR528 | Deadline for Filing ADR Claims | Amends the deadline for filing an Alternative Dispute Resolution (ADR) claim for denied settlement and billing disputes from thirty (30) to forty-five (45) days. | 06/29/2004 | COPS | No | 9.5.4 | Approved | |
| PRR529 | Calculating Final REC Purchasing Requirements | Revises Section 14 to reflect REC Program software changes that (1) allow for recalculation of previous years Final REC Requirements for all Competitive Retailers and (2) change the way the Final REC Requirements are calculated. | 06/30/2004 | ERCOT | Yes | 14 | Approved | |
| PRR530 | Short Pay Uplift to LSEs | Require the uplift of and short payment to Load on a more timely basis. | 06/30/2004 | CWG | No | 9.4.4 | Rejected | |
| PRR531 | Load Clarification | Make modifications necessary to clarify the registration and treatment of loads associated with Block Load Transfers. Clarifies BLT load points of delivery are wholesale loads that are not subject to Texas retail choice and that should be treated similar to NOIE loads. | 07/07/2004 | AEP | No | 2.1, 5.7, 5.7.2, 16.3 | Approved | |
| PRR532 | Implementation of Non-Transmission Alternatives to RMR and OOM Services | Revisions to allow ERCOT to implement non-transmission alternatives to Reliability Must-Run (RMR) and Out-Of-Merit (OOM) Services to reduce uneconomic uplift. | 07/20/2004 | WMS | No | 2.1, 6.1.9, 6.3.1, 6.5.9.2, 6.7.8, 6.8.3, 6.9.4.2, 7.4.5 | Approved | |
| PRR533 | Definition of Transmission Facility Owner | Responsibility associated with providing model data is not clearly defined in the Protocols. The use of TDSP has not provided clear direction for owners, operators, and ERCOT regarding model data submission. Suggested removal of responsibilities associated with Outage Scheduling provides a streamline appropriate flow of information. | 07/29/2004 | LCRA | No | 2, 8.3.8, 8.8.2.1, 8.8.2.4, 12.4.4.1, 12.4.4.1.1, 12.4.4.1.2, 12.4.4.2.2, 12.4.4.2.3.1 | Withdrawn | |
| PRR534 | Temporary Modifications to the Annual Load Profile ID Assignment and Validation Process | Inserts language in Protocols to allow temporary modifications applicable to the process for annual Load Profile ID Assignment and Validation to be established and approved by the ERCOT Board. | 08/02/2004 | RMS | Yes | 18.4.3 | Approved | |
| PRR535 | Reactive Testing | This PRR is to clarify this section and to minimize the possibility of misinterpretation of the time period between testing of a generators reactive capability. | 08/02/2004 | GRTPTF | No | 6.10.3.5 | Approved | |
| PRR536 | Mandatory IDR Threshold Reduction | Lower the mandatory threshold for IDR mandatory installation to 700 kW (or kVA) and be complete by January 30, 2006. | 08/17/2004 | PWG | No | 18.6.1; 18.6.6 | Approved | |
| PRR537 | Increased Congestion Management Flexibility | This PRR provides ERCOT with additional options to use in the management of congestion both in day-ahead and real-time operations. | 08/23/2004 | TXU Energy | Yes | 1.3.1.1; 6.5.10 | Approved | |
| PRR538 | OOMC Generic Cost for Coal | Establish generic cost for coal plants for use when they receive OOMC Instructions. This same logic would apply to Nuclear & Hydro units. | 09/01/2004 | AEP | No | 6.8.2.1 | Approved | |
| PRR539 | OOMC Claw Back Correction | Prevents payments for OOMC service from being negative (a charge) | 09/01/2004 | AEP | No | 6.8.2.2 | Withdrawn | |
| PRR540 | OOM Cost Recovery Process Clarification | Clarify the process ERCOT is to use when making payments for cost recovery request associated with OOMC & OOME instructions. Clarify payments for cost categories approved in an executive session of the Board are to occur on a Resettlement Statement rather than waiting for the True Up Statement. | 09/01/2004 | AEP | No | 6.8.2.2; 6.8.2.3 | Approved | |
| PRR541 | Regulation Deployment Ramp Rate | Eliminates implied ramp rate limitation on Regulation Service deployments and clarify that the limitations outlined for performance purposes are not intended to limit ERCOTs ability to fully deploy regulation at any time. | 09/01/2004 | AEP | No | 6.7.2; 6.10.5.3 | Rejected | |
| PRR542 | Clarifying the LaaR Three Hour Limit | Clarify that QSEs are allowed to replace LaaR Responsive Reserve with Responsive Reserve from a Generating Resource or other uncommitted LaaR following a deployment of Responsive Reserve Service. | 09/08/2004 | DSWG | No | 6.10.5.4 | Approved | |
| PRR543 | Schedules and Emergency Assistance Over CFE-ERCOT DC Ties | Incorporates the use of DC ties with CFE for commercial and emergency services. | 09/14/2004 | ERCOT | No | 4.4.18.1, 5.6.6.1, 5.6.7, 5.6.8, 5.8, 6.8.2.1 | Approved | |
| PRR544 | Twelve Month Window for Scaling NIDR to IDR ESI IDs | Modifies the window for Non-Weather Sensitive Proxy Day selection from 6 months to 12 months. | 09/20/2004 | PWG | No | 11.3.3.3 | Approved | |
| PRR545 | Retail Market Extracts | Include in Section 11 a new 11.3 that addresses ESI ID-level extract information provided to LSEs | 09/21/2004 | RMS | No | 11.3 [new] | Approved | |
| PRR546 | PCR Treatment for Federal Hydropower Resources | Tex-La and Rayburn propose to revise Protocols Section 7.5.6 to provide that long-term power purchase agreements for federal hydropower are eligible for PCR treatment if a long-term allocation was in place prior to September 1, 1999. | 10/01/2004 | Tex-La Rayburn | Yes | 7.5.6 | Approved | |
| PRR547 | Trading Hubs | This PRR creates a new section that establishes a definition of a trading hub and specifically identifies the transmission buses that make up each trading hub. | 10/01/2004 | CMWG | No | 7.9 | Approved | |
| PRR548 | Settlement for Mismatched Inter-QSE Energy Schedules | This PRR proposes to reduce the quantities of energy scheduled by ERCOT into or from the Balancing Energy market during intervals in which Inter-QSE trades do not match. This will reduce ERCOT and Market Participants credit exposure to entities which submit mismatched inter-QSE trades. | 10/04/2004 | Tenaska | No | 4.7.2, 6.9.8 | Rejected | |
| PRR549 | Regulation Control During Abnormal Frequency Events | This PRR revises Sections 6.5.3, 6.8.1.15.1, and 6.10.6 to establish an ERCOT frequency deadband of +/- 0.03Hz to aid in regulation control during abnormal frequency events. When ERCOT frequency is outside the deadband, any Qualified Scheduling Entity (QSE) that has a System Control Error (SCE) that is acting to return frequency to a level that is within the deadband will continue to send Dispatch signals to their Resources until the ERCOT frequency returns to a level that is within the deadband. However, in the case when ERCOT frequency is outside the deadband and, any QSE has an SCE error that is acting to move frequency further outside the deadband, that QSE will temporarily suspend sending signals to its Resources until ERCOT frequency returns to a level that is within the deadband. | 10/08/2004 | TXU | No | 6.5.3, 6.8.1.15, 6.10.6 | Withdrawn | |
| PRR550 | Pace of Short Pay Uplift to LSEs | This revision sets a rate at which money due from QSEs representing load is collected. | 10/13/2004 | LCRA | Yes | 9.4.4 | Approved | |
| PRR551 | Security Interest | This PRR adds additional language to the Protocols to greater protect ERCOT Market Participants in the event of a bankruptcy. | 10/15/2004 | ERCOT | No | 16.2.5.1.2 16.8.1.5.3 | Approved | |
| PRR552 | Clarification of Relaxed Balanced Schedules | Clarifies section 4.3.2 Schedule Components to ensure that QSEs may schedule Load or generation, even though they may not physically represent Load or generation. | 10/18/2004 | Coral | No | 4.3.2 | Withdrawn | |
| PRR553 | Scheduling Trading Hubs | Modify ERCOTs scheduling requirements to accommodate transactions involving ERCOT Trading Hubs. | 10/20/2004 | TXU | No | 4.2, 4.3.1, 4.4.8, 4.7.2, 4.9.4.1 | Withdrawn | |
| PRR554 | ERCOT Approval of Transmission System Outages | Changes language to allow ERCOT to approve requested outages that may interrupt provision of a required reliability service such as Black Start service or RMR service if an alternate supplier is available. | 10/29/2004 | Black Start TF | No | 8.3.1 | Withdrawn | |
| PRR555 | Modify Number of Sub-QSEs a Single Entity Can Partition | Revise the Protocols to increase the maximum number of Sub-QSEs an Entity can implement from three to twenty. | 11/09/2004 | Calpine | No | 16.2.1 | Approved | |
| PRR556 | Elimination of ERCOT-wide Uplift of Costs Related to OOMC, OOME, LBES and RMR Payments | Changes the allocation of OOMC, OOME, LBES and RMR costs from ERCOT-wide LRS to Congestion Zone LRS. | 11/12/2004 | Reliant | No | 6.9.4.2, 6.9.7.1, 6.9.7.2 | Rejected | |
| PRR557 | Late Fees and Late Fee Recovery | Clarifies how late fees are calculated and distributed. | 11/23/2004 | ERCOT | No | 9.4.4, 9.4.6 | Approved | |
| PRR558 | Market Notice of LaaR Proration | Allow market participants to be notified when LaaRs awards for Responsive Reserve are prorated by ERCOT. | 11/23/2004 | DSWG | No | 4.4.13, 6.6.3.1 | Approved | |
| PRR559 | Regulation E10 Update and SCPS1/SCPS2 References | Change E10 to the current value being used. Add references to call measures SCPS1 and SCPS2 as they are commonly referred to. | 11/23/2004 | ERCOT | No | 6.10.5.3 | Approved | |
| PRR560 | QSE Qualification Using LaaRs | Add Protocol Language what describes how a QSE can qualify to provide Ancillary Services by using only LaaR Resources | 11/23/2004 | ERCOT | No | 6.10.3, 6.10.3.2, 6.10.3.3, 6.10.3.4 | Approved | |
| PRR561 | Remove Nuclear and Hydroelectric Generators from Automatic Deployment Software | This revision directs ERCOT to remove Nuclear and Hydro Electric generation from any software driven automatic solution to resolve congestion. ERCOT retains the right to provide verbal dispatch instructions during an ERCOT emergency when it is deemed that the Hydro or Nuclear unit in question is uniquely qualified to resolve the problem. | 12/09/2004 | LCRA | No | 4.4.20, 6.7.1.2 | Approved | |
| PRR562 | Permanent Elimination of Market Solution for Local Congestion | Section 7.4.3 regarding the prohibition of the use of a Market Solution for Local Congestion payment is scheduled to expire Feb. 1, 2005. This revision would eliminate the date of such expiration. | 12/16/2004 | CPS | Yes | 7.4.3 | Approved | |
| PRR563 | Standard Form Black Start Agreement - Payment | With PRR487 (Black Start Resources) approval, Black Start resources, within close proximity of another power pool, which are capable of starting from such power pool via a firm standby power supply contract, are available if the resources and the transmission line(s) connecting the Black Start resource and the external power pool are both in service. | 12/17/2004 | BSTF | No | Section 22 Attachment A Section 9 B. (1) | Approved | |
| PRR564 | Clarification of OOME Definition | While the protocols implicitly indicate that an SPS actuation as an OOME dispatch they do not explicitly include an SPS in its definition in section 6. | 12/17/2004 | ANP | No | 6.1.11 | Approved | |
| PRR565 | Calculation of Losses for Settlement | Modify the way distribution losses are calculated to be based on actual rather than forecasted ERCOT load. | 12/22/2004 | PWG | No | 13.1.1, 13.1.2, 13.3.1, 13.3.1.1, 13.3.1.2. | Approved | |
| PRR566 | Implementation of IDR Optional Removal Threshold | Allow the removal of an IDR meter for settlement under certain conditions when load drops below a minimum threshold. The language to allow a customer to request removal of an IDR meter under certain conditions was approved in PRR479. However, the language was boxed until the report required by Section 18.6.2 was modified to indicate whether a customer was eligible to request removal of the IDR meter. Based on discussions between Market Participants, OPUC, the PUCT and ERCOT staff, the PRR 479 language changes were not intended to require changes to the report specified in 18.6.2. This PRR modifies the language in 18.6.2 so that the report does not need to be modified and the language allowing the customer to request removal of the IDR meter can be unboxed. This PRR modifies the reporting requirement in Section 18.6.2 and unboxes the language that allows the customer to request removal of an IDR meter under such circumstances. | 01/12/2005 | OPUC | Yes | 18.6.2, 18.6.7 | Approved | |
| PRR567 | Block Bidding of Ancillary Services | Revision would allow QSEs to link ancillary service bids across consecutive hours and establish minimum block values that must be selected to clear the bid. | 01/19/2005 | Constellation | No | 4.4.11 | Rejected | |
| PRR568 | Change Initial Settlement from 17 days to 10 days | Change Initial Settlement from 17 days to 10 days. | 01/19/2005 | TXU Energy | No | 9.2.3 | Approved | |
| PRR569 | Revision to Balancing Energy Payments from a Specific Resource | Revision modifies the payment for Resource-specific deployments to use the fuel index for the current Operating Day. | 01/21/2005 | ERCOT | No | 7.4.3.1, 7.4.3.2 | Approved | |
| PRR570 | Clarification of Settlements of Local Congestion Costs | Clarify wording to specify that resources deployed by the Balancing Market will be paid the difference between MCPE and the Up/Down Premium Bid. | 01/21/2005 | ERCOT | No | 7.4.3.1, 7.4.3.2 | Approved | |
| PRR571 | Balancing Energy Bid Cap | Revises the definition of Balancing Energy Bid Cap by clarifying that Balancing Energy Service bids shall be between -$1,000 per MWh and $1,000 per MWh, inclusive, for all Resources. | 01/21/2005 | ERCOT | No | 6.5.2 | Approved | |
| PRR572 | Weather Sensitivity Classification | Includes language regarding procedures to determine weather sensitivity classifications when an ESI ID is inactive or de-energized. | 02/09/2005 | PWG | No | 11.4.3.1 | Approved | |
| PRR573 | Mothballed Generation Resource Definition and Time to Service Updates | This defines mothballed units and requires the responsible Generation Entity to report to ERCOT, twice annually, the lead time required to reliably return the unit to service. The Generation Entity would be required to document its claim to ERCOTs satisfaction. Time to service updates and supporting documentation would be considered Protected Information. | 02/09/2005 | Austin Energy | Yes | 1.3.1.1, 2.1, 6.5.9.3 | Approved | |
| PRR574 | Specify Effective Date for PRRs | Revise Section 21.1 to replace the terms ... additions, edits, deletions, revisions or clarifications with the term revise, and make it clear in Section 21.6 that all PRRs are effective only on a prospective basis from the date of implementation. | 02/10/2005 | CPS | No | 21.1, 21.6 | Withdrawn | |
| PRR575 | Mandatory Down Balancing Ramp Rate | Proposes new subsection (4.5.2(3)) that would clarify that the Mandatory Down Balancing Bid amount should be deployable within one interval. | 02/11/2005 | ERCOT | No | 4.5.2 | Approved | |
| PRR576 | Disclosure of OOME, OOMC, and RMR Service | This changes Protocol Sections which require that ERCOT post on the MIS Resource-specific information for OOMC, OOME and RMR Services. Also, a definition for Off-line has been added for consistency. | 02/18/2005 | ERCOT | No | 6.5.10, 6.7.8, 2.1 | Approved | |
| PRR577 | Availability of Aggregated Load Data by TDSP | Receive aggregated TDSP Load data from ERCOT for the purposes of accurately identifying TDSP system peaks required for FERC filings. | 02/28/2005 | TXU Energy | No | 11.5.1.1 | Approved | |
| PRR578 | Emergency Fuel Supply Resource Service | This PRR adds Emergency Fuel Supply Resource Service as an Ancillary Service that can be provided by Generating Resources or Load Resources. | 03/07/2005 | TXU Energy | No | 1.3.1.2, 2.1, 4.5.11, 4.5.11.1, 4.5.11.2, 5.6.1, 5.6.7, 6.2.1, 6.3.1, 6.4.2, 6.6.2, 6.9.4, 12.4.4 | Rejected | |
| PRR579 | Trading Hubs Language Correction | Modifies language in Section 7.9.2.1 for the calculation of the North 345 kV Trading Hub to be consistent with the calculation of the other three regional trading hubs by removing the 90% / 10% language that was originally applied to the North 345 kV Trading Hub only; Replaces the specific minimum scheduling increments by hub specified in Section 7.9.3.4 (2) with a Trading Hub to 2005 Congestion Zone conversion matrix. | 03/07/2005 | TXU Energy | Yes | 7.9.2.1, 7.9.3.4 | Approved | |
| PRR580 | Modify RMR Evaluation | Removes localized restriction on transmission constraints for consideration of RMR Units. | 03/08/2005 | CenterPoint | No | 6.1.9 | Rejected | |
| PRR581 | Update RMR Language Due to PUC Rule 25 | 502. Changes the RMR language to be consistent with PUC Substantive Rule 25.502, Pricing Safeguards in Markets Operated by the Electric Reliability Council of Texas, which became effective Jan. 9, 2005. | 03/08/2005 | CenterPoint | No | 6.5.9.1(7) & (8) | Approved | |
| PRR582 | Initiate RMR Negotiations | A new section that allows ERCOT to re-activate RMR negotiations with Generation Resource that has Mothball status and for which ERCOT has previously indicated no need for RMR Service | 03/08/2005 | CenterPoint | No | 6.5.9.4 (New) | Rejected | |
| PRR583 | Responsive Reserve Deployment | Revise Section 6.7.3 to distinguish Responsive Reserve deployments for frequency restoration from conditions that require EECP to be declared. | 03/11/2005 | ERCOT | No | 6.7.3 | Approved | |
| PRR584 | Extending Black Start Service Bid Timeline | Change Black Start Service Bids to a two year process | 03/25/2005 | BSTF | No | 6.5.8 | Rejected | |
| PRR585 | Settlement Obligation Formula for Balancing Energy Service | Adds the sum function in the Imbalance Ratio Share (IRSiq) settlement equation. | 03/25/2005 | ERCOT | No | 6.9.5.1 | Approved | |
| PRR586 | SCE Performance and Regulation Cost Re-allocation | Replaces monitoring of QSEs adherence to their base power schedules, Balancing Energy Dispatch Instructions, and Ancillary Service Dispatch Instructions with a single metric that motivates QSEs to stay on schedule and perform their obligations. | 04/01/2005 | PUCT Staff | No | 6.10.5, 9.6.1 | Rejected | |
| PRR587 | Midyear Modification of CSC or CRE definitions | Allow ERCOT staff the authority to modify CSC and CRE definitions midyear | 04/01/2005 | ERCOT | Yes | 7.2.2 (New) | Approved | |
| PRR588 | Testing of Quick Start Units in the Balancing Energy Market | This PRR establishes a test by which a quick start unit can demonstrate its ability to perform in the BES market. | 04/01/2005 | Austin Energy | No | 6.10.3.4 | Approved | |
| PRR589 | CSC and Zone Determination | This PRR is intended to strengthen ERCOT staffs role in the CSC and zone determination process. | 04/01/2005 | ERCOT | Yes | 7.2 | Approved | |
| PRR590 | Update Unit Telemetry Requirement | This revision proposes to add a requirement for QSEs to submit real-time AGC status and Ramp Rate for all online units in their portfolio. | 04/01/2005 | ERCOT | No | 6.5.1.1 | Approved | |
| PRR591 | Switchable Unit Declaration | This PRR defines switchable units and requires the responsible Generation Resource to report to ERCOT whether the unit is committed to another grid outside of ERCOT that would make it unavailable for capacity in the ERCOT market during the summer months. Unit availability reporting is considered Protected Information | 04/05/2005 | GATF | Yes | 1.3.1.1., 2.1, 6.3.2 | Approved | |
| PRR592 | Modify Shift Factor Calculation to Exclude Fixed Output Generators | Modifies the calculation of the monthly zonal Shift Factors used to manage and settle zonal congestion. | 04/05/2005 | ERCOT | Yes | 7.1, 7.2.1.2, 7.2.1.4, 7.3.4.1 | Approved | |
| PRR593 | Behind the "Fence" Reporting of Load | The GATF has recommended that a PRR be drafted that would add more resolution to the total actual ERCOT and projected Load. Due to generation netting, there could be a significant amount of Load that never gets reported to ERCOT | 04/13/2005 | GATF | Yes | 1.3.1.1, 10.3.2.3 | Approved | |
| PRR594 | Replacement Reserve Service Payment Formulas | Corrects the Resource Replacement Reserve Service payment formula to result in negative amounts. Modifies Protocol language to match or refer to the formulas in 6.8.1.10 and 6.8.1.11. | 04/14/2005 | ERCOT | Yes | 6.6.3.2.1, 6.8.1.1, 6.8.1.11 | Approved | |
| PRR595 | ERCOT Protocol Section 10 | The revision to Section 10 proposes clarity and consistency with current Market and ERCOT processes. | 04/19/2005 | MWG | No | Entire Section 10 | Approved | |
| PRR596 | Mothballed Generation Resource Estimated Return to Service Dates | This revision requires owners of Mothballed Generation Resources to provide annually to ERCOT projections of the MW of generation capacity of currently Mothballed Generation Resources that will return to service over the next five years. | 04/19/2005 | GATF | Yes | 6.5.9.3 | Approved | |
| PRR597 | Texas Test Plan Team | TTPT is revising all market place documentation (Section 23 in ERCOT Protocols, Section 6.1.2.2 in Retail Market Guide [RMGRR024], and TTPT Procedures) to keep all information uniform, consistent, and current. | 04/20/2005 | TTPT | No | 23 | Approved | |
| PRR598 | Extension of Credit Against OOM Start Up | If MCPE is greater than Resource Category Generic Minimum Energy Cost, the difference will be credited against Startup Cost. This credit against Startup Cost shall continue until the earlier of: a) the end of the calendar day; or b) the credit has completely covered the startup payment | 04/22/2005 | OPUC | No | 6.8.2.2 | Approved | |
| PRR599 | Notification for Mismatched Inter-QSE Energy Schedules | This PRR requires that notice be provided to both QSEs involved in a mismatch in the event that ERCOT remedies a mismatch as prescribed in PRR 548. The effective date for this PRR should be upon the implementation of PRR 548. | 05/02/2005 | COPS | No | 4.7.2 | Approved | |
| PRR600 | Align BES Bids with Resource Plan Capability and Resource Schedule | This documents the current ERCOT practice of limiting BES bids by the difference in Capacity in the Resource Plan and resource obligations and proposes language that is responsive to Potomac Economics recommendation number 8. | 05/04/2005 | QSE Manager's WG | No | 6.5.2 | Approved | |
| PRR601 | 15 Minute Ramping for BES and Base Power Schedule | The ramping period for BES deployment and for Base Power Schedule changes is changed from 10 minute to 15 minute | 05/04/2005 | QSE Manager's WG | No | 6.5.2, 6.8.1.15.3, 6.10.4.2 | Approved | |
| PRR602 | Ancillary Service Obligation for DC Tie Exports | This revision removes the allocation of Ancillary Service to DC Tie exports and provides for curtailment of DC Tie exports at Step 2 of EECP | 05/18/2005 | Tenaska | No | 4.4.18.2, 4.4.18.4, 5.6.6.1, 5.6.7 | Withdrawn | |
| PRR603 | Defaulting QSEs Cost Obligation in Second AS Market | This PRR removes a duplicate sentence in Section 6.6.3.2 of the current Protocols. It also removes Section 6.9.1.5(2) because such subsection is unnecessary in light of Section 6.9.1.5(1) and modifies Section 6.9.1.5 (3) to remove other unnecessary language. | 05/23/2005 | ERCOT | No | 6.6.3.2, 6.9.1.5 | Approved | |
| PRR604 | Replacement Reserve Service Bid Cap | This revision adds bid limit language for Generation Resources offering to provide Replacement Reserve Service (RPRS). | 05/25/2005 | First Choice Power | No | 4.4.11, 4.4.16 | Approved | |
| PRR605 | SCE Performance Monitoring for Combined Cycle Resources 052705 | Revise Sections 6.10.5.3 and subsections to change the SCE performance standard for combined cycle resources from 90% to 80%. | 05/27/2005 | Coral | No | 6.10.5.3 | Withdrawn | |
| PRR606 | User Security Administrators and Digital Certificates | Creation of new Section 16.11 defining User Security Administrators (USAs) and Digital Certificates; outlining responsibilities of the USAs; and requiring Market Participants to report results of their annual audits of their Digital Certificates to ERCOT. | 05/27/2005 | ERCOT | Yes | 16.11 (New) | Approved | |
| PRR607 | One-Minute Ramp Schedules | Allows QSEs representing Resources to submit one-minute schedules for the ramping period associated with unit start up and shut down. Requires ERCOT to accept these one-minute ramp schedules for operations, compliance, and settlement purposes. | 05/27/2005 | FPL Energy | No | 4.4.15, 4.10.4, 4.10.7 | Rejected | |
| PRR608 | Improve Ancillary Service Performance Conditions | Revise section 6.10.6 of the protocols to include the impact of different ramp rates on the calculation of a QSEs SCE Performance Metric. | 06/01/2005 | Coral | No | 6.10.6 | Withdrawn | |
| PRR609 | Smooth 15-minute Resource Schedules | Introduce explicit language that encourages QSEs to make use of Relaxed Balanced Schedules so that Resource Schedules are within the capability of the generating unit and make reasonable transitions between the 15-minute intervals. | 06/01/2005 | Tenaska | No | 4.3.5 | Rejected | |
| PRR610 | Reduction of OOME Down Payments | This revision would introduce further Resource Plan analysis by ERCOT between 1600 and 1800 prior to the Adjustment Period. It will require ERCOT to evaluate whether the scheduled capacity from the QSEs Generation Resources may cause transmission security violations during the Operating Day. If the potential for a transmission security violation exists, ERCOT would notify the QSE of the potential issue and the amount of MW in question with the understanding that the QSE, if it receives an OOME DN instruction, would not be paid to back down. This is intended to reduce the Uplift cost caused by a QSE that schedules more output in the Resource Plan than may be possible for the transmission system to absorb without causing a transmission security problem. The PRR does not change the Protocols that compensate generators for OOME Down instructions issued by ERCOT in Real-Time. | 06/10/2005 | Reliant Energy | No | 4.1.1, 4.4.16 (New), 6.8.2.3 | Rejected | |
| PRR611 | Reporting of Operation Reserve Capability Under Severe Gas Curtailments | Adds a requirement that Resources provide additional data describing their alternative fuel capability during the winter months. Adds information submitted under Section 12.4.7 to the list of items considered Protected Information in Section 1.3.1.1. | 06/14/2005 | ERCOT | No | 1.3.1.1, 12.4.7 (New) | Approved | |
| PRR612 | Ancillary Service Procurement During the Adjustment Period | This revision allows for the update of Ancillary Service bids after Notice of ERCOTs intent to procure Ancillary Services during the Adjustment Period. | 06/17/2005 | QSE Manager's WG | No | 4.5.8, 4.5.9.2 | Approved | |
| PRR613 | Replacement Reserve Under Scheduled Capacity Delineation | Updates To he Replacement Reserve Under Schedule Capacity section to reflect current Bill Determinants and their corresponding processes. | 06/27/2005 | ERCOT | Yes | 6.9.2.1.1 | Approved | |
| PRR614 | Balancing Bids for Replacement Capacity | Requests information on Load Management Standard Offer and Direct Load Control program Load reduction capability to allow ERCOT to determine if the programs meet the DLC criteria | 06/30/2005 | Exelon | Yes | 6.6.3.2.1 | Approved | |
| PRR615 | Direct Load Control Programs | Requests information on Load Management Standard Offer and Direct Load Control program Load reduction capability to allow ERCOT to determine if the programs meet the DLC criteria | 07/07/2005 | GATF | No | 6.3.2, 18.7.2 | Withdrawn | |
| PRR616 | Interim Solution for the Direct Assignment of Replacement Costs for System-wide Capacity Insufficiency | Provides for an interim solution for the procurement and cost assignment for RPRS for the purpose of system insufficiency as already required by the Protocols until such time as EMMS 4.0 is implemented. | 07/13/2005 | CPS | Yes | 6.1.6, 6.1.10, 6.6.3.2.1, 6.9.2.1.1 | Withdrawn | |
| PRR617 | IDR Optional Removal Threshold | This PRR will alleviate conflicting language and provide clarity on the original intent of Sections 18.6.1(2) and 18.6.7 as these sections relate to the process for an optional IDR removal and re-installation. This PRR also makes non-substantive changes to Sections 18.6.1 and 18.6.7. | 07/28/2005 | IDR TF | No | 18.6.1, 18.6.7 | Approved | |
| PRR618 | Balancing Energy Up from a Specific LAAR Resource | These proposed revisions provide an equation that describes how a QSE representing a LaaR receives compensation when a LaaR it represents provides Balancing Energy Up, and clarifies that only Generation Resources will provide Balancing Energy Down to resolve Local Congestion. | 07/28/2005 | ERCOT | No | 7.4.3.1, 7.4.3.2 | Approved | |
| PRR619 | Day Ahead Procurement of LaaR for RRS | All bids to provide Responsive Reserve Service (RRS) from Loads Acting as Resources (LaaR) submitted in the Day Ahead Market, with bid prices equal to or less than the applicable Market Clearing Price for Capacity (MCPC), will be awarded proportionally, using existing ERCOT procedures for handling multiple bids which have the same price. | 07/28/2005 | DSWG | No | 6.6.3.1 | Rejected | |
| PRR620 | Notifying QSEs of their DBES Percentages | This proposed revision would change the requirement for ERCOT to notify QSEs (via the web listener) concerning their mandatory Down Balancing Energy Service (DBES) percentages. ERCOT would only send notifications to QSEs if there is any change in the percentages of the mandatory Down Balancing Energy Service. This proposed revision would require ERCOT to always post the QSEs mandatory Down Balancing Energy Service percentages. | 08/19/2005 | BP | No | 4.4.5 | Approved |
01/01/2006
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| PRR621 | QSE Qualification Using Renewable Resources | Specifies QSEs representing only Uncontrollable Renewable Resources may qualify to provide Balancing Down Energy Service. The proposed language also clarifies that ERCOT may only request DBES in an amount actually deliverable from the Uncontrollable Renewable Resource based upon energy production at the time of the qualification. | 08/25/2005 | FPL Energy | No | 6.10.3.4 | Approved |
01/01/2006
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| PRR622 | Calculation of Marginal Heat Rate for Resources Receiving OOME Up Instructions | During the process of drafting language for PRR 540 (OOM Cost Recovery Process Clarification) a sentence was inadvertently left in the Protocols which is not consistent with the intent or scope of other Sections describing how to calculate a Generation Resource Marginal Heat Rate. In particular, under Section 6.8.2.3 (4)(b)(ii), the Protocols state; ERCOT will use the heat rate of the Resource at the deployed level. This is not consistent with the rest of the subparagraph describing Marginal Heat Rates and should be removed. | 08/25/2005 | ERCOT | No | 6.8.2.3 | Approved |
01/01/2006
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| PRR623 | Resource Plan Use for OOME Instructed Deviation | This PRR would align the Protocols with current EMMS system functionality by specifying that the most current Resource Plan available at the time of Real Time Balancing (RTB) Market Clearing be used for RTB calculations. | 08/25/2005 | ERCOT | No | 6.7.7.2 | Approved |
01/01/2006
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| PRR624 | Clarification of Market Participant Default Language | This PRR is the result of meetings of the WMS group within the TAC Joint Task Force formed to address market concerns resulting from recent market defaults. This PRR proposes changes that strengthen or clarify Protocol language that address default situations. Much of this language is based on language drafted for the TNT Protocols. | 08/26/2005 | WMS/RMS Joint TF | No | 16.2.8, 16.2.9, 16.2.10, 16.2.12, 16.2.14, 16.3.1.2, 16.8.1.7, 16.8.1.8, 16.8.1.9, 16.8.1.10 | Approved | |
| PRR625 | Clarification of Emergency QSE Language | This PRR is the result of meetings of the WMS side of the TAC Joint Task Force formed to address market concerns after recent market defaults. This PRR proposes changes that strengthen or clarify Protocol language that address when and how Emergency QSEs may be used. | 08/26/2005 | WMS/RMS Joint TF | No | 2.1, 16.2.4.3, 16.2.13 | Approved |
02/01/2006
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| PRR626 | Monthly RMR Status Report | Adds a requirement for ERCOT to post on the Market Information System (MIS) a monthly report on the status of Reliability Must-Run (RMR) contracts and exit strategies (e.g., Must-Run Alternative (MRA) contracts) including an explanation of any changes in RMR or MRA information from the previous months posting. | 08/26/2005 | TXU Wholesale | No | 6.5.9.2 | Withdrawn | |
| PRR627 | RMR Transmission Issues and RMR Contract Extension | Establishes reporting requirements for TDSPs responsible for construction of transmission system upgrades associated with an RMR and/or MRA exit strategy. Also provides ERCOT with additional flexibility to deal with potential delays in the completion of transmission system upgrades associated with an RMR and/or MRA exit strategy. ERCOT will be able to extend an RMR and/or MRA contract for limited time periods as necessary to allow for planned transmission system upgrades to be completed. ERCOT will also be able to require reporting of project status from the responsible TDSP. | 08/26/2005 | TXU Wholesale | No | 6.5.9.4 (new), 6.5.9.5 (new), 6.5.9.6 (new), 22F | Approved |
03/01/2006
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| PRR628 | ERCOT Operation Performance - Non-Spinning Reserve Service Deployments | Adds a requirement for ERCOT to publish on the MIS the percentage of Balancing Energy Service (BES) bids awarded in every interval that includes deployment of Non-Spinning Reserve Service (NSRS). Also adds a requirement for ERCOT to publish a monthly report showing the average percentage of BES bids awarded when NSRS was deployed in the month. Adds a performance metric for ERCOT that reports when deployment of NSRS (in accordance with Section 6.7.4 (1)) leads to excessive replenishment of the BES Up Bid Stack, which is defined to be 90% or less depleted. | 08/26/2005 | TXU Wholesale | No | 6.10.11 | Approved | |
| PRR629 | Proper Pricing of Non-Spinning Reserve Service Energy | Adjusts the Market Clearing Price of Energy (MCPE) for the deployment of Non-Spinning Reserve Service (NSRS) to provide correct price signals to the market by using the MCPE of the appropriate zone for the interval before deployment or the interval of deployment (whichever is higher) for pricing of Balancing Energy associated when Non-Spinning Reserve Service is used by ERCOT. | 08/26/2005 | TXU Wholesale | No | 6.8.1.12, 6.9.5.1 | Rejected | |
| PRR630 | Private Use Networks | Adds a requirement for private use networks (i.e., those networks that are connected to the ERCOT System that may include both generation and Load behind the meter) to maintain and report appropriate watt/VAR metering at each substation identical to the requirements of Distribution Service Providers (DSPs) and reporting of the addition or deletion of Load points. | 08/26/2005 | TXU Wholesale | No | 2.1, 5.2.1, 5.2.2 | Approved |
05/01/2006
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| PRR631 | Black Start Bid Procedures and Compensation for Testing | This PRR establishes a process that requires ERCOT to perform the simulation studies (the cost of which will be uplifted to the entire market through the ERCOT Administrative Fee) of Black Start Resources called for in Protocol Section 6.10.3.6(1)(f), rather than require the simulation to be done by the prospective Black Start Resource owner before the final Black Start Service awards are made by ERCOT. In addition, this PRR establishes a payment mechanism to reimburse Resource Owners for costs incurred in the qualification and/or testing of Black Start Resources. | 09/06/2005 | TXU Wholesale | No | 6.10.3.6 | Withdrawn | |
| PRR632 | Clawback Mechanism for Generating Resources at a Site with an RMR Unit | Establishes a clawback mechanism applicable to RMR Standby Cost to prevent improper subsidization of Generation Resources located at the same physical location as an RMR Unit. Such Resources are called RMR Companion Unit(s). The clawback mechanism reduces the hourly Standby Price paid for RMR Service by the profits earned by operation of any RMR Companion Units located at the same site as the RMR Unit up to the cumulative total hourly Standby Cost incurred. The profits of the RMR Companion Unit(s) are defined as the difference between the MCPE for each interval that the Companion Unit(s) operate and the Resource Category Generic Fuel Cost (RCGFC) for the Companion Unit(s) less the Resource Category Generic Start Cost of the RMR Resource if started during the period in which the RMR Companion Unit(s) operated. | 09/09/2005 | TXU Energy | No | 2.1, 6.8.3.1 | Rejected | |
| PRR633 | TSP Data Information Requirements | Update and clarify high level data requirements required by ERCOT from TSPs for modeling transmission grid modifications. Specifically require an energize date, ratings, the Entities responsible for proposed element ratings, and ERCOT specified data requirements. Also removed requirements for reporting work accomplished procedures, description of method to energize and test facilities, and in service testing. | 09/20/2005 | NDSWG | No | 8.8.2.1, 8.8.2.2 | Approved |
02/01/2006
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| PRR634 | ESI IDs Incorrectly Placed Into Inactive Status | Provide the ability for ERCOT to re-instate ESI IDs incorrectly placed into an inactive status | 09/22/2005 | DEWG | No | 15.4, 15.4.1.3 | Approved |
02/01/2006
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| PRR635 | Resource Plan Performance Metrics Update | Exclude units undergoing required testing from having to bid down balancing. Exclude units with physical and/or mechanical issues from having to show an inaccurate LSL and/or HSL. Exclude hours where the QSE updated their Resource Plan after the close of the Adjustment Period and failed to pass the Adjustment Period Zonal Schedule Measure for those hours. Clarify that the Down Bid & Obligation Measure is done by Congestion Zone when possible. Update the Resource Plan Performance Metrics to include improvements being made to the Resource Plan as part of Release 4. | 09/22/2005 | QSE Manager's WG | No | 4.5.2, 4.10.4, 4.10.6, 4.10.7 | Approved |
04/01/2006
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| PRR636 | Texas SET Version 2.1-Customer Registration | Updated and Added Sections to comply with Texas SET Version 2.1 changes to transaction and business processing. | 10/12/2005 | Tx SET | No | 15.1.2.1, 15.1.4.4, 15.1.4.5, 15.1.6, 15.1.9 (new) | Approved | |
| PRR637 | Texas SET Version 2.1- Retail Point to Point Communications | Modifications and Additions to support the Texas SET Version 2.1 Implementation. | 09/23/2005 | Tx SET | No | 24.1.1, 24.1.3.1, 24.2.1, 24.3, 24.3.3, 24.5, 24.5.2 | Approved | |
| PRR638 | Change Settlement Invoice Due Date from 16 Calendar Days to Five Business Days | Changes the Settlement Invoice Due Date from sixteen (16) calendar days to five (5) Business Days. NOTE: There is no change to Protocol Sections 9.4.1 (2) and 9.4.3; that is, ERCOT payments occur on the next Business Day following the QSE payment date. | 10/04/2005 | COPS | No | 9.3 | Approved |
04/01/2006
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| PRR639 | Notification of Repairs to EPS Meter Facilities Under Emergency Conditions | This revision would allow, in emergency situations, the TDSP to repair its EPS metering without first having to notify ERCOT. | 10/21/2005 | Meter Working Group | No | 10.8.1.2 | Approved | |
| PRR640 | Payments for RMR Service and Agreement for Synchronous Service | This PRR revises portions of Section 6 and the RMR Agreement to provide consistency between the two. Additionally, in the RMR Agreement, portions specific to synchronous condensers have been removed and a new Agreement (in Attachment J) created for Synchronous Condenser service. Attachment J is based on language in Attachment F. | 10/21/2005 | ERCOT | No | 6.8.3, 22F, 22J | Approved |
04/01/2006
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| PRR641 | Clarifying RPRS Scheduling Language | Section 6.4.2 (5) states that after a RPRS deployment, a QSE needs to adjust their BES bids based on the LSL and HSL of the deployed unit. Section 6.7.5 (2) states that after a RPRS deployment, a QSE needs to adjust their BES bids based on €¦ the full megawatt quantity of capacity accepted by, and purchased by, ERCOT in the Replacement Reserve markeâ€? This PRR would change the language of Section 6.7.5 (2) to match the language of Section 6.4.2 ( | 10/27/2005 | BP Energy Company | Yes | 6.7.5 | Approved | |
| PRR642 | Lower Limit to IDR Meters in MRE for True-Up Settlement IDR Threshold | Sets a lower limit to the number IDR meters within a Meter Reading Entity (MRE) that would be considered when determining whether the IDR threshold requirement is met or not for true-up settlement. | 11/10/2005 | COPS | No | Current Protocols: 9.2.6 Nodal Protocols: 9.5.8 | Approved |
04/01/2006
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| PRR643 | Shorten Payment Default Timelines | This PRR proposes to: 1) Reduce the number of days allowed to cure a breach before it becomes a Default under the LSE, QSE and TCR Agreements from 3 days to 2 days; and 2) Make collateral payments due by 3:00pm on the second day after notification rather than by 5:00 pm on that day. | 12/14/2005 | Credit Working Group | Yes | 16.2.8, 16.2.9, Sec 8 and 11 of 22B, 22C, and 22H Nodal Protocols: 16.11.5, 16.11.6, Sec 8 and 11 of Standard Form MP Agreement | Approved |
01/01/2006
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| PRR644 | Ancillary Service Re-qualification | Allows QSEs to re-qualify as provider(s) of Responsive Reserve Service, Balancing Energy Service, Regulation Service, and Non-Spinning Reserve Service based upon demonstrated historical performance in lieu of repeating the qualification test(s). | 11/14/2005 | ERCOT | Yes | 6.10.3 Nodal Protocols: 8.1.2.2.1 | Approved |
01/01/2006
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| PRR645 | Customer Information Repository | This PRR documents the responsibilities of Competitive Retailers to provide Customer information to the third party for maintaining the Customer Information Repository. (An RMGRR will be submitted to document the details of the process in Section 7, Market Processes of the Retail Market Guide (RMG) if this PRR is approved.) | 11/18/2005 | Mass Transition Task Force | No | 15.1.2.9 | Withdrawn | |
| PRR646 | Establish a Floor for Responsive Reserve Service Bids | Revise 4.4.11 so that all bids to provide Responsive Reserve Service (RRS), have bid prices equal to or greater than $0. | 11/29/2005 | Credit Working Group | Yes | 4.4.11 | Approved |
02/01/2006
|
| PRR647 | Gross and Net MW/Mvar Data Reporting | Adds a requirement for a QSE representing a Resource to supply both gross and net MW and Mvar data to ERCOT for use in the operations model. | 12/05/2005 | ERCOT | No | 6.5.1.1 | Approved | |
| PRR648 | Prevent IDR Removal from Customers Served at Transmission Voltage | This PRR introduces language to clarify that IDRs may not be removed from Premises served at transmission voltage. | 01/16/2006 | Profiling Working Group | No | 18.6.7 | Approved |
06/01/2006
|
| PRR649 | Correct "K" Factor in Compliance SCE Formula | This PRR revises the œ€? factor in the compliance formula from 0.81 to 1. | 02/22/2006 | American National Power, Inc. | Yes | 6.10.5.3 | Rejected | |
| PRR650 | Balancing Energy Price Adjustment Due to Non-Spinning Reserve Service Energy Deployment | Adjusts the Market Clearing Price of Energy (MCPE) when the deployment of Non-Spinning Reserve Service (NSRS) occurs to provide correct price signals via a post-deployment adjustment to separate the pricing solutions from the deployment on NSRS. This adjustment will still be subject to MCSM, if the Balancing Energy Service Up bids are depleted and no zonal congestion occurs, as detailed in Protocol Section 6.9.5.1(2). ERCOT will provide a notice to all market participants that highlights the interval beginning the NSRS deployment and another notice when NSRS deployment is being discontinued. The adjusted MCPE price signal would remove NSRS deployments and manually re-run SPD, sending accurate price signals in an energy-only market design. | 02/24/2006 | TXU Energy | No | 6.7.4, 6.8.1.12, 6.9.5.1 | Approved | |
| PRR651 | RPRS Cost Recovery Process Clarification | Clarify the process ERCOT shall use when making payments for cost recovery request associated with Replacement Reserve Service (RPRS) instructions. | 02/24/2006 | ERCOT | Yes | 6.8.1.11 | Approved |
05/01/2006
|
| PRR652 | Customer Information Repository | This PRR documents the responsibilities of Competitive Retailers to provide Customer information to ERCOT or a designated third party for maintaining the Customer Information Repository. (An RMGRR will be submitted to document the details of the process in Section 7, Market Processes of the Retail Market Guide (RMG) if this PRR is approved.) | 03/08/2006 | Mass Transition Task Force | No | 15.1.2.9, 15.1.2.10 (new) | Withdrawn | |
| PRR653 | OOME Ramp Rate Adherence | This PRR would allow QSEs to request Verbal Dispatch Instructions when being undeployed from OOME instructions that would exceed the QSEs ramp rate. | 03/09/2006 | Constellation | No | 6.5.10 | Approved | |
| PRR654 | Remove Market Solution References | This revision removes references to the term "Market Solution" within the Protocols. | 03/14/2006 | LCRA | No | 2.1, 4.5.11.1, 4.5.11.3, 6.1.9, 6.1.10, 6.1.11, 6.7.8, 6.8.1.11, 7.4.2, 7.6 | Approved | |
| PRR655 | Approval of Temporary Modification to Annual Validation | Allow approval to grant a temporary modification to the Annual Validation process by the Technical Advisory Committee (TAC). | 03/14/2006 | Profile Working Group | No | 18.4.3 Load Profile ID Assignment | Approved |
08/01/2006
|
| PRR656 | SCE Performance Charge | This creates an SCE Performance Charge to replace SCE Performance monitoring. | 03/15/2006 | Tenaska Power Services | No | 6.8.6, 6.9.9, 6.10.5.1-3, 6.10.5.6, 6.10.6 | Rejected | |
| PRR657 | Process for Protocol Revisions During the Transition to a Nodal Market | This PRR introduces a more streamlined procedure for processing revision requests relating the Nodal Protocols during the period prior to implementation of the Nodal market. This PRR shortens the comment period and limits the Impact Analysis requirements to only those revision requests that may affect a Requirements Document. The new procedure would be outlined in new Section 21.11, Process for Nodal Protocol Revisions During the Transition to a Nodal Market, and this process would only be applicable until the day of full implementation of the Texas Nodal market | 03/24/2006 | ERCOT | Yes | Section 21.1, Introduction, and Section 21.11, Process for Nodal Protocol Revisions during the Transition (New). | Approved |
05/16/2006
|
| PRR658 | Requirements for Entities Re-entering the ERCOT Market | This PRR proposes revisions to Section 16.1 and; creates a new Section 16.1.1, to establish requirements for Entities who wish to re-enter the ERCOT Market as a qualified Market Participant. | 03/31/2006 | Mass Transition Task Force | No | 16.1, 16.1.1 | Approved | |
| PRR659 | Reporting of ERCOT Replacement Reserve Service Procurements | This PRR requires reporting on the classification and amounts of ERCOT™s procured Replacement Reserve Service (RPRS), as well as a comparison of actual procurements of RPRS for system capacity to a theoretical amount of RPRS procurement for system capacity | 04/03/2006 | TXU Wholesale | Yes | 1.3.1.1, 6.10.11 | Approved | |
| PRR660 | Texas SET Transactional Solution for a Mass Transition Event | This PRR introduces a transactional solution for reducing mass transition timelines and documents the process for parties involved in a Mass Transition event. | 04/06/2006 | Texas SET | Yes | 15.1.2.9 | Approved | |
| PRR661 | SCE Performance Enforcement Criteria | This revision creates the criteria for SCE Performance Enforcement. | 04/07/2006 | PSEG Texgen I | Yes | 6.10.5.3, 6.10.12.1 (new) | Approved | |
| PRR662 | Modify Ancillary Service Deployment Performance Conditions | Clarifies current language exempting the intervals following a Forced Outage from the Schedule Control Error compliance measure and adds additional exemptions to address infeasible portfolio instructions, Responsive Reserve Service ramping, unit testing, and the scheduling of Uncontrollable Renewable Resources. | 04/10/2006 | WMS Frequency TF | Yes | 6.10.6 | Approved | |
| PRR663 | Payment When a Resource Receives an OOME Down to Zero (0) MW Dispatch Instruction | Conforms OOME down to zero Dispatch Instruction cost recovery process to that used for OOMC (e.g. verifiable costs). | 04/18/2006 | American National Power, Inc. | No | 6.8.2.6 | Approved |
10/01/2006
|
| PRR664 | Revise Non-Spinning Reserve Services Performance Monitoring Criteria | Revise the Non-Spinning Reserve Service (NSRS) Performance Monitoring Criteria. | 04/21/2006 | PDCWG | No | 6.10.5.5, Non-Spinning Reserve Services Performance Monitoring Criteria; 6.10.3, Ancillary Services Qualification Criteria and Portfolio Test Methods | Approved | |
| PRR665 | Revise Responsive Reserve Service Performance Monitoring Criteria | Correct the Schedule Control Error (SCE) to reflect Loads acting as Resource (LaaR) obligation when it is deployed. Revise the Responsive Reserve Service (RRS) Performance Monitoring Criteria to accurately reflect compliant performance by Qualified Scheduling Entities (QSEs). Moved language regarding LaaRs and bids from Combined Cycle plants from Section 6.10.5.4 to Section 6.5.4 since this is a more appropriate place for this language. Revised Section 6.10.3 to update Ancillary Service (AS) Re-Qualification language to reflect new criteria. | 04/21/2006 | PDCWG | No | 6.10.4.4, Schedule Control Error; 6.10.5.4, Responsive Reserve Services Performance Monitoring Criteria; 6.5.4, Responsive Reserve Service; 6.10.3, Ancillary Services Qualification Criteria and Portfolio Test Methods | Approved | |
| PRR666 | Modification of RPRS Under-Scheduled Capacity Charge Calculation | The PRR revises Section 6.9.2.1.1, Replacement Reserve Under Scheduled Capacity, to charge QSE™s for ERCOT-wide RPRS based on their net ERCOT-wide position. A clarification is also included for Section 4.7.2(2) which refers to sections of the Protocols that use the Schedule Mismatch amount | 05/22/2006 | Reliant Energy | Yes | 4.7.2 (2), 6.9.2.1.1 | Approved | |
| PRR667 | RPRS Uplift Charge and Under Scheduled Charge Correction | This PRR will correct an over collection and inequitable negative uplift charge, aligning RPRS payments with RPRS procurement costs. | 05/22/2006 | Constellation Energy | Yes | 6.6.3.2.1, Specific Procurement Process Requirements for Replacement Reserve Service in the Adjustment Period; 6.9.2.1, Settlement for RPRS | Rejected | |
| PRR668 | Distribution Loss Factor Calculations | Modify the Settlement Interval Distribution Loss Factor (SILF) to better represent the non-linear relationship between the loss factor and Settlement Interval ERCOT System Load (SIEL). | 05/24/2006 | Unaccounted For Energy Task Force (UFETF) | No | 13.3 | Approved | |
| PRR669 | Timing of Calculation of RPRS Under Scheduled Charges | This PRR revises the timing of schedules that ERCOT uses for determining the quantity of under scheduled energy from 1300 to 1600 in the day ahead period. The PRR also revises the timing of the load forecast that ERCOT uses from 1100 to 1600. | 05/24/2006 | Fulcrum Power | Yes | 4.4.17, 6.9.2.1.1 | Approved |
08/01/2006
|
| PRR670 | First Available Switch Date (FASD) for Switch Requests | This PRR introduces revisions to Section 15, Customer Registration. Specifically this PRR: Adds language to reflect the First Available Switch Date (FASD) for a Switch Request in situations where: · Customer notification is required; · Customer notification has been waived; or · Drop to AREP request Statements were removed that are no longer accurate based upon current business and system processes. Relocated some of the existing language to make the document flow easier to understand for the reader. | 05/31/2006 | Kathy Scott on behalf of TX SET | Yes | 15, Customer Registration | Approved | |
| PRR671 | Remove Sunset Date on Floor for Responsive Reserve Service Bids | Revise 4.4.11 to remove sunset date of January 1, 2007. | 06/15/2006 | Demand Side Working Group | No | 4.4.11 Ancillary Services Bid Submittal | Approved | |
| PRR672 | Retail Market Timing Necessary for PUCT Project 29637 | Revise the transaction timings in Section 15 for retail processes in order to comply with PUCT Project 29637 and Mass Customer Transition Requirements. Create a new defined term in Section 15, œRetail Business Hou€?. | 06/19/2006 | Retail Market Subcommittee | Yes | 15 | Approved | |
| PRR673 | Adjust SCE Performance Charge Scale Factor | The Scale Factor value in the SCE Performance Charge calculation is currently fixed at 1. This PRR would modify the Scale Factor monthly based on ERCOT™s CPS_1 score. This PRR also sets maximum and minimum values for the Scale Factor | 07/14/2006 | Frequency Control Task Force | No | 6.10.12.1 SCE Performance Charge | Approved | |
| PRR674 | Temporary Alteration of Settlement Equations Related to the RPRS Under Scheduled Charge | This PRR temporarily alters the settlement equations for the RPRS Under Scheduled charge. | 07/19/2006 | Constellation NewEnergy | Yes | 6.9.2.1.1, 6.9.2.1.2 | Approved | |
| PRR675 | Multiple Ramp Rates | Revises Sections 4.5.2 and 6.5.2 to allow QSEs to submit a ramp rate curve to ERCOT that would be used to calculate an equivalent ramp rate for clearing the balancing energy market. | 07/21/2006 | Coral Power, LLC | No | 4.5.2 Receipt of QSE's Balancing Energy Bid Curves; 6.5.2 Balancing Energy Service | Approved | |
| PRR676 | RPRS Solution with Nodal RUC-Type Procurement and Cost Allocation | This PRR modifies the current day ahead capacity procurement and cost allocation methods to be consistent with the procurement and cost allocation methods for the Reliability Unit Commitment that is contained in the Nodal Protocols as approved by the PUCT. The PRR also removes the provisions related to the direct assignment of zonal capacity procurements. | 07/25/2006 | CPS Energy | Yes | 4.1.1 Day Ahead Scheduling Process; 4.1.2 Adjustment Period Scheduling Process; 4.4.16 ERCOT Receipt of Replacement Reserve Service Bids; 4.4.17 ERCOT Procurement of Replacement Reserve Service As Needed; 4.5.6 ERCOT Notice of Need to Procure Replacement Reserve Service Resources; 4.5.7 Available Bids for RPRS; 6.4.2 Determination of ERCOT Control Area Requirements; 6.5.6 Replacement Reserve Service; 6.6.3.2.1 Specific Procurement Process Requirements for Replacement Reserve Service in the Adjustment Period 6.8.1.1; Payments for Ancillary Service Capacity; 6.8.1.10 Zonal or System Wide Replacement Reserve Service Capacity Payment to QSE.; 6.8.1.11 Local Congestion Replacement Reserve Payment to QSE When Market Solution Exists; 6.8.2.2 Capacity and Minimum Energy Payments; 6.9.2.1 Settlement for RPRS Procured for System-wide Capacity Insufficiency; 6.9.2.1.1 Replacement Reserve Under Scheduled Capacity; 6.9.2.1.2 Replacement Reserve Uplift Charge; 6.9.7 Settlement Obligations for Premiums for Individual resource Dispatch Payments; 6.9.7.1 OOM Capacity Charge; 7.1 Overview of ERCOT Congestion Management ;7.3.4.2 Replacement Reserve Service Zonal Congestion Charge; 7.4.2 Resolution of Local Congestion | Approved | |
| PRR677 | Substitute Source For Fuel Index Price (FIP) | This PRR establishes that, in the event the periodical noted fails to publish a daily FIP, the ERCOT Board of Directors will direct ERCOT Settlements on the use of an alternative index. | 07/26/2006 | Transition Plan Task Force (TPTF) | No | 2 | Approved |
01/01/2007
|
| PRR678 | Allocation of RPRS Over-Collection to QSEs | This PRR allocates any over-collection of funds caused by ERCOT deployment of RPRS to QSEs that are scheduling the excess capacity that offset the requirement for RPRS. | 07/28/2006 | TXU Wholesale | Yes | 6.8.1.16 – Settlement of NSRS Over-Collection (New); 6.9.2.1.2 – Replacement Reserve Uplift Charge | Withdrawn | |
| PRR679 | Revision to NLRI Formula and Other Credit Requirements | Several changes are proposed, with the three primary changes being: (1) Change the formula for Net Load Imbalance Liability and Net Resource Imbalance Liability (NLRI) to better match with Nodal formula “ perform calculation on a more detailed level using entity specific pricing rather than WA_MCPE pricing (2) Require/allow ERCOT to withhold payment from entities that have exceeded their EAL or NLRI. (3) Address request by RMS/Texas Set to add requirement that QSEs (that are LSEs) and are in Payment Default to provide ESID information on their customers | 08/01/2006 | Credit Working Group | No | 16.2.7.4, 16.2.8, 16.2.9, 16.2.9.1, 16.2.9.1.1, 16.2.9.1.2, 6.2.9.1.3, 16.2.9.1.4, | Approved |
02/01/2007
|
| PRR680 | Procurement of Capacity for Load Forecast Uncertainty | ERCOT presently procures an 1800 MW Mulligan and RPRS using the same process. This revision separates out the load forecast uncertainty procurement process from the RPRS procurement. Capacity for Load Forecast Uncertainty is procured from the Ancillary Services markets. | 08/02/2006 | PSEG Texgen I | Yes | 5.6.5 Alert | Rejected | |
| PRR681 | Discontinuation of Interest Charge for Defaulting Entities at Time of Uplift | This PRR allows ERCOT to cease the calculation of interest (Late Fees) for defaulting entities when the conditions initiating uplift are met. Late Fee calculations will continue for Short paying entities until uplift conditions are met. | 08/10/2006 | LCRA | No | 9.4.4, 9.4.6 | Approved |
01/01/2007
|
| PRR682 | Emergency Electric Curtailment Plan (EECP) Event Realignment | These revisions conform the Protocols with revisions to the Operating Guide proposed in OGRR186, Emergency Electric Event Curtailment Plan (EECP) Event Realignment, to set forth the necessary sequence for ERCOT to process EECP related items, thereby allowing ERCOT to be more proactive in communicating system conditions during certain events. | 08/14/2006 | Reliability Operations Subcommittee (ROS) | Yes | 5.6.6.1, 5.6.7, 6.10.3.2 | Approved |
12/01/2006
|
| PRR683 | Reduce Timeline for Notice and Cure and Create a Working Credit Limit | “ Reduces time to post collateral from two Bank Business Days to one - Creates a working credit limit which allows an entity to utilize up to 85% of posted collateral + unsecured credit limit (rather than 100 | 08/16/2006 | Credit WG | No | 22 Attachments B, C and H; 16.2.8, 16.2.9 | Rejected | |
| PRR684 | Mass Transition Process Necessary for PUCT Rule 31416 | This Protocol Revision Request (PRR) introduces revisions to Section 15.1.2.9, Mass Transition and adds a new Section 15.1.2.9.1, Customer Billing Contact Information to comply with the PUCT rulemaking for Project 31416. (An RMGRR will be submitted to document the details of the process in Section 7, Market Processes of the Retail Market Guide (RMG). | 08/16/2006 | No | 2. 1, Definitions 15.1.2.9, Mass Transition 15.1.2.9.1, Customer Billing Contact Information (New) | Approved | ||
| PRR685 | TCRs and PCRs Payment Due Date | This PRR documents the requirements for both Transmission Congestion Rights (TCRs) and Pre-assigned Congestion Rights (PCRs) payment period due date to three (3) Bank Business Days after being invoiced. | 08/21/2006 | Roy McCoy on behalf of ERCOT staff | Yes | 7.5.3.2.2.(5), Auction | Approved | |
| PRR686 | Black Start Testing Requirements | Specifies the requirements for starting the next start Resource; Specifies which tests are allowed to be run simultaneously. | 08/23/2006 | Black Start Task Force | No | 6.10.3.6 | Approved |
02/01/2007
|
| PRR687 | Replacement Reserve Under-Scheduled Capacity Delineation | This PRR corrects discrepancies in the Replacement Reserve Under-Scheduled Capacity charge equation. | 08/24/2006 | ERCOT | Yes | 6.9.2.1 | Approved | |
| PRR688 | ERCOT Nodal Implementation Surcharge | This PRR documents how ERCOT shall calculate the Nodal Implementation Surcharge (NIS) to comply with the Final Order issued in Public Utility Commission of Texas (PUCT) Docket No. 32686, Application of the Electric Reliability Council of Texas for Approval of a Nodal Market Implementation Surcharge and Request for Interim Relief, to fund implementation of the nodal market redesign. | 08/28/2006 | ERCOT Staff | Yes | 9.7.7 | Approved |
10/01/2006
|
| PRR689 | Down Balance Qualification for Renewable Resources | Modifies the Balancing Down Energy Service qualification for QSEs representing only Uncontrollable Renewable Resources to at or below the deployment level requested by ERCOT. | 08/28/2006 | Florida Power & Light | No | 6.10.3.4 Balancing Energy | Approved |
01/01/2007
|
| PRR690 | Termination of the Modified Competitive Solution Method | Consistent with the Commission™s Substantive Rules, this proposed revision eliminates the references to the MCSM | 08/28/2006 | Suez Energy Marketing | Yes | 6.5.2, Balancing Energy Service; 6.9.5.1, Balancing Energy Clearing Price | Approved | |
| PRR691 | Nodal Implementation Surcharge Verifiable Costs | This PRR adds nodal implementation surcharges as a verifiable cost for resources called on for reliability purposes. The changes proposed in this PRR are contingent on the passage of PRR688, ERCOT Nodal Implementation Surcharge. | 09/14/2006 | NRG Texas | No | 6.8.1.11, 6.8.2.2, 6.8.2.3, 6.8.3.1 | Approved |
05/01/2007
|
| PRR692 | Corrections to Replacement Reserve Service | Removes costs related to capacity procured for system security from the costs that are solely assigned to under-scheduled Qualified Scheduling Entities (œQS€?), provides incentives for more accurate resource plans and eliminates the RPRS over-collection by compensating QSEs representing unscheduled resource | 09/19/2006 | Constellation New Energy | No | 2.1, Definitions; 2.2, Acronyms; 4.4.16, ERCOT Receipt of Replacement Reserve Service Bids; 6.4.2, Determination of ERCOT Control Area Requirements; 6.5.6, Replacement Reserve Service; 6.8.1.11, Local Congestion Replacement Reserve Payment to QSE; 6.9.2.1.1, Replacement Reserve Under Scheduled Capacity; 6.9.2.1.2, Replacement Reserve Uplift Charge | Rejected | |
| PRR693 | Update Transactions for Texas SET 3.0 Implementation and Timing for Processing Priority/Standard Move- In Transactions | This PRR: Revises the transaction timings in Section 15.1.3.1, Move-In Request to Begin Electric Service and Section 15.1.3.4, Notification to TDSP of Move-In to reflect the language approved by the ERCOT Board with PRR672 for the TX SET 3.0 implementation as it relates to priority move-in transactions and clarified requirements for standard move-ins. Renames the TX SET transactions for 814_11, 814_14 and 814_15 due to new functionality introduced by TX SET with the long term solution for Mass Transition (see RMGRR042). Revises language as it relates to transaction functionality and brings all processes for each transaction current with TX SET version 3.0 implementation. Reformats and corrects terminology throughout Sections 15, 19 and 24. | 09/22/2006 | Kathy Scott and Rob Bevill on behalf of Texas SET | No | Section 15, Customer Registration Section 19, Texas Standard Electric Transaction Section 24, Retail Point to Point Communication | Approved | |
| PRR694 | Modification of Certain Board Approvals | In keeping with the activities of the TAC Board Action Items Subgroup addressing this issue, TAC resolution and the Board™s discussion, the PRR proposes refinements as set forth in the TAC resolution of June 1, 2006. | 09/25/2006 | TAC Board Action Items Subgroup | No | 10.14.1, 18.2, 18.2.2, 18.2.9, 21.4.6, 21.4.7, 21.4.8, 21.8.6, 21.8.7, 21.8.8, 21.9 | Approved |
04/01/2007
|
| PRR695 | Unaccounted For Energy (UFE) Analysis | This PRR eliminates outdated sections pertaining to UFE analysis and provides a more meaningful approach to annual UFE analysis reporting. | 10/11/2006 | UFE Task Force | No | 11.6, 11.6.1, 11.6.2, 11.6.2, 11.6.3 | Approved |
03/01/2007
|
| PRR696 | MAPE Publication | This PRR would amend current Protocols to include the measure of forecast error (i.e., ERCOT™s Mean Absolute Percent Error, or MAPE). Current protocols require ERCOT to provide a load forecast and the actual load. This PRR would isolate the forecast for the Day Ahead market at 1600 hours and at midnight. Additionally, the PRR would require ERCOT to post and maintain an up-to-date historical series for the monthly average MAPE data. Lastly, this PRR would require ERCOT to segregate the weather forecast error from the overall load forecast error | 10/17/2006 | Deutsche Bank | No | 4.2, Scheduling-Related Duties of ERCOT | Withdrawn | |
| PRR697 | Posting Requirement Changes | This PRR incorporates changes resulting from P.U.C. Subst. R. 25.502, Pricing Safeguards in Markets Operated by the Electric Reliability of Texas Power Region and new P.U.C. Subst. R. 25.505, Resource Adequacy in the Electric Reliability of Texas Power Region, adopted under P.U.C. Project No. 31972, Rulemaking Concerning Resource Adequacy and Market Power in the Electric Reliability Council of Texas Power Region. | 10/20/2006 | ERCOT | No | 1.3.1.1, Items Considered Protected Information; 1.3.1.2, Items Not Considered Protected Information; 1.3.3, Expiration of Confidentiality; 8.7, Analysis of Resource Adequacy (deleted); 12.3.5, Analysis of Resource Adequacy (new); 12.4.2, Ancillary Service -Related Information; 12.4.4.2.3.2, Public ERCOT Posting; 12.4.4.2.3.3, Public Posting of Standard QSE-Specific Market Reports | Approved |
05/01/2007
|
| PRR698 | Remove Default QSE Provisions | This PRR revises provisions for the Emergency and Virtual Qualified Scheduling Entity (QSE) to allow them to provide for Resource Entities and Load Serving Entities (LSEs) in the event that their QSE defaults. This PRR also removes the Default QSE concept, including all references to a Default QSE. | 11/07/2006 | ERCOT Staff | Yes | 2.1, 16.2.1, 16.2.8, 16.2.9.1.4, 16.2.12, 16.2.12.1, 16.2.12.2, 16.2.12.3, 16.2.13.1, 16.2.13.2, 16.2.13.3 | Approved |
01/01/2007
|
| PRR699 | Removal of the Northeast Congestion Zone in Trading Hub Transaction Conversions | This PRR Synchronizes the ERCOT Protocols to reflect the removal of the Northeast Congestion Zone in the Trading Hub calculations beginning January 1, 2007. As such, reference to the Northeast Congestion Zone in the Protocols is removed, and the calculation for converting transactions at Trading Hubs to existing Congestion Zones is revised. In addition, the calculation is adjusted to account for the fact that a transmission bus that was previously in the West Congestion Zone will be in the North Congestion Zone in 2007 (bus number 6096). | 11/13/2006 | ERCOT | Yes | 7.9.2.6, ERCOT Bus Average 345 kV Trading Hub; 7.9.3.4, Scheduling of Transactions Using ERCOT Trading Hubs | Approved |
01/01/2007
|
| PRR700 | Creation of Interim Measure for Collecting the ERO/TRE Fee | Revise the ERCOT System administration fees to include the FERC-mandated fee for the ERCOT Region™s share of the new Electric Reliability Organization (ERO) and the new Texas Regional Entity (TRE) for the ERCOT Region. The ERO/TRE fee will be $0.0169 per MWh. FERC approved a ERO/TRE budget for the ERCOT Region which results in a fee of $0.021 per MWh; however, a portion ($900, 000) of the ERO/TRE fee will be collected via the PUCT-approved ERCOT System administration fee of $0.4171 per MWh. | 11/15/2006 | ERCOT Staff | Yes | 2.1, 9.7.1 | Approved |
01/01/2007
|
| PRR701 | Enabling of Stranded Capacity During Alerts | This Protocol Revision Request will provide ERCOT with a tool that will enable incremental online capacity upon ERCOT issuing an Alert due to a capacity short supply situation. This Protocol change will also allow QSEs to represent their previously stranded capacity as available and capable of being loaded to their full real-time capability during an Alert due to a capacity short supply situation. | 11/20/2006 | PSEG Texgen I | Yes | 5.6.5, 5.6.6, 5.6.7.1, 5.6.8 | Approved | |
| PRR702 | Emergency Interruptible Load Service | Modify the Zonal Protocols to allow for the use of an Emergency Interruptible Load Service (EILS) when an Emergency Electric Curtailment Plan (EECP) is declared and all available Generation and Loads acting as Resources (LaaR) have been deployed. | 12/19/2006 | Eagle Energy Partners, Enernoc, and Occidental Chemical Corporation | Yes | Section 2, Definitions and Acronyms; Section 4, Scheduling; Section 5, Dispatch; Section 6, Ancillary Services; Section 9, Settlements; Section 12, Market Information System; and Section 16, Registration | Rejected | |
| PRR703 | Emergency Interruptible Load Service (EILS) | This PRR changes the Protocols Sections noted above and institutes an Emergency Interruptible Load Service (EILS) as a load interruption emergency backstop for use only during Emergency Electric Curtailment Plan (EECP) Step 3. EILS would be a merit order of loads that have voluntarily offered to interrupt at an offer price and would be dispatched to interrupt in the EECP step just prior to the Independent System Operator™s (ISO) dispatch order to Transmission and Distribution Service Provider/Distribution Service Providers (TDSP/DSPs) to shed firm load in order to preserve the syste€™s frequenc | 12/28/2006 | Emergency Interruptible Load Task Force | Yes | Section 2, Definitions and Acronyms; Section 4.1.1, Day Ahead Scheduling Process; Section 4.1.3, Month Ahead Scheduling Process (New); Section 4.4.8, Submittal of Day Ahead Schedules and Ancillary Services Schedules; Section 4.11, Month Ahead Scheduling Process (New); Section 5.6.7, EECP Steps; Section 5.6.8, Emergency Compensation; Section 5.8.3.1, Data Collection; Section 6.1.13, Emergency Interruptible Load Service (EILS) (New); Section 6.2.1, Ancillary Services Solely by ERCOT; Section 6.5.1.1, Requirement for Operating Period Data for System Reliability and Ancillary Service Provision; Section 6.5.12, Emergency Interruptible Load Service (EILS) (New); Section 6.6.2, Competitive Procurement of Ancillary Service Resources by ERCOT; Section 6.7.9, Deployment and Recall of EILS (New); Section 6.10.2, General Capacity Testing Requirements; Section 6.11, (Emergency Interruptible Load Service Qualification, Testing and Performance Standards (New); Section 12.4.2, Ancillary Service – Related Information; and Section 16.2, Registration of Generation Resources and Loads Acting as a Resource. | Rejected | |
| PRR704 | Emergency Interruptible Load Service (EILS) | This PRR changes the Zonal Protocols sections noted above and upon approval institutes an Emergency Interruptible Load Service (EILS) as a load interruption emergency backstop during Emergency Electric Curtialment Plan (EECP) Step 3. EILS would provide ERCOT with a pool of loads that have voluntarily offered to interrupt at an offer price and would be dispatched to interrupt in the EECP step just prior to the Independent System Operator™s (ISO) dispatch order to Transmission and Distribution Service Provider/Distribution Service Providers (TDSP/DSPs) to shed firm load in order to preserve the syste€™s frequency. | 01/10/2007 | Chaparral Steel and Nucor Steel | Yes | Section 2, Definitions and Acronyms; Section 4.1.3, Month Ahead Scheduling Process (New); Section 4.2, Scheduling-Related Duties of ERCOT Section; 4.8, Temporary Deviations from Scheduling Procedures; Section 4.11, Month Ahead Scheduling Process (New); Section 5.6.7, EECP STEPS; Section 5.6.7.1, Restoration of Market Operations; Section 6.1.13, Emergency Interruptible Load Service (New); Section 6.2.2, Ancillary Services Provided in Part by ERCOT and in part by Qualified Scheduling Entities; Section 6.3.1, ERCOT Responsibilities; Section 6.4.2 Determination of ERCOT Control Area Requirements; Section 6.5, Technical Requirements for Providers of Ancillary Services; Section 6.5.1.1, Requirement for Operating Period Data for System Reliability and Ancillary Service Provision; Section 6.5.1.2, Requirement for Operating Period Data for Emergency Interruptible Load Service Provision (New); Section 6.5.12, Emergency Interruptible Load Service (New); Section 6.6.1, Qualified Scheduling Entity Rights and Obligations to Self-Arrange Ancillary Service Resources; Section 6.6.2, Competitive Procurement of Ancillary Service Resources by ERCOT; Section 6.6.8, ERCOT Month-Ahead Ancillary Service Procurement Process (New); Section 6.8.6, Capacity Payments for Emergency Interruptible Load Service (New); Section 6.8.6.1, Payments for Emergency Interruptible Load Service Capacity (New); Section 6.8.6.2, Emergency Interruptible Load Service Payment to QSE (New); Section 6.9.9, Settlement for ERCOT Emergency Interruptible Load Service Procured for the Operating Month (New); Section 6.9.9.1, Emergency Interruptible Load Service Charge (New); Section 6.10.2, General Capacity Testing Requirements; Section 6.11, Emergency Interruptible Load Service Qualification, Testing and Performance Standards (New); Section 9.2.2, Settlement Statement Data; Section 16, Registration and Qualification of Market Participants; Section 16.5, Registration of Generation Resources, Loads Acting as a Resource, and Emergency Interruptible Load Resources | Rejected | |
| PRR705 | Emergency Interruptible Load Service (EILS) - Interim Option | This PRR would modify the ERCOT Protocols to allow for the use of an Emergency Interruptible Load Service (EILS) when an EECP is declared and all available Generation and Loads acting as Resources (LaaRs) have been deployed. | 01/10/2007 | ERCOT Staff | Yes | Section 2, Definitions and Acronyms; Section 5.6.7, EECP STEPS; Section 5.9.3, ERCOT Data Collection; Section 6.1.13, Emergency Interruptible Load Service (New); Section 6.2, Providers of Ancillary Services; Section 6.5, Technical Requirements for Providers of Ancillary Services; Section 6.5.12, Emergency Interruptible Load Service (New); Section 6.7.9, Deployment of Emergency Interruptible Load Service (New); Section 6.8.6, Capacity Payments for Emergency Interruptible Load (New); Section 6.9.4, Settlement Obligation for Black Start Service, RMR Standby Service, and Synchronous Condenser Service; Section 6.10.2, General Capacity Testing Requirements; Section 6.10.13, Emergency Interruptible Load Service Qualification, Testing and Performance Standards (New); Section 16.5, Registration of Generation Resources and Loads acting as Resources; Section 22 -- Attachment K, Standard Form Emergency Interruptible Load Service Agreement (New) | Approved |
04/19/2007
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| PRR706 | Provisional Qualification for Ancillary Services | Provide for a provisional qualification time period for the provision of Ancillary Services (AS) and discontinue the practice of œborrowin€? units for AS qualificatio | 01/10/2007 | Bryan Texas Utilities | No | 6.10.3, Ancillary Services Qualification Criteria and Portfolio Test Methods Normal | Approved |
06/01/2007
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| PRR707 | Prioritization and Timing of Transactions Based Upon PRR672 Collaborative Analysis and Retry Process for 814_20s. | This PRR proposes the following revisions which are recommended by ERCOT: 1) Add paragraph to outline the prioritization of transactions at ERCOT. 2) Revise transaction timings for Off-Cycle Switches and Off-Cycle Drops to AREP. a) Off-Cycle Switches should be added to Level 4 Transactions to be processed within one (1) Retail Business Day. b) Off-Cycle Drops to AREP should be added to the Level 4 Transactions to be processed within one (1) Retail Business Day. 3) Add language in Section 15.4.1.4 for New ESI ID Creation that explains a retry process for 814_20s. | 01/18/2007 | Karen Farley on behalf of ERCOT | No | 15, Customer Registration 15.1.1.4, Switch Registration Notification Request to TDSP 15.1.1.6, Response to Valid Switch Request 15.1.1.10, Rejection of Switch Request 15.1.2.2, Response to Drop to Affiliate Retail Electric Provider Request 15.1.2.4, Notification to TDSP of Drop to Affiliate Retail Electric Provider 15.4.1.4, New ESI ID Creation | Approved | |
| PRR708 | Data Provided by ERCOT to TDSPs | The proposed protocol revision requires ERCOT to provide adjusted interval meter data for load and generation to a TDSP involved in system planning and operation activities. Any information provided pursuant to this revised provision will retain its protected status pursuant to Section 1.3, Confidentiality, of the Protocols, and will be subject to all applicable codes of conduct, including the PUCT code of conduct restricting the internal sharing of transmission information by employees of the TDSP. | 01/29/2007 | AEP | No | 12.4.4.1.2 | Approved | |
| PRR709 | Scarcity Pricing Mechanism | This PRR revises the ERCOT Protocols to provide for a scarcity pricing mechanism as required by subsection (g) of P.U.C. Subst. R. 25.505, Resource Adequacy in the Electric Reliability Council of Texas Power Region. ERCOT is already performing the calculations and postings required by this rule. This PRR synchronizes the Protocols with this rule. | 01/31/2007 | ERCOT Staff | No | Section 4.4.11, Ancillary Services Bid Submittal; Section 4.4.16, ERCOT Receipt of Replacement Reserve Service Bids; Section 6.5.2, Balancing Energy Service; and Sections 6.11, System-Wide Offer Caps (New). | Approved |
07/01/2007
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| PRR710 | Validation Tests Update | This PRR removes the requirement to post exception reports from the Load Profile Type and Weather Zone validation tests to the ERCOT MIS. | 01/31/2007 | Profiling Working Group | No | 18.4.4.1 | Approved |
07/01/2007
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| PRR711 | Update of ERCOT Protocols to Comply with NERC Name Change | This Protocol Revision Request (PRR) updates ERCOT Protocol References to reflect the recent NERC name change from North American Electric Reliability Council to North American Electric Reliability Corporation. | 02/12/2007 | ERCOT | No | 2.1, 2.2, 4.4.18.2, 5.1.2, 5.2, 5.6.1, 6.1 | Approved |
07/01/2007
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| PRR712 | Local Congestion Replacement Reserve Payment Methodology | This PRR modifies the Local Congestion Replacement Reserve Service (RPRS) payment methodology to be identical to that of the Out-of-Merit Capacity (OOMC) payment methodology, as described in Section 6.8.2 .2, Capacity and Minimum Energy Payments. This PRR also includes a "Max" function in the equation of startup payments in case there is a delay in the implementation of PRR676, RPRS Solution with Nodal RUC-Type Procurement and Cost Allocation. | 02/19/2007 | WMS | No | 6.6.3.2.1, Specific Procurement Process Requirements for Replacement Reserve Service in the Adjustment Period; 6.8.1.11, Local Congestion Replacement Reserve Payment to QSE; 6.8.2.2, Capacity and Minimum Energy Payments | Withdrawn | |
| PRR713 | Resource Outage Notification | This PRR clarifies and further details the long-term outage notification submission process for resources. | 02/21/2007 | ERCOT Staff | No | 6.5.9, Reliability Must-Run Service; 6.5.9.1, Initiation and Approval of RMR Agreements; 6.5.9.3, Mothballed Generation Resource Time to Service Updates; 8.4, Acceptance of Proposed Planned Outages of Resources other than Reliability Resources; Section 22, Attachment I: Notification of Suspension of Operations; Section 22, Attachment F: Standard Form Reliability Must-Run Agreement; Section 22, Attachment K: Notification of Change of Generation Resource Designation (New) | Approved |
10/01/2007
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| PRR714 | Qualification and Periodic Testing of Loads acting as Resources (LaaRs) | This revision request tightens the requirements for initial qualification; introduces periodic testing requirements; and provides for more clearly defined conditions that would disqualify a Load acting as Resource (LaaR) for under/non-performance. | 03/06/2007 | Damand Side Working Group | No | 6.10.2, General Capacity Testing Requirements; and 6.10.12, Non-Compliance Actions of ERCOT | Approved | |
| PRR715 | Simplifying the Dispute Process | This Protocol Revision Request (PRR) removes the concept of œlat€? disputes that can still be worked by ERCOT, and removes the concept of disputing settlement statements. Instead, disputes that are filed with enough time for ERCOT to work them, as defined in the Protocols modified by this revision, will be worked and included in the next settlement statement if grante | 03/27/2007 | Settlements and Data Aggregation Working Group (SDAWG) | No | 6.8.2.6, 9.1.2, 9.2.5, 9.5, 9.5.2, 9.5.3, 9.5.4, 9.5.4.1 (new), 9.5.4.2 (new) | Withdrawn | |
| PRR716 | NOIE Self-Provision of Emergency Interruptible Load Service | This PRR proposes the following revisions: · Section 2.1: The addition of a Definition for EILS Self-Provision by NOIEs · Section 6.5.12(3): The addition of steps to allow for NOIE Self-Provision and at the same time inform ERCOT of how much EILS it needs to purchase in order to reach its desired goal.. · Section 6.5.12(7)(e): Stating that EILS Self-Provision does not require a MW price. · Section 6.5.12(7)(i): Requiring NOIEs to inform ERCOT of the Maximum amount of EILS Self-Provision they are willing to provide. · Section 6.5.12(7)(j): Allowing NOIEs the option of bidding into the EILS program in the same manner as other loads. · Section 6.5.12(8): Requiring ERCOT to reduce its EILS Budget by the amount of EILS that is Self-Provided. · Section 6.5.12(13): Stating that EILS Self-Provision does not involve payment by ERCOT to NOIEs. · Section 6.8.6: Adding a calculation and description for summing the total MW of capacity purchased by ERCOT for the purposes of EILS. This number does not include EILS capacity that is secured through self-provision. · Section 6.9.4: Adding EILS to Settlement Obligations. · Section 6.9.4.4(1): Description and changes to the settlement calculations to accommodate NOIE Self-Provision. Section 6.10.13.3(4)(g) and 6.10.13.4(1): Describing the way a NOIE Self-Providing EILS is treated if it fails to perform. | 04/11/2007 | CPS Energy | Pending | 2, Definitions and Acronyms; 6.5.12, Emergency Interruptible Load Service; 6.8.6, Capacity Payments for Emergency Interruptible Load; 6.9.4.4, Settlement Obligation for Emergency Interruptible Load Service; 6.10.13, Emergency Interruptible Load Service Qualification, Testing and Performance Standards; 6.10.13.3, Performance Criteria for EILS Resources; and 6.10.13.4, Revocation of Qualification of EILS Resources and/or their QSEs | Approved | |
| PRR717 | EILS Disputes and Resettlements | This PRR adds a definition for EILS Contract Period to Section 2.1; revises Section 6.5.12 to reflect the addition of the definition; adds new Section 9.5.5 to describe a process for disputing and resettling the EILS Service; and renumbers former Section 9.5.5 to Section 9.5.6. | 04/13/2007 | Constellation NewEnergy | No | 2.1: Definitions; 6.5.12, Emergency Interruptible Load Service (EILS); 9.5.5, Resettlement of Emergency Interruptible Load Service (NEW); and 9.5.5, Disputes for Operational Decisions or Market Rules (RENUMBERED) | Approved |
01/01/2008
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| PRR718 | Authority for Determination of Urgency for a SCR | This PRR replaces "PRS" with the "Assigned TAC Subcommittee" as the proper entity to grant a request for Urgent status for a SCR in Section 21.8.11 and revises the requirements for Urgent status designation to mirror those for a Protocol Revision Requests (PRR). | 04/16/2007 | ERCOT Staff | No | 21.8.11 | Approved |
09/01/2007
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| PRR719 | Texas Regional Entity/NERC/FERC Penalties or Assessments | As an ISO, ERCOT is subject to the risk of monetary and/or non-monetary penalties assessed by the Federal Energy Regulatory Commission (FERC) and/or by North American Electric Reliability Corporation (NERC) or any regional entity to which NERC may delegate enforcement authority, in accordance with FERC Order Nos. 672 and 672-A1 for violations of mandatory Reliability Standards. This Protocol Revision Request (PRR) allows for recovery of the costs of paying or complying with any such penalties. | 04/16/2007 | ERCOT | No | 2.1, 2.2, 9.7.9 (new), 9.7.9.1 (new), 9.7.9.2 (new) | Withdrawn | |
| PRR720 | Texas Regional Entity Fee Methodology Revision | This Protocol Revision Request (PRR) changes how ERCOT will issue invoices to collect the Texas Regional Entity Fee (TREF). | 05/01/2007 | ERCOT | No | Section 2.1, 2.2, 9.7.1, and 9.7.8 (new) | Approved |
01/01/2009
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| PRR721 | Provision of Customer Billing Information to TDSPs | This Protocol Revision Request (PRR) revises Section 15.1.2.9.1, Customer Billing Contact Information, so that ERCOT is required to provide Customer contact information to the Transmission and /or Distribution Service Providers (TDSPs). This PRR will allow ERCOT to take the Customer Billing Contact Information file provided by the defaulting CR, remove all information except for ESI ID, Customer Name, and Customer Phone Number from the file and then pass that file to the TDSPs. | 05/10/2007 | Jennifer Garica w/Direct Energy | No | 15.1.2.9.1 Customer Billing Contact Information | Approved | |
| PRR722 | 48 Hour Restoration | This Protocol Revision Request (PRR) proposes language so that in the unlikely event of an ERCOT System shut down, ERCOT will return 90% of ERCOT peak load to pre-disturbed condition at or near 48 hours if a viable solution is available. | 05/14/2007 | Dennis Starbuck on behalf of the ERCOT Black Start Task Force | No | 6.5.8, Black Start Service | Rejected | |
| PRR723 | Conform 5.6.6.1 EECP (formally titled "Emergency Interruptible Load Service Formula Correction") | This Protocol Revision Request (PRR) proposes technical corrections to the progression of the Steps during an EECP event in Protocol Section 5.6.6.1. | 05/16/2007 | ERCOT | Yes | 5.6.6.1 | Approved |
07/01/2007
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| PRR724 | Removal of the Drop to AREP References | This Protocol Revision Request (PRR) removes references to the Drop-to-AREP transaction. | 05/18/2007 | Kathy Scott and Rob Bevill on behalf of Texas SET | No | 2.2, Acronyms 15, Customer Registration 15.1.1.9, Switching to Provider of Last Resort (delete) 15.1.2, Drop to Provider of Last Resort or Affiliate Retail Electric Provider (delete) 15.1.2.1, Drop Request by CR (delete) 15.1.2.2, Response from ERCOT to Drop to Affiliate Retail Electric Provider 15.1.2.3, Notification to Customer of Drop to Affiliate Retail Electric Provider (delete) 15.1.2.4, Notification to TDSP of Drop to Affiliate Retail Electric Provider (delete) 15.1.2.5, Response from TDSP to Registration Notification Request(delete) 15.1.2.6, Response from the TDSP to the Drop to Affiliate Retail Electric Provider Request (delete) 15.1.2.7, Notification of Affiliate Retail Electric Provider of Drop to Affiliate Retail Electric Provider 15.1.2.8, Completion of Drop Affiliate Retail Electric Provider Request and Effective Drop Date 15.1.2.9, Mass Transition 15.2.2.10, Rejection of Drop to Affiliate Retail Electric Provider Request (delete) 15.1.5, Concurrent Processing 15.1.5.1, Drop Date After or Equal to Switch Date (delete) 15.1.5.2, Drop Date Prior to Switch Date (delete) 15.1.5.7, Move-In Date Prior to or Equal to Drop Date (delete) 15.1.5.8, Move-In Date after Drop Date 15.1.5.11, Move-Out Date Prior to or Equal to Drop date (delete) 15.1.5.12, Move-Out Date After Drop Date 15.1.5.14, Multiple Drop to Affiliate Retail Electric Providers (delete) 15.1.7, Cancellation of Registration Transactions 15.1.8.4, Notice to CSA Competitive Retailer of Drop Due to Move-In 15.1.9.4, Notice to CSA Competitive Retailer of Drop Due to Move In 19.3.1, Defined Texas SET Transactions. | Approved | |
| PRR725 | Emergency Interruptible Load Service Formula & Standard Form Correction | This Protocol Revision Request (PRR) proposes technical corrections to the Protocols relating to Emergency Interruptible Load Service (EILS). | 05/24/2007 | ERCOT Staff | No | 6.10.13.3, Performance Criteria for EILS Resources; 22, Attachment K, Standard Form Emergency Interruptible Load Service (EILS) Agreement | Approved | |
| PRR726 | DC Tie Scheduling Clarifications | This Protocol Revision Request (PRR) clarifies language related to DC Tie scheduling and eliminates the use of the term œBack to Back Ti€? (BtB Tie) in the Protocols since the definition o“DC eâ€? captures any asynchronous tie. This PRR also modifies Protocol language regarding scheduling to reflect the manner in which ERCOT Operations actually treats DC Tie schedu | 05/25/2007 | ERCOT | No | 2.1, 2.2, 4.4.18.2, 5.6.6.1, 5.6.7, 5.6.8, 5.7.3, 5.8, 6.8.2.1 | Approved |
10/01/2007
|
| PRR727 | Process for Transition to Nodal Market Protocol Sections | This PRR authorizes an orderly transition from the zonal Protocols to the nodal Protocols. This PRR provides a transparent mechanism to retire zonal Protocol sections and implement nodal Protocol sections. This PRR also requires two notices to Market Participants: the first market notice thirty days prior to the retirement or effective date and the second market notice no less than ten days prior to the retirement or effective date. | 05/25/2007 | ERCOT Staff | No | 21.12 | Approved | |
| PRR728 | Proposal to Allow ERCOT Discretion When Processing Renewable Production Values | This PRR modifies paragraph (3) of Section 6.8.1.15.1 to allow ERCOT the discretion to process Renewable Production Potential values when submitted by Qualified Scheduling Entities (QSEs) representing only Uncontrollable Renewable Resources. | 05/25/2007 | ERCOT Staff | No | 6.8.1.15.1, Uninstructed Resource Charge Process | Approved | |
| PRR729 | Conforming Section 16 to New Section 22 Standard Form MP Agreements | Only one Standard Form Market Participant Agreement can be in place at a given point in time. To accommodate this, the following PRR conforms zonal Section 16 to match the updated Standard Form MP Agreement in the Nodal Protocols reflecting a single Standard Form Market Participant Agreement, as well as language applicable to the Independent Market Monitor (IMM), as required by P.U.C. SUBSt. R. 25.365, relating to the Independent Market Monitor (IMM). Modification of Section 22, adds Standard Form Market Participant Agreement. | 05/25/2007 | ERCOT Staff | Yes | 16.1, 16.2, 16.3, 16.4, 16.5, 16.6, 16.7, 16.9, 16.10, 22L (new) | Approved | |
| PRR730 | Balancing Energy Price Adjustment for Deployment of Replacement Reserve Service | This PRR adjusts the Market Clearing Price for Energy (MCPE) when Replacement Reserve Service (RPRS) is deployed. This PRR is intended to be similar to PRR 650, Balancing Energy Price Adjustment Due to Non-Spinning Reserve Service Energy Deployment, which removes non-spin deployments from the bid stack before calculating the MCPE. | 06/19/2007 | Coral Power | No | 6.8.1.12, Payments for Balancing Energy Provided from Ancillary Services During the Operating Period and 6.9.5.1, Balancing Energy Clearing Price | Rejected | |
| PRR731 | Fuel Oil Index Price (FOIP) | This Protocol Revision Request (PRR) adds Fuel Oil Index Price (FOIP) definition in Protocol Section 2 and revises language in Sections 6.8.1.11, Section 6.8.2.2 and Section 6.8.2.3 to allow the use of FOIP to meet verifiable cost documentation requirements. | 07/02/2007 | TXU Wholesale | No | 2, 6.8.1.11, 6.8.2.2, 6.8.2.3 | Approved |
12/01/2007
|
| PRR732 | Automatic Voltage Regulator (AVR) Status -- Compliance with NERC Reliability Standards | This PRR adds a requirement for telemetry of Generation Resource AVR status to comply with NERC Reliability Standards. | 07/09/2007 | ERCOT | No | 6.5.7.2 | Withdrawn | |
| PRR733 | Remove 168-Hour Generation Testing Requirement | This PRR will remove the 168 hour requirement and the need to utilize the observed actual output in the first 168 hours, if test data is not provided. | 07/09/2007 | ERCOT Staff | No | 6.10.2, General Capacity Testing Requirements | Approved |
12/01/2007
|
| PRR734 | Revisions to Congestion Management in McCamey Area Provisions | This PRR eliminates the 0600 hour timeframe by which ERCOT must post the Tradeable Generation Right (TGR) limits in Section 7.8.2, deletes the requirements in Section 7.8.7, and revises the spelling of "Tradeable" to "Tradable" in Section 2.2 and Section 7.8.4. | 07/30/2007 | ERCOT Staff | No | 2.2, Acronyms; 7.8.2, Determination of Generation Limits; 7.8.4, Determination of Tradeable Generation Rights; and 7.8.7, Trading or Other Uses of TGRs | Approved |
12/01/2007
|
| PRR735 | Incorporating the ERCOT Internal Audit Department and Other Clarifications | This PRR incorporates the ERCOT Internal Audit Department into the Protocols, clarifies the audits to be performed, and the treatment of audit results. Responsibility for performing the annual operational or "settlements" audit, otherwise commonly known as the Statement on Auditing Standards (SAS) No. 70 ("SAS 70"), Type II report, will continue to be performed by an external independent certified public accounting firm. Upon approval of this PRR, responsibility for performing the other audits referenced in Protocol Section 1.4, Operational Audit, will transition to the Internal Audit Department. | 08/07/2007 | ERCOT Staff | No | 1.4.2, 1.4.3.2, 1.4.3.1.1, 1.4.4, 1.4.5, 1.4.6 | Approved |
01/01/2008
|
| PRR736 | Demand Response Revisions | This Protocol Revision Request (PRR) revises existing Protocol language to facilitate Demand Response (DR) program(s) implementation. | 08/21/2007 | Lee Starr on behalf of COPS and PWG | No | 2, 18 | Withdrawn | |
| PRR737 | Direct Assignment of RPRS Costs | This PRR modifies the cost allocation methods for RPRS to be exactly the same as PRR676, RPRS Solution with Nodal RUC-Type Procurement and Cost Allocation, with one exception: the cap on the RPRS and Out-of-Merit Capacity (OOMC) charges is a multiple of one times the megawatts that a Qualified Scheduling Entity (QSE) is short. In PRR676, which was approved by the ERCOT Board of Directors and subsequently overturned by the Public Utility Commission (PUCT), the cap on the OOMC and RPRS charges was two times the megawatts that a QSE is short. | 09/05/2007 | Coral Power | Yes | 6.6.3.2.1, Specific Procurement Process Requirements for Replacement Reserve Service in the Adjustment Period; 6.8.2.2, Capacity and Minimum Energy Payments; 6.9.2, Obligations for Capacity Services Obtained in the Adjustment Period; 6.9.7.1, OOM Capacity Charge | Rejected | |
| PRR738 | Remove Old Versions of Standard Form Agreements | This revision deletes old versions of Standard Form Market Participant Agreements. | 09/24/2007 | Andrew Gallo | No | Section 22 Attachment B, Standard Form Load Serving Entity Agreement (delete) Section 22 Attachment C, Standard Form Qualified Scheduling Entity Agreement (delete) Section 22 Attachment D, Standard Form REC Account Agreement (delete) Section 22 Attachment E, Standard form Resource Entity Agreement (delete) Section 22 Attachment G, Standard Form Transmission and/or Distribution Service Provider Agreement (delete) | Approved |
02/01/2008
|
| PRR739 | Administrative Price Adjustments | This proposal revises that calculation to include administrative price adjustments under certain conditions. By modifying the calculation of MCPE in Section 6.9.5.1, all other Protocol reference to MCPE should be correct without further modification. Note that acceptance of this revision request negates the need for revisions to Protocols as passed under PRR650. | 10/03/2007 | BTU | No | 6.3.1, ERCOT Responsibilities 6.8.1.12, Payments for Balancing Energy Provided from Ancillary Services During the Operating Period 6.9.5.1, Balancing Energy Clearing Price | Rejected | |
| PRR740 | Creating Amendment to Standard Form Market Participant Agreement | This adds a new form, Amendment to Standard Form Market Participant Agreement, to the ERCOT Protocols. | 10/23/2007 | ERCOT Staff | No | 22N | Approved |
04/01/2008
|
| PRR741 | Revision of Digital Certificate Procedures | This PRR documents, in Section 16.11.3, Market Participant Audits of User Security Administrators and Digital Certificates, the requirement that Market Participants generate their own list of USA and Digital Certificate holders for audit purposes and use an automated process to manage (i.e., enroll, renew, revoke, and audit) their Digital Certificates. This PRR also clarifies the language describing the responsibilities of the Market Participant, its USA and ERCOT. | 10/24/2007 | ERCOT Staff | Yes | 16.11 | Approved |
01/01/2008
|
| PRR742 | Balancing Energy Price Adjustment Due to OOMC, OOME and RRS Deployments During Alert and Emergency Notice Conditions | This PRR is an alternative to PRR 739. It adjusts the Market Clearing Price of Energy (MCPE) when the deployment of Out of Merit Capacity (OOMC), or Out of Merit Energy (OOME) or Responsive Reserve Service (RRS) occurs during an Alert or Emergency Notice condition. This adjustment is similar to that applied to Non-Spin Reserve Service as described in PRR 650, Balancing Energy Price Adjustment Due to Non-Spinning Reserve Service Energy Deployment, which was approved by the ERCOT Board on August 15, 2007. However, in this PRR, these adjustments are effective only during intervals in which an ERCOT-declared Alert or Emergency Notice condition exists. Although ex-post pricing is not a perfect solution, it does allow the market to establish prices during emergency conditions rather than an administratively-set price. | 10/25/2007 | Luminant | No | 6.8.1.12 -- Payment for Balancing Energy Provided from Ancillary Services During the Operating Period | Rejected | |
| PRR743 | TCR Transition to CRR | This Protocol Revision Request (PRR) inserts Section 7.5.10, referring to the Transmission Congestion Rights (TCR) to Congestion Revenue Rights (CRR) Transition Plan. Section 7.5.10 allows the TCR to CRR Transition Plan to modify or supplement certain aspects of TCRs as documented in Section 7.5, Transmission Congestion Rights. The TCR to CRR Transition Plan is approved by TAC | 10/29/2007 | Bill Barnes, ERCOT | No | 7.5.10, Transition of Transmission Congestion Rights to Congestion Revenue Rights (new) | Approved |
10/01/2008
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| PRR744 | Revision to 16.2.8, Monitoring of Creditworthiness by ERCOT | The revision ensures that ERCOT will receive and accept as sufficient from the QSE, financial statements of the QSE or a guarantor if a guarantee is being provided for the purpose of determining the QSE’s creditworthiness. | 10/31/2007 | Reliant Energy | Yes | 16.2.8 | Approved | |
| PRR745 | NERC-TRE Terminology Update | This PRR updates the Protocols to reflect changes in NERC terminology and governance and contains other conforming changes. | 11/05/2007 | ERCOT Staff | No | 1.3.6, Exceptions; 2.1, Definitions; 4.4.18, Direct Current Tie Interconnection Day Ahead Scheduling Process; 5, Dispatch; 6.1, Ancillary Services Required by ERCOT; 6.4, Standards and Determination of the Control Area Requirements for Ancillary Services; 6.4.1, Standards for Determining Ancillary Services Quantities; 6.4.2, Determination of ERCOT Control Area Requirements; 6.5.3, Regulation Service (RGS) 6.5.8, Black Start Service; 6.5.11, Zonal Out-of-Merit Energy Service; 6.7.3, Deployment of Responsive Reserve Service; 6.8.2.1, Resource Category Generic Costs; 6.10.3.1, Regulation; 6.10.4, Ancillary Service Deployment Performance Measures; 6.10.5.3, SCE Monitoring Criteria; 6.10.9, Reactive Power Supply from Generation Resources Required to Provide VSS Performance Criteria; 6.10.11, ERCOT Operations Performance; 6.10.12.3, Settlement Timeline and Dispute Process; and 9.8.2, Direct Current Tie Schedule Information | Withdrawn | |
| PRR746 | Revisions to EILS Provisions to Conform to Amended P.U.C. Subst. R. 25.507 | This PRR amends various Protocols related to EILS. The specific amendments are as follows: · Section 2.1 is modified to eliminate the definitions of EILS Business Hours and EILS Non-Business Hours and to redefine the term "Time Period" consistent with the amended Rule. The Rule has eliminated the terms "Prime" and "Non Prime" hours and has provided ERCOT with flexibility to modify EILS Time Periods within a Contract Period. This amendment would permit ERCOT to establish EILS Time Periods by defining the hours in the Request for Proposal specific to a Contract Period. It would also allow ERCOT to restructure the EILS Contract Periods, consistent with the Rule, and would require ERCOT to post the restructured hours on its website at least 90 days prior to the start of the Contract Period. · Section 6.5.12(2) is amended to eliminate a requirement that was specific to the initial EILS bid solicitation in April 2007. · Section 6.5.12(5) is amended to clarify that ERCOT solicits EILS bids and that the bids are submitted by QSEs. · Section 6.5.12(6) is amended to eliminate the requirement that all members of an aggregated EILS Resource must have a peak demand of at least 500 kW. · Section 6.5.12(8) is amended to conform the EILS Cost Cap to the $50 million cost cap established by the Rule. This provision also conforms the Protocols to the Rule by clarifying that the Cost Cap applies to the 12 months from February through January, instead of a "rolling 12-month period." This provision also clarifies that ERCOT may reject any bid that it finds unreasonable or outside the parameters of an acceptable bid. This provision also moves the current Protocol language relating to how the Cost Cap is adjusted for Self-Provided EILS to its own subparagraph (9), and renumbers the existing (9) to (10). · Section 6.5.12(10), which established a 500 MW procurement minimum for the EILS service, is eliminated. · Section 6.5.12(17)(a) is amended to add clarity to the meter data requirements for any EILS Resource that does not have a dedicated ESI ID. This may include Loads within a NOIE area or within a Private Use Network. · Section 6.5.12(17)(b) is amended to clarify that an EILS Resource may return to service only after being released by ERCOT and to correct a typographical error. · Section 6.5.12(20), relating to sunset provisions for EILS, is eliminated. · A new Section 6.5.12(20) is added to prescribe ERCOT’s EILS reporting requirements. · Section 6.8.6 is amended to eliminate all subscript references to the terms "b" (business hours) and "nb" (non-business hours) in the equations used to calculate EILS Capacity Payments and convert them to a single reference term "tp" (time period). This amendment reaffirms that each EILS Time Period will be clearly defined by ERCOT in the Request For Proposal (RFP) specific to the EILS Contract Period. · Section 6.9.4.4 is amended to eliminate all subscript references to "b" (business hours) and "nb" (non-business hours) in the EILS settlement equations and convert them to a single reference of "tp" (time period). This amendment reaffirms that each EILS Time Period will be clearly defined by ERCOT in the RFP specific to the EILS Contract Period. · Section 6.10.13.3 is amended to eliminate all subscript references to "b" (business hours) and "nb" (non-business hours) in the equations used to calculate EILS Resources’ performance criteria and convert them to a single reference of "tp" (time period). This amendment reaffirms that each EILS Time Period will be clearly defined by ERCOT in the RFP specific to the EILS Contract Period. · Section 6.10.13.4 is amended to clarify procedures for ERCOT-administered penalties applied to QSEs and/or EILS Resources that fail to meet their availability or performance obligations and to make the Protocols consistent with the Rule. Specifically, the Rule requires a six-month suspension for failure to perform. This provision clarifies that the suspension may apply to the EILS Resource’s ability to participate and/or its QSE’s ability to offer EILS; clarifies when the six-month suspension period shall commence; and requires that a suspended EILS Resource may be reinstated only after successfully completing a load-shedding test. The provision also eliminates references to "revocation" of participation privileges for an EILS Resource or a QSE, as such is not provided for in the Rule. This amendment also retitles this Section to replace the word "Revocation" with the word "Suspension." · Section 16.5 is amended to clarify that EILS Resources are not required to register as Resource Entities, but rather are required to register via Appendix A of the QSE’s Standard Form EILS supplemental agreement with ERCOT. Appendix B of Section 22K, Supplement to QSE Agreement, is amended to provide flexibility to accommodate differing Time Periods. Appendix B is the "Term Sheet" representing the actual contractual obligation of a QSE and its EILS Resources for a specific Contract Period. Future Time Periods defined in Appendix B may vary by Contract Period, mirroring those set forth in the Registration/Proposal Form that accompanies the RFP and is the form used by the QSE and its EILS Resources to submit Bids or Self-Provision offers. | 11/07/2007 | ERCOT Staff | Yes | 2.1, 6.5.12, 6.8.6, 6.9.4.4, 6.10.13.3, 6.10.13.4, 16.5, 22K-AppB | Approved |
12/11/2007
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| PRR747 | IDR Requirement Change | This Protocol Revision Request (PRR) removes obsolete language covering the IDR threshold change to 700 KW and refers to the Retail Market Guide for specific installation procedures. | 12/05/2007 | Ernie Podraza | No | 18.6.1, Interval Data Recorder (IDR) Installation and Use in Settlement | Approved |
05/01/2008
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| PRR748 | Settlement During EDS 3 LFC Testing | This PRR modifies Out Of Merit Energy (OOME) and Local Balancing Energy (LBE) payment formulas for Early Deliver System (EDS) 3 R6.3 Load Frequency Control (LFC) (Total System) test. It also contains "clean up" items to correct terminology and capitalize terms that ought to be capitalized. | 12/10/2007 | Bill Barnes, ERCOT | Yes | 6.8.2.3, 7.4.3.1 and 7.4.3.2 | Approved |
02/01/2008
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| PRR749 | Rule Changes to the REC Trading Program | This Protocol Revision Request (PRR) provides changes in wording, REC account qualification, REC award formulas and the introduction of compliance premiums to comply with . P.U.C. Subst. R. 25.173. | 12/10/2007 | ERCOT | Yes | 2, 14 | Approved |
03/01/2008
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| PRR750 | Unannounced Generation Capacity Testing | This PRR replaces the seasonal testing requirement with unannounced Generation Resource testing and adds a requirement for Qualified Scheduling Entities (QSEs) to seasonally update their Resources’ High Sustainable Limits (HSLs). | 12/11/2007 | ERCOT Staff | Yes | 6.10.2 | Approved |
03/01/2008
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| PRR751 | Clarification to Definition of DUNS Number; Section 2, Definitions and Acronyms | This PRR revises and clarifies the definition of "DUNS Number" in Section 2 of the ERCOT Protocols. | 12/14/2007 | ERCOT Staff | No | 2.1 | Withdrawn | |
| PRR752 | Update to Posting Requirements of Standard QSE-Specific Market Reports | This PRR incorporates requirements in P.U.C. Subst. R. 25.505, Resource Adequacy in the Electric Reliability of Texas Power Region, adopted by the Public Utility Commission of Texas (PUCT) in its Order Adopting Amendment to §25.505 as Approved at the August 16, 2007, Open Meeting, in P.U.C. Project No. 33490, Rulemaking Proceeding to Address Pricing Safeguards in Markets Operated by the Electric Reliability Council of Texas. Specifically, this PRR removes language from boxes, revises the disclosure dates from 30 to 60 days after the Operating Day and adds language requiring disclosure of certain information if the Market Clearing Price for Energy (MCPE) or the Market Clearing Price for Capacity (MCPC) exceeds a certain level. | 12/17/2007 | ERCOT Staff | No | 12.4.4.2.3.3 | Approved |
05/01/2008
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| PRR753 | PRR Appeals Process | This Protocol Revision Request (PRR) provides for a more structured process for parties to appeal the decisions pertaining to PRRs made by the Protocol Revision Subcommittee (PRS) and the Technical Advisory Committee (TAC). This proposal also provides timelines for appealing PRS and TAC decisions and makes accommodating provisions for PRRs on an Urgent timeline. | 02/04/2008 | ERCOT Staff | No | 21.4.11, Appeal of Decision | Approved |
02/01/2009
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| PRR754 | Resource Settlement Due To Forced Transmission Outage | Clarifies Qualified Scheduling Entities (QSEs) scheduling generation Resources will receive Out of Merit Energy (OOME) Down to zero (0) Verbal Dispatch Instructions (VDIs) when a Transmission Facility Forced Outage trips a generation unit offline. | 02/04/2008 | FPL Energy | No | 6.5.11, Zonal Out-of-Merit Energy Service | Rejected | |
| PRR755 | Demand Response Program | To revise existing Protocol language to provide a short-term solution for the settlement of DR program(s). | 02/13/2008 | Jennifer Troutman on behalf of the Demand Response Task Force (DRTF) | No | 2.1, Definitions, 2.2, Acronyms, and 9.6, Settlement Charges | Withdrawn | |
| PRR756 | Distributed Renewable Generation Modifications | These changes allow for Load Profiling and Data Aggregation methodology to better represent the output of distributed renewable generation Resources with a capacity of less than 50 kW. | 02/29/2008 | Ernie Podraza on behalf of the Profiling Working Group (PWG) | Yes | 2.1, 2.2, 11.4.4.2 (new), 11.4.4.3 (new), 18, 18.2, 18.2.3 (new), 18.2.9 | Approved |
06/01/2008
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| PRR757 | Emergency Interruptible Load Service Formula Correction | This Protocol Revision Request (PRR) proposes the following changes: Revise the equation in Section 6.8.6(1) to eliminate subscript references to the term "b" (business hours) and replace it with reference term "tp" (time period) and delete a duplicate term in the variable definitions. Revise the equation in subsection 6.9.4.4(3) to delete the undefined term "EILS Business Hours;" provide a definition for the subscript term "i"; and revise subscript term "n" from upper case to lower case to match its use in the equ | 03/07/2008 | ERCOT Staff | No | 6.8.6, Capacity Payments for Emergency Interruptible Load Service (EILS); and 6.9.4.4, Settlement Obligation for Emergency Interruptible Load Service | Approved |
10/01/2008
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| PRR758 | Clarification of Language Related to Generation Netting for ERCOT Polled Settlement Meters | This PRR makes a minor change in wording to make clear intent of Protocol Section 10.3.2.3, i.e., that metering may net the generation and the Load associated with such generation for the purposes of settlement. | 03/14/2008 | Henry Durrwachter (Luminant Generation Company LLC) | Yes | 10.3.2.3, Generation Netting for ERCOT Polled Settlement Meters | Approved |
05/01/2008
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| PRR759 | Changes to Notification to Customer of Service Establishment | This Protocol Revision Request (PRR) deletes Section 15.1.4.3 from the ERCOT Protocols and renumbers subsequent subections. | 03/19/2008 | ERCOT Staff | No | 15.1.4.3, Notification to Customer of Service Establishment | Approved |
08/01/2008
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| PRR760 | Emergency Interruptible Load Service (EILS) Availability Factor Clarification | This Protocol Revision Request (PRR) clarifies a settlement and compliance provision relating to availability requirements for Emergency Interruptible Load Service (EILS) Resources assigned to the alternate baseline. | 03/24/2008 | ERCOT Staff | No | 6.10.13.3 Performance Criteria for EILS Resources | Approved |
10/01/2008
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| PRR761 | Inadvertent Energy Account Revision | This Protocol Revision Request corrects the definition for an Inadvertent Energy Account | 04/16/2008 | ERCOT Staff | No | 2.1, Definitions; and 4.4.18.5, Inadvertent Energy Account | Approved |
08/01/2008
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| PRR762 | West Zone SCE Performance Conditions | The PRR revises Section 6.10.6 to exclude from consideration of performance periods where Qualified Scheduling Entities (QSEs) operating controllable units in the West zone are called upon to deploy and recall Balancing Energy in response to high wind production and Congestion in the area. | 04/21/2008 | AEP | Yes | 6.10.6, ancillary service deployment performance conditions | Approved | |
| PRR763 | Use of WGRPP as Planned Operating Level in Day-Ahead Resource Plan for WGRs | This Protocol Revision Request (PRR) allows Qualified Scheduling Entities (QSEs) representing Wind-powered Generation Resources (WGR) to use an ERCOT provided Wind-powered Generation Resource Power Potential (WGRPP) forecast as the planned operating level in the Resource Plan. | 05/16/2008 | John Dumas on behalf of the Reliability and Operations Subcommittee (ROS) | Yes | 2.1, Definitions, 2.2, Acronyms and 4.4.15, QSE Resource Plans | Approved |
07/01/2008
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| PRR764 | Zonal Congestion and CSCs/CREs | This Protocol Revision Request (PRR) provides that zonal constraints are only those constraints for which a Commercially Significant Constraint (CSC) or Closely Related Elements (CRE) is the base case or post-contingency limiting element. | 05/29/2008 | Potomac Economics | Yes | 7.3.2, 7.5.2 | Approved | |
| PRR765 | Time Of Use Revisions | This Protocol Revision Request (PRR) revises existing Protocol language to comply with the latest Public Utility Commission of Texas (PUCT) Ruling on approval of Time Of Use Schedules (TOUS). | 06/10/2008 | Ernie Podraza on behalf of the Profiling Working Group (PWG) | No | 18, Load Profiling | Approved |
11/01/2008
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| PRR766 | Interim Solution for 15-Minute Settlement of Advanced Meters | Implementing this Nodal Protocol Revision Request (NPRR) will support the interim settlement of all provisioned Advanced Meters using actual fifteen minute data, the same way Interval Data Recorder (IDR) meters are settled today, until the long-term solution developed by Project 34610, Implementation Project Relating to Advanced Metering or future rulemakings is implemented.ERCOT and the Public Utility Commission of Texas (PUCT) have developed an Request For Information to investigate the long-term solution to advanced meter settlement and data transport. The PUCT unanimously approved the "Scope of Work" of the long-term study on May 22, 2008. See P.U.C. SUBST. R. 25.130(h), Advanced Metering. | 06/20/2008 | AEP Texas | Yes | 9.2.6, 10.3.3.1, 10.3.3.3, 10.12.3, 11.2.2, 18.2, 18.6.7, 18.7.2, 19.7 (new) | Approved | |
| PRR767 | Issuance of Alerts for Certain Uses of Balancing Energy | This Protocol Revision Request (PRR) proposes a revision that allows ERCOT to issue an Alert pursuant to Section 5.6.5, Alert, instead of declaring an Emergency Condition when using zonal Balancing Energy to resolve flow limit violations for base case or post-contingency limiting elements that are not Commercially Significant Constraints (CSCs) or CREs. | 07/14/2008 | ERCOT Staff | No | 7.3.2 | Rejected | |
| PRR768 | TSP Energy Storage for Reliability (formerly "TDSP Energy Storage for Reliability") | This Protocol Revision Request (PRR) inserts new paragraph (6)(c) in Section 10.3.3.1 which clarifies that energy flows, from Transmission Service Provider (TSP) owned battery storage technology, will be treated similarly as substation equipment and therefore the measurement of such flows are not required for settlement. This new paragraph will be limited to ERCOT Board endorsed TSP reliability projects. | 07/21/2008 | American Electric Power Company | Yes | 10.3.3.1 | Approved | |
| PRR769 | EECP Media Appeal Change | This Protocol Revision Request (PRR) removes required energy conservation media appeal from EECP Step Two and allows ERCOT management to issue a media appeal for energy conservation at management’s discretion, without requiring ERCOT CEO authorization. | 07/22/2008 | John Jonte on behalf of the Operations Working Group (OWG) | No | 5.6.6.1, 5.6.6.2, 5.6.7 | Approved |
02/01/2009
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| PRR770 | Deletion of UFE Analysis Zone Language | This Protocol Revision Request (PRR) deletes an outdated section pertaining to Unaccounted for Energy (UFE) analysis. | 07/24/2008 | ERCOT | No | 13.4.2 | Approved |
01/01/2009
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| PRR771 | Ramp Rate Limitation of 10% per minute of On-Line Installed Capability for Wind-powered Generation Resources | This Protocol Revision Request (PRR) proposes a requirement for Wind-powered Generation Resources (WGRs) to limit the ramp rate to 10% per minute of On-line installed capability. | 07/25/2008 | ROS | No | 6.5.13(new), 6.6, 6.6.1 | Approved |
01/01/2009
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| PRR772 | Description of MCPE Cap and Shadow Price Cap Methodology | This PRR clarifies ERCOT’s authority to take action to ensure that the Market Clearing Price of Energy (MCPE) does not exceed the system-wide offer cap established by the Public Utility Commission of Texas (PUCT) in PUC Subst. R. 25.505, Resource Adequacy in the Electric Reliability Council of Texas Power Region. This PRR also proposes that the methodology to make the price adjustments be described in a separate document and that Market Participants be notified of any changes in the Shadow Price caps. In addition, this PRR proposes to change the section title in Section 6.11.1, Balancing Energy Offer Cap Floor, to Balancing Energy Offer Floor, to avoid confusion. A similar change is proposed for Section 6.11.2. | 07/25/2008 | ERCOT Staff | Yes | 6.11.1, Balancing Energy Offer Cap Floor; 6.11.2, Responsive Reserve Service (RRS) Offer Cap Floor; and 7.1, Overview of ERCOT Congestion Management | Approved | |
| PRR773 | Setting the LSL Requirement for WGRs | This Protocol Revision Request (PRR) requires that a Wind-powered Generation Resource (WGR) Low Sustainable Limit (LSL) to be set at 10% of the name plate rating of the WGR. | 07/28/2008 | QSE Managers Working Group | No | 4.10.4, Resource Low Sustainable Limit as a Percent of High Sustainable Limit Measure | Approved | |
| PRR774 | Treatment of Financial Information as Confidential | This Nodal Protocol Revision Request (NPRR) clarifies that non-public financial information provided to ERCOT is to be treated as Protected Information. | 08/15/2008 | Clayton Greer on behalf of J Aron | No | 1.3.1.1 | Approved |
01/01/2009
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| PRR775 | Change the name of Emergency Electric Curtailment Plan (EECP) to Energy Emergency Alert (EEA) | This Protocol Revision Request (PRR) changes the name of the Emergency Electric Curtailment Plan (EECP) to Energy Emergency Alert (EEA). | 08/22/2008 | ERCOT | No | 2.1, 2.2, 5.6.6.1, 5.6.6.2, 5.6.7, 5.6.7.1, 5.6.8, 5.7, 5.8, 6.1.13, 6.5.2, 6.5.12, 6.7.3, 6.7.9, 6.10.2, 6.10.3.2, 6.10.6, 6.10.13.3 | Approved |
05/01/2009
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| PRR776 | Automatic MCPE Adjustment During Intervals of Non-Spinning Reserve Service Deployment | This Protocol Revision Request (PRR) adjusts the Market Clearing Price of Energy (MCPE) when the deployment of NSRS occurs to provide accurate prices in Real Time through an automatic $100/MWh upward adjustment. The $100 MCPE adjustment would replace the current PRR650, Balancing Energy Price Adjustment Due to Non-Spinning Reserve Service Energy Deployment, method of removing NSRS deployments and manually re-running Scheduling, Pricing, and Dispatching (SPD). The $100 adjustment is based on the average MCPE adjustment during NSRS deployments since 01/01/07. | 08/25/2008 | Texas Industrial Energy Consumers (TIEC) | Yes | 6.8.1.12, 6.9.5.1 | Approved | |
| PRR777 | WGR QSE Metric Correction | This Protocol Revision Request (PRR) exempts Wind-powered Generation Resource (WGR) Qualified Scheduling Entities (QSEs) from the Resource Plan metric that compares Day Ahead and Adjustment Period Schedules to Resource Plans. | 09/18/2008 | J Aron | No | 4.10.5, 4.10.6 | Approved |
01/01/2009
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| PRR778 | Clarification of Authorized Representative | This Protocol Revision Request (PRR) codifies the definition of "Authorized Representative" in Section 2, Definitions and Acronyms, and clarifies the need to designate "Authorized Representatives" for registration for all registered Entities. | 09/19/2008 | ERCOT | No | 2.1, 6.8.1.11, 6.8.2.2, 6.8.2.3, 10.3.2.1, 16.2.8, 16.2.9, 16.2.9.2.1, 16.2.9.2.2, 16.2.9.2.3, 16.2.9.2.4, 16.2.9.2.7, 16.3, 16.4, 16.5 | Approved |
02/01/2009
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| PRR779 | Transparency for PSS and Full Interconnection Studies | Updates to Section 1 to provide transparency to status of Power System Stabilizer Equipment and interconnection requests. | 09/19/2008 | Marguerite Wagner/PSEG Texas | No | 1.3.1.1, Items Considered Protected Information 1.3.1.2, Items Not Considered Protected Information 12.2, ERCOT Obligation to Provide Information 12.3, Transmission-Related Information | Approved | |
| PRR780 | Extending Black Start Service Bid Timeline | This Protocol Revision Request (PRR) changes the Black Start Service bids from a one (1) year period to a two (2) year period. | 09/23/2008 | John Dumas on behalf of the Reliability and Operations Subcommittee (ROS) | No | 6.5.8, Black Start Service 22, Attachment A, Standard Form Black Start Agreement | Approved | |
| PRR781 | EILS Self-Provision Formula Correction and Clarifications | This Protocol Revision Request (PRR) proposes to correct terms contained in the settlement equations related to EILS Self-Provision to make the formulas consistent with the verbal description of EILS Self-Provision settlement and the author’s stated original intent. Specifically, the formula correction applies to the uplifted costs of EILS as defined in paragraph (3) of Section 6.9.4.4, as follows: · Clarifies that uplifted EILS costs are based on final adjusted EILS obligations after accounting for any self-provided EILS. This is accomplished by establishing and defining a new formula term, EILOF. · Adjusts other related formula terms accordingly. · Adds a missing subscript term definition that appears in numerous places elsewhere in the Protocols. · Adds clarity to certain other equation term definitions.This PRR also makes clarifications in language contained in paragraph (3)(d) of Section 6.5.12 related to Qualified Scheduling Entities’ (QSEs’) EILS Self-Provision options in cases where less than 1,000 MW of EILS has been offered, and adds copies of definitions that are applicable to both equations in this Section. | 09/23/2008 | ERCOT | No | 6.5.12, 6.9.4.4 | Approved |
02/01/2009
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| PRR782 | Clean-up and Corrections to Terminology and Transaction Timings in Protocol Section 15, Customer Registration | This Protocol Revision Request (PRR) corrects and clarifies the transaction timing descriptions to make them consistent with current processes and Appendix D, Transaction Timing Matrix, in the Retail Market Guide. | 10/02/2008 | Rob Bevill and Kathy Scott on behalf of the TX SET Working Group | No | 2.1, 2.2, 15 | Approved |
03/01/2009
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| PRR783 | Elimination of the Non-ERCOT LSE Fee | Eliminate language within protocol Section 9.7.3 which describes the Texas Non-ERCOT LSE fee. | 10/02/2008 | Barry R. Smith | Yes | 9.7.3, Texas Non-ERCOT Load Serving Entity Fee | Approved |
01/20/2009
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| PRR784 | Delete Use of Boundary Generation Resources to Resolve CRE Congestion | This Protocol Revision Request (PRR) removes language regarding resolution of Congestion on a Closely Related Element (CRE) by Boundary Generation Resources from Protocol Section 7.3.2, Resolution of Zonal Congestion. | 10/28/2008 | J Aron | No | 7.3.2 | Approved |
04/01/2009
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| PRR785 | Timing for Required Black Start Unit Load Carrying Test. | This Protocol Revision Request (PRR) changes the required Black Start Unit Load Carrying Test from once every six (6) years to once every five (5) years. | 11/20/2008 | ERCOT | No | 6.10.3.6 | Approved |
04/01/2009
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| PRR786 | Modifications to EILS Settlement | This Protocol Revision Request (PRR) revises language to: · Clarify that the first settlement of the Emergency Interruptible Load Service (EILS) Contract Period shall utilize a Qualified Scheduling Entity (QSE) Load Ratio Share (LRS) which is based upon the Final Load for each Operating Day in the EILS Contract Period; · Introduce a resettlement of EILS Contract Period settlement utilizing a QSE LRS which is based upon the True-Up Load for each Operating Day in the EILS Contract Period; · Remove conflicting language about EILS disputes; · Clarify the timing by which EILS settlement disputes must be submitted; and · Move all language related to the timing of the EILS settlement process to Section 9.5.5, Resettlement of Emergency Interruptible Load Service. | 11/21/2008 | Jim Galvin on behalf of the SDAWG | No | 6.8.6 Capacity Payments for Emergency Interruptible Load Service (EILS), 6.9.4.4 Settlement Obligation for Emergency Interruptible Load Service, 9.5.5, Resettlement of Emergency Interruptible Load Service | Approved | |
| PRR787 | Add Non-Compliance Language to QSE Performance Standards (formerly "Add Violation Language to QSE Performance Standards") | This Protocol Revision Request (PRR) adds language to Section 6.10.5.3 which clearly defines if and when a violation of the Protocols occurs for failure to comply with performance standards. The proposed language adds clarity to Section 6.10.5.3 that is found in other Protocol Sections associated with Qualified Scheduling Entity (QSE) performance metrics. | 12/03/2008 | International Power America | No | 6.10.5.3, 6.10.6, 6.10.12, 6.10.12.1, 6.10.12.2, 6.10.12.3, 6.10.12.5 (new) | Approved | |
| PRR788 | Ramp Rate Limits for Existing WGRs | This PRR proposes a requirement that certain existing WGRs limit the unit ramp rate to ten percent (10%) per minute of their nameplate capacity ratings as registered with ERCOT. | 12/09/2008 | FPLEnergy | Yes | 6.5.13 | Approved |
02/01/2009
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| PRR789 | Removal of Grey Box Language Related to Lagged Dynamics Load Profiling Due to Unfunded Projects | This Protocol Revision Request (PRR) removes grey box language related to the use of lagged dynamic samples for new profiles. | 12/09/2008 | Ernie Podraza on behalf of the Profiling Working Group (PWG) | No | 18.2.1, Guidelines for Development of Load Profiles 18.2.2, Load Profiles for Non-Interval Metered Loads 18.2.6, Daily Profile Creation Process | Approved | |
| PRR790 | Load Profile ID Annual Validation Change Request | This Protocol Revision Request (PRR) allows for changes in the Annual Validation process timeline due to extreme events. | 12/09/2008 | Ernie Podraza on behalf of the Profiling Working Group (PWG) | No | 18.4.2, Load Profile Id assignment | Approved | |
| PRR791 | Shortage Pricing Mechanism | This PRR creates "Virtual QSEs" that can establish pricing during periods of energy shortage. | 12/10/2008 | J Aron | Yes | 6.5.2.2 | Withdrawn | |
| PRR792 | Revised Renewable Portfolio Standards Allocation Process, Pursuant to P.U.C. Subst. R. 25.173 | This PRR modifies the Protocols to comply with PURA § 39.904(m-1) and P.U.C. Subst. R 25.173. | 12/15/2008 | Katie Coleman of Andrews Kurth, LLP, on behalf of Texas Industrial Energy Consumers (TIEC) | Yes | 1.3.1.1, 14.2, 14.5.2, 14.5.3 (new), 14.9.3.1 and 14.9.5 | Approved |
02/01/2009
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| PRR793 | WGR QSE Scheduling Metric | This Protocol Revision Request (PRR) provides specific details for WGR-only QSEs such that the scheduling metric will apply to more Operating Hours. | 12/24/2008 | QSE Managers Working Group (QMWG) | Yes | 4.10.6, 5.5.1, 7.3.2 | Approved |
03/01/2009
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| PRR794 | Meteorological Data Required from QSEs Representing Wind-powered Generation Resources | This Protocol Revision Request (PRR) will require a Wind-powered Generation Resource (WGR) Entity to provide Real Time meteorological information to ERCOT through its selected Qualified Scheduling Entity (QSE). It will also require ERCOT to establish procedures specifying the accuracy requirements of WGR meteorological information telemetry. | 12/24/2008 | QSE Managers Working Group (QMWG) | Yes | 6.5.1.1 | Approved |
04/01/2009
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| PRR795 | 90-Day Transmission Outage Scheduling Timeline | This Protocol Revision Request (PRR): 1) Adds a new Outage response timeline that will place a requirement on ERCOT to coordinate Outages submitted with more than ninety (90) days notice at least seventy-five (75) days prior to the start of the proposed Outage; and 2) Provides clarification of three (3) to eight (8) day timeline to eliminate an overlap in requirements. | 01/05/2009 | ERCOT | Yes | 8.3.3 | Approved |
03/01/2009
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| PRR796 | Resource Plan Performance Metrics Revision | With this Protocol Revision Request (PRR), ERCOT shall determine the performance of providers of Qualified Scheduling Entities (QSEs) Schedule Control Error (SCE) performance under normal operating conditions. ERCOT shall remove from consideration of average performance of a QSE any period during which an abnormal or unusual event(s) has occurred and which does not have a passing score. | 01/07/2009 | FPL Energy | No | 4.10.2.1 (new) | Approved | |
| PRR797 | Removal of Reference to ERCOT Business Processes | This Protocol Revision Request (PRR) revises the term "Generation Resource Asset Registration Form" in Section 4.10.4.1, LSL Requirements for WGRs, to a generic phrase "as registered with ERCOT". | 01/12/2009 | Patrick Coon | No | 4.10.4.1, LSL Requirement for WGRs | Approved | |
| PRR798 | Update Trading Hub Conversion | This Protocol Revision Request (PRR) synchronizes the ERCOT Protocols to reflect the 2009 Commercially Significant Constraint definitions, approved by the ERCOT Board on October 21, 2008, as it affects the Trading Hub calculations for 2009 (several transmission buses moved between Congestion Zones). As such, the calculation for converting transactions at Trading Hubs to existing Congestion Zones is revised. | 01/12/2009 | ERCOT | Yes | 7.9.2.6, 7.9.3.4 | Approved |
02/17/2009
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| PRR799 | ERCOT CEO Approval of NPRRs and SCRs Prior to Posting on MIS | This Protocol Revision Request (PRR) mandates ERCOT CEO approval before NPRRs may be posted to the Market Information System (MIS). This PRR also mandates ERCOT CEO approval for System Change Requests (SCRs) that impact system functionality for the Nodal market. This PRR also allows an appeal mechanism for the submitter of the NPRR or SCR if the ERCOT CEO’s decision is to reject the NPRR or SCR. | 01/19/2009 | ERCOT | Yes | 21.8.1, 21.11.3.1 | Approved |
02/17/2009
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| PRR800 | QSE Day Ahead Metric | This Protocol Revision Request (PRR) re-defines the Day Ahead metric for both Wind-powered Generation Resource (WGR) Qualified Scheduling Entities (QSEs) and non-WGR QSEs to ensure that both categories of QSEs schedule enough capacity in the Day Ahead market to meet their planned energy schedules plus Ancillary Service (AS) Obligations. This PRR removes the WGR QSEs exemption established in PRR 777, WGR QSE Metric Correction. | 01/20/2009 | ERCOT | Yes | 4.10.5 | Approved | |
| PRR801 | Manual TCR Adjustments | This Protocol Revision Request (PRR) revises Section 7.5.3.1, Annual and Monthly Auction Summary, to provide a description of the process used by ERCOT to achieve revenue neutrality in the monthly TCR auction. | 02/09/2009 | ERCOT | No | 7.5.3.1 | Approved |
09/01/2009
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| PRR802 | TCR Transition to CRR Refund Revision | This Protocol Revision Request (PRR) revises Section 7.5.10 methodology, providing flexibility in the event monthly Transmission Congestion Rights (TCR) are awarded and require refund for the subsequent month after Nodal Go-Live. | 02/19/2009 | Mandy Bauld / Steve Reedy | No | 7.5.10, Transition of Transmission Congestion Rights to Congestion Revenue Rights | Approved | |
| PRR803 | Revised Implementation Approach for PRR 601 | This PRR changes the ramping period for BES deployment for Base Power Schedule Calculation and Balancing Energy Power Schedule from ten (10) minutes to fourteen (14) minutes. | 02/20/2009 | Raj Rajagopal and Troy Anderson on behalf of ERCOT | Yes | 6.5.2, Balancing Energy Service 6.8.1.15.3, Uninstructed Charge Methodology and Equation 6.10.4.2, Base Power Schedule Calculation 6.10.4.3, Balancing Energy Power Schedule | Approved | |
| PRR804 | Revisions to Section 21 Appeal Process | This Protocol Revision Request (PRR) revises Section 21, Process for Protocol Revision, to provide that if a motion to approve a revision request fails, the revision request shall be deemed rejected by the body considering it and subject to appeal, unless at the same meeting that body later votes to recommend approval, remand, or refer the revision request. | 02/20/2009 | ERCOT | Yes | 21.4.3, 21.4.4, 21.4.6, 21.4.7, 21.4.9, 21.4.10, 21.4.11.1, 21.4.11.3, 21.8.3, 21.8.4, 21.8.7, 21.8.8, 21.8.9, 21.8.10, 21.8.12, 21.8.12.1, 21.8.12.2, 21.8.12.3, 21.11.3.3, 21.11.3.4, 21.11.3.6, 21.11.3.7, 21.11.3.8, 21.11.3.9, 21.11.3.10 | Approved | |
| PRR805 | Adding POLR Customer Class and AMS Meter Flag to the Database Query Function on the MIS | This Protocol Revision Request (PRR) will add Provider of Last Resort (POLR) Customer class and the Advanced Metering System (AMS) meter flag to the database query function on the Market Information System (MIS). | 03/06/2009 | Jennifer Frederick on behalf of the Texas Standard Electronic Transaction (Texas SET) Working Group | No | 15.2 | Approved | |
| PRR806 | Re-Registration of Market Participant due to Mass Transition of ESI IDs | This Protocol Revision Request (PRR) requires re-registration as a Market Participant (MP) if they transfer Electric Service Identifiers (ESI IDs) from one Competitive Retailer (CR) to another using the Mass Transition process. | 03/06/2009 | Jennifer Frederick on behalf of the Texas Standard Electronic Transaction (Texas SET) Working Group | No | 15.1.3 and 16.1.1 | Approved |
08/01/2009
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| PRR807 | Clarify Definition of Messaging System | This Protocol Revision Request (PRR) revises the definition of "Messaging System" to include a process that makes Real Time messages available to "bidding QSEs" without Resources. | 03/26/2009 | ERCOT | No | 2.1 | Approved | |
| PRR808 | Clean-up and Alignment of RECs Trading Program Language with PUCT Rules | This Protocol Revision Request (PRR) cleans up and aligns the language in Section 14, State of Texas Renewable Energy Credit Trading Program, with P.U.C. Subst. R. 25.173, Goal for Renewable Energy. This PRR also updates references to the Renewable Energy Credit (REC) Trading Program throughout the Protocols. | 03/26/2009 | ERCOT | No | 14 | Approved |
08/01/2009
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| PRR809 | OOMC Startup Costs Clarification & Modification | This Protocol Revision Request (PRR) modifies Section 6.8.2.2, Capacity and Minimum Energy Payments, to explicitly state the criteria currently used to determine eligibility for Out of Merit Capacity (OOMC) startup costs, as well as clawback of startup costs. This PRR also incorporates ‘max zero’ logic into the settlement formula that calculates the price for the startup costs (PSui). | 03/27/2009 | Mandy Bauld on behalf of ERCOT | Yes | 6.8.2.2, Capacity and Minimum Energy Payments | Approved |
07/01/2009
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| PRR810 | Remove McCamey Congestion Management | This Protocol Revision Request (PRR) removes the unique congestion management procedures for the McCamey Area. | 04/01/2009 | Potomac Economics | No | 2.2, 7.8 | Approved |
09/01/2009
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| PRR811 | Real Time Production Potential | This Protocol Revision Request (PRR) establishes a requirement for Wind Generation Resources (WGRs) to telemeter a Real Time signal indicating the Real Time Production Potential which will be a function of wind and turbine availability at the time. | 04/17/2009 | Wind Coalition | No | 2.1, 2.2, 6.5.1.1 | Approved | |
| PRR812 | Wind Generator Forecast Scheduling (formerly "Wind Generator Forecast for Scheduling Metric") | This Protocol Revision Request (PRR) specifies the process for Wind-powered Generation Resources (WGRs) to update Resource Plans and schedules every hour using the ERCOT provided most likely Short-Term Wind Power Forecast (STWPF) as the standard for accuracy. [Note - It is expected that AWS Truewind will be providing a forecast adjusted for turbine availability as a result of other pending Protocol changes.] | 04/24/2009 | Wind Coalition | No | 2.1, 2.2, 4.5.1, 4.5.10, 4.5.12 (new) | Approved |
10/01/2009
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| PRR813 | FIP Definition Revision | This Protocol Revision Request (PRR) revises the definition of Fuel Index Price (FIP) to correctly account for the timing difference between ERCOT’s application of the FIP in its systems (midnight to midnight) and the timing of natural gas prices reflected by the index (i.e., 10 AM to 9 AM). The fuel price index published in Gas Daily, in the Daily Price Survey, under the heading "East-Houston-Katy, Houston Ship Channel" for any particular day reflects natural gas prices available to users from hour ending 10 AM of the particular day to hour ending 9 AM of the next day (i.e., the normal "gas day"). This PRR also adds a new definition for the term "Gas Day."This PRR also proposes non-substantive administrative changes, such as correcting acronym and defined term usage and section references. These are shown below with the author "ERCOT Market Rules." | 05/29/2009 | Luminant Energy Company LLC | No | 2.1, 6.8.2.1, 6.8.2.3 | Withdrawn | |
| PRR814 | NOx Emissions Allowance Index Price (NOxEAIP) | This Protocol Revision Request (PRR) establishes a definition for NOx Emissions Allowance Index Price (NOxEAIP) that relies on a published cost index for NOx emissions allowances. The PRR provides Qualified Scheduling Entities (QSEs) with an option to either provide detailed documentation of the actual cost of NOx emissions allowances as part of the verifiable cost process or to rely on the NOxEAIP. Specifically, this PRR allows QSEs to recover the cost of emissions allowances when providing Replacement Reserve, Out of Merit Capacity (OOMC) or Out of Merit Energy (OOME) Service as directed by ERCOT if the costs of those emissions allowances are less than one hundred ten percent (110%) of the NOxEAIP. This is the same concept that is applied to the documentation requirements of natural gas prices and fuel oil prices for verifiable cost purposes. This PRR also adds language to clarify how QSEs can recover any emissions-related costs for both startup and operations when providing Replacement Reserve, OOMC or OOME Service. This PRR also proposes non-substantive administrative changes, such as correcting acronym and defined term usage and section references. These are shown below with the author "ERCOT Market Rules." | 06/01/2009 | Luminant Energy Company LLC | Yes | 2.1, 6.8.1.11, 6.8.2.2, 6.8.2.3 | Approved |
09/01/2009
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| PRR815 | CSC Process Clarification | This Protocol Revision Request (PRR) clarifies the process used to determine Commercially Significant Constraints (CSCs). This PRR also proposes non-substantive administrative changes, such as correcting acronym and defined term usage and section references. These are shown below with the author "ERCOT Market Rules." | 06/10/2009 | ERCOT | Yes | 7.2, 7.2.1, 7.2.2, 7.2.3 | Approved |
08/01/2009
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| PRR816 | CRE Determination Criteria | This Protocol Revision Request (PRR) establishes a set of four criteria for determining if a candidate contingency/limiting element pair qualify as a Closely Related Element (CRE). | 06/22/2009 | Congestion Management Working Group (CMWG) | Yes | 7.2.3, 7.2.3.1 (new), 7.2.3.1.1 (new), 7.2.3.1.2 (new), 7.2.3.1.3 (new), 7.2.3.1.4 (new), 7.2.3.1.5 (new) | Approved |
09/01/2009
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| PRR817 | Cease Late Payment Charges for Defaulted Entities | This Protocol Revision Request (PRR) modifies language to: 1) Enable ERCOT to cease charging late fees to defaulting Entities prior to the initiation of the Uplift process, provided that ERCOT has determined that the recovery of late fees from the defaulting Entity is unlikely; and 2) Clarify how much security may be held back to be used to pay minor Final, True Up and other Invoices as they come due to reduce the administrative burden to the ERCOT market of processing short payments. | 06/25/2009 | Cheryl Yager on behalf of ERCOT | No | 9.4.4, Partial Payments | Approved | |
| PRR818 | OOMC for Quick Start Units | This Protocol Revision Request (PRR) provides that a Quick Start Unit that is not synchronously interconnected to the ERCOT System that receives an Out of Merit Energy (OOME) Dispatch Instruction or Local Balancing Energy Instruction will be settled as providing Out of Merit Capacity (OOMC) Service. | 06/26/2009 | Topaz Power Group | Yes | 6.5.2, 6.8.2.2, 6.8.2.3 | Approved |
10/01/2009
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| PRR819 | Changes to Support Revisions to the PUCT POLR and Expedited Switch Rules | This Protocol Revision Request (PRR) provides that ERCOT shall identify, for 60 days, Electric Service Identifiers (ESI IDs) acquired in a Mass Transition to a Provider of Last Resort (POLR) so that Customers that switch from the POLR are not charged for an out-of-cycle meter read. This PRR also implements changes necessary to expedite the customer switching process. This PRR also proposes non-substantive administrative changes, such as correcting acronym and defined term usage and section references. These are shown below with the author "ERCOT Market Rules." | 06/29/2009 | Jennifer Frederick on behalf of the Texas Standard Electronic Transaction (Texas SET) Working Group | Yes | 2.1, 15, 15.1.1, 15.1.1.1, 15.1.1.2, 15.1.1.3, 15.1.1.3.1, 15.1.1.3.2, 15.1.1.4, 15.1.1.5, 15.1.1.6, 15.1.1.7, 15.1.1.8, 15.1.1.9, 15.1.3, 15.1.4.2, 15.1.5.4, 15.1.6.3, 15.1.6.6, 15.1.8, 15.1.10 | Approved |
08/18/2009
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| PRR820 | Definition for Transmission and/or Distribution Service Provider | The PRR modifies the definition for Transmission and/ or Distribution Service Provider (TDSP) to include Entities that were selected to own and operate Transmission Facilities listed in the PUCT Order for Docket 35665, Commission Staff’s Petition for the Selection of Entities Responsible for Transmission Improvements Necessary to Deliver Renewable Energy from Competitive Renewable Energy Zones. | 07/10/2009 | ChadSeely | Yes | 2.1, Definitions | Approved | |
| PRR821 | Update of Section 21, Process for Protocol Revision | This Protocol Revision Request (PRR) updates Section 21 to more effectively align with the current stakeholder process. Changes were made to bring consistency between the PRR, System Change Control (SCR), and Nodal Protocol Revision Request (NPRR) processes, where applicable; remove arbitrary or conflicting timelines; clarify commenting process; expand on a revision request being deemed rejected to include email voting for the Technical Advisory Committee (TAC); and include administrative changes and clean up. | 07/13/2009 | ERCOT | No | 21 | Approved |
01/01/2010
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| PRR822 | Removing Access to Restricted Computer Systems, Control Systems and Facilities | This PRR defines the requirement for all Market Participants to have processes in place for removing access to restricted computer systems, control systems, and Facilities upon termination. This PRR also defines the reporting requirement for incidents where improper access by terminated employees, contractors, consultants and affiliates has occurred. | 07/14/2009 | Victor Barry | Yes | 16.12, Improper Access to Restricted Computer Systems, Control Systems and Facilities (new) | Approved | |
| PRR823 | Clarifying Language for Resource 12-Month Rolling Planned Outage Schedule Format and Reporting Requirement | This Protocol Revision Request (PRR) clarifies language regarding the requirement for Resource Entities to input a 12-month rolling schedule for Outages in the Outage Scheduler application. | 07/14/2009 | Calpine | No | 8.1.3.2 | Approved | |
| PRR824 | Primary Frequency Response from WGRs | This Protocol Revision Request (PRR) adds a requirement for wind generator control systems to be programmed to respond to frequency deviations by controlling WGR real power output in a way that is similar to governor response for conventional generators. | 07/21/2009 | Rick Keetch on behalf of the Reliability and Operations Subcommittee (ROS) | No | 2.1, 5.9.1.1, 5.9.1.3 (new) | Approved | |
| PRR825 | Distributed Energy Resource Participation in Responsive Reserve Service Markets | This Protocol Revision Request (PRR) allows Distributed Energy Resources (DERs) to participate in Responsive Reserve Service (RRS) markets subject to the restrictions provided in the Protocols and Operating Guides. The sponsor of this PRR anticipates that changes to the Operating Guides would also need to be made to define the set points for the under-frequency relays. The sponsor proposes setting these values at 59.7 to parallel the action of under-frequency relay breakers in Loads acting as a Resource (LaaR). | 07/24/2009 | Enchanted Rock Reliability Services | No | 2.1, 2.2, 6.5.1.1, 6.5.4, 6.7.3, 6.10.1, 6.10.2, 6.10.5.4, 6.10.12 | Rejected | |
| PRR826 | Clarification of Resource Definitions and Resource Registration of Self-Serve Generators for Reliability Purposes | This Protocol Revision Request (PRR) adds language to acknowledge the existence of Generation Resources that have no or minimal injection onto the ERCOT System that qualify either as distributed generation or are registered with the Public Utility Commission of Texas (PUCT) according to P.U.C. Subst. R. 25.109, Registration of Power Generation Companies and Self-Generators, as a self-generator but yet are required to participate with ERCOT for reliability purposes. | 07/24/2009 | ERCOT | No | 2.1, 2.2, 5.3, 5.4.2.1, 5.4.3, 5.9.3.1, 6.5.1.1, 8.1.1, 8.1.2, 8.1.3.2, 8.2.1, 8.2.3, 8.2.4, 8.2.5, 8.4.1, 8.4.3, 8.4.7, 8.8.2, 16.5, 16.5.1, 16.5.2, 16.5.2.2 | Withdrawn | |
| PRR827 | Find Transaction and Find ESI ID Functions on the MIS | This Protocol Revision Request (PRR) updates the Protocols to reflect current options that Market Participants have to obtain information from ERCOT in order to determine or to verify the Electric Service Identifier (ESI ID) for a Service Delivery Point (SDP). | 08/20/2009 | ERCOT | No | 15.2, 15.2.1 (new), 15.2.2 (new), 15.2.3, (new) | Approved |
01/01/2010
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| PRR828 | Remove QSE SCE Performance Exemption for QSEs with only Uncontrollable Renewable Resources On-line | Stakeholders participating in the special task force on steady state performance metrics for Resources in response to the Public Utility Commission of Texas (PUCT) Staff’s draft Protocol Revision Request (PRR) 586, SCE Performance and Regulation Cost Re-allocation, purposely and temporarily exempted Wind-powered Generation Resource (WGR)-only Qualified Scheduling Entities (QSEs) from the metric they developed in order to focus on the task of building a meaningful metric for all other Resource technologies. This PRR would eliminate that exemption and place WGR-only QSEs on an even playing field with other technologies based on their impact to the system’s reliability and Ancillary Services procured and in recognition of the maturity of the technology to date as evidenced in select white papers promoting WGR provision of Ancillary Services. | 09/01/2009 | Calpine | Yes | 6.10.6 | Rejected | |
| PRR829 | Total Transmission Capacity Correction | This Protocol Revision Request (PRR) replaces the acronym Total Transfer Capability (TTC) with Total Transmission Capacity (TTC), defined in Section 2.2. | 09/03/2009 | ERCOT | Yes | 2.2, 4.4.2, 12.1 | Approved | |
| PRR830 | Reactive Power Capability Requirement | This PRR clarifies the Reactive Power capability requirement for all Generation Resources, including existing WGRs who are not able to meet the 0.95 lead/lag requirement with the Generation Resource’s Unit Reactive Limit (URL). WGRs that commenced operation on or after February 17, 2004, and have a signed Standard Generation Interconnection Agreement (SGIA) on or before November 1, 2009 may met the Reactive Power requirements through a combination of the WGR’s URL and/or automatically switchable static VAR capable devices and/or dynamic VAR capable devices. | 09/08/2009 | ERCOT | Yes | 2.1, 2.2, 6.5.7, 6.5.7.1, 6.7.6 | Approved |
12/01/2009
|
| PRR831 | Annual Transmission Congestion Rights (TCR) Auction Amount | This PRR revises the amount of TCRs sold in the annual TCR auction from 40% to 30%. | 09/09/2009 | Isabel Flores | Yes | 7.5.3.1, Annual and Monthly Auction Summary | Approved | |
| PRR832 | Deletion of Schedule Control Error (SCE) Posting Requirement | This Protocol Revision Request (PRR) removes the language that requires ERCOT to post the Schedule Control Error (SCE) report seven days after the Operating Day to the Market Information System (MIS). | 09/15/2009 | John Dumas | No | 12.4.4.2.3.3, Public Posting of Entity-Specific Market Reports | Approved | |
| PRR833 | Primary Frequency Response Requirement from Existing WGRs | This Protocol Revision Request (PRR) places a Primary Frequency Response requirement on WGRs that were not covered by PRR824, Primary Frequency Response from WGRs. | 09/22/2009 | CPS Energy | No | 5.9.1.3 (new) | Approved | |
| PRR834 | ERCOT Load Forecast Accuracy | This Protocol Revision Request (PRR) proposes revisions that are intended to monitor and establish performance standards for ERCOT’s Load forecasting of the ERCOT Region and ERCOT Congestion Zones.This PRR also proposes non-substantive administrative changes, such as correcting acronym and defined term usage and section references. These are shown below with the author "ERCOT Market Rules." | 09/24/2009 | Luminant, CPS Energy and NRG Texas | Yes | 2.2, 4.4.7.1 (new), 4.4.7.2 (new), 4.4.7.3 (new), 6.4.2 | Withdrawn | |
| PRR835 | Reactive Capability Requirement | This PRR clarifies the Reactive Power capability requirement for WGRs by specifying +/- 0.95 power factor criteria as the minimum requirement, and the Generation Resources Unit Reactive Limit (URL) criteria as the maximum requirement contingent upon a System Impact Study by the TSP. | 09/30/2009 | Peter Wybierala on behalf of NextEra Energy Resources | Yes | 2.1, 2.2, 6.5.7, 6.5.7.1, 6.5.7.4 (new), 6.7.6 | Rejected | |
| PRR836 | Revised Minimum Ramp Rate for Balancing Energy Service Down to Comport with PRR803 | This Protocol Revision Request (PRR) changes the divisor for the minimum ramp rate required for a Balancing Energy Service Down bid from 40 to 56 to reflect the change resulting from the implementation of PRR803, Revised Implementation Approach for PRR 601, as it relates to the number of minutes of Balancing Energy Service ramping over a one-hour time period. | 10/14/2009 | Luminant Energy Company LLC | Yes | 4.5.2 | Approved |
12/01/2009
|
| PRR837 | Load Used in RMR Studies | This Protocol Revision Request (PRR) would provide guidance to ERCOT to use the peak Load forecast posted pursuant to P.U.C. Subst. R. 25.505, Resource Adequacy in the Electric Reliability Council of Texas Power Region, for the next 12 months for the Reliability Must-Run (RMR) study, except with respect to the Load in the RMR local area. This aligns the Load forecast period with the RMR contract period and ensures that the Load forecast used for the analysis is one with a reasonable probability of occurrence.This PRR also proposes non-substantive administrative changes, such as correcting acronym and defined term usage and section references. | 10/16/2009 | PSEG TX | No | 6.5.9.1 | Approved |
04/01/2010
|
| PRR838 | Fast Response Distributed Energy Resource (DER) | This Protocol Revision Request (PRR) allows for participation of Distributed Energy Resources (DERs) in Responsive Reserve Service (RRS) on an equivalent basis with synchronous condenser fast-response hydro. | 10/22/2009 | Enchanted Rock | No | 2.1, 2.2, 6.5.4 | Withdrawn | |
| PRR839 | Revised Resource Category Generic Fuel Costs | This Protocol Revision Request (PRR) revises the Resource Category Generic Fuel Cost (RCGFC) for Direct Current (DC) Tie with non-ERCOT Control Area and Block Load Transfer (BLT) Resources to synchronize with the Nodal Protocols and to allow cost recovery for supplying this service. | 10/23/2009 | AEP Energy Partners | Yes | 6.8.2.1, 6.8.2.3 | Approved |
01/01/2010
|
| PRR840 | Update Trading Hub Conversion for 2010 Congestion Zones | This PRR synchronizes the ERCOT Protocols to reflect the 2010 Commercially Significant Constraint (CSC) definitions, approved by the ERCOT Board on September 15, 2009, as ot affects the Trading Hubs to existing Congestion Zones is revised. A similar PRR for 2009, PRR798, was approved by the ERCOT Board on February 17, 2009. | 11/12/2009 | Carrie Tucker | Yes | 7.9.2.6, ERCOT Bus Average 345 kV Trading Hub 7.9.3.4, Scheduling of Transactions Using ERCOT Hubs | Approved | |
| PRR841 | Revise Total ERCOT Wind Power Forecast (TEWPF) | This Protocol Revision Request (PRR) revises the probability of exceedance percentage applicable to the Total ERCOT Wind Power Forecast (TEWPF) from 80% to 50% to better reflect the total ERCOT Wind-powered Generation Resource (WGR) production that has been historically experienced. | 11/30/2009 | Luminant | No | 2.1, 2.2, 4.4.15, 4.5.12 | Approved |
04/01/2010
|
| PRR842 | Addition of Generic Startup Cost and Minimum Energy Cost for Diesel | This Protocol Revision Request (PRR) adds generic costs for the Diesel Resource Category, which also includes other gas-fired Resources (including reciprocating engines). This PRR makes the minimum energy costs for diesel consistent with what is currently in the Nodal Protocols. | 12/10/2009 | South Texas Electric Cooperative, Inc. | Yes | 6.8.2.1 | Approved |
02/01/2010
|
| PRR843 | Add Regional Planning Section to Protocols | This Protocol Revision Request (PRR) adds the entirety of the RPG Charter and Procedures (Charter) document, as it was recently approved by the ERCOT Board, to the Protocols. | 12/18/2009 | ERCOT | No | 1.1, 2.1, 2.2, 3.5, 25 (new) | Withdrawn | |
| PRR844 | Transmission and/or Distribution Service Provider (TDSP) Definition Revision | This Protocol Revision Request (PRR) revises the definition of Transmission and/or Service Provider (TDSP) to include Entities that have been selected to own and operate Transmission Facilities and have a code of conduct approved by the Public Utility Commission of Texas (PUCT). | 01/15/2010 | Mike Grable on behalf of ERCOT | No | 2.1, Definitions | Approved | |
| PRR845 | Definition for IDR Meters and Optional Removal of IDR Meters at a Premise Where an Advanced Meter Can be Provisioned | This Protocol Revision Request (PRR) clarifies the meaning of Interval Data Recorder (IDR) Meter and provides for optional removal of IDR Meters under certain conditions for Premises where an Advanced Meter can be provisioned by the Transmission and/or Distribution Service Provider (TDSP). In addition, due to the proposed definition of an IDR Meter, Protocol references to IDR and/or IDR Meter are being updated to ensure appropriate understanding and usage of the terms. This PRR also proposes non-substantive administrative changes, such as correcting acronym and defined term usage and section references. | 01/22/2010 | Terry Bates on behalf of the Retail Metering Working Group (RMWG) | No | 2.1, 2.2, 6.5.12, 6.10.5.2, 6.10.13.1, 6.10.13.3, 9.2.5, 9.2.6, 9.2.6.1, 9.9, 10.2.2, 10.3.2.3, 10.3.3.3, 10.9, 10.9.1,10.9.2, 10.9.3, 18.6, 18.6.1, 18.6.2, 18.6.3, 18.6.4, 18.6.5, 18.6.6, 18.6.7 | Approved |
08/01/2010
|
| PRR846 | Deadlines for Initiating Alternative Dispute Resolution | This PRR amends Section 20.3 to establish deadlines for the ADR procedures. | 02/15/2010 | Horizon Wind Energy LLC | No | 20.3, Informal Dispute Resolution 20.4, Mediation Procedures 20.5.2, Selection of Arbitrators | Approved | |
| PRR847 | Additional Exemptions for Uninstructed Resource Charge | This Protocol Revision Request (PPR) proposes two changes to Section 6.8.1.15.1 as follows: 1. When a Qualified Scheduling Entity (QSE) is given a verbal Dispatch Instruction from ERCOT, the QSE shall be exempt from any Uninstructed Resource Charge during the specified verbal Dispatch Instruction time period, provided that the QSE followed instructions to within the Schedule Control Error (SCE) of the verbal Dispatch Instruction given. 2. After a Load acting as a Resource (LaaR) has been activated, the QSE representing the LaaR can request a three hour extension for scheduling under paragraph (11) of Section 6.10.6, Ancillary Service Deployment Performance Conditions, and during this rescheduling time, a Private Use Network shall not incur Uninstructed Resource Charges for three hours as the Load returns back to service. Additional non-substantive administrative revisions, such as correcting defined term usage, number usage and paragraph references, are shown with the author "ERCOT Market Rules." | 03/15/2010 | Formosa Utility Venture, Ltd | No | 6.8.1.15.1 | Approved | |
| PRR848 | Allow ERCOT Option to Cancel RPRS Capacity Commitments | This Protocol Revision Request (PRR) adds statements allowing ERCOT the option of canceling capacity commitments made by Replacement Reserve Service (RPRS). Additional non-substantive administrative revisions, such as correcting acronym usage, are shown with the author "ERCOT Market Rules." | 03/22/2010 | ERCOT | No | 6.5.6 | Rejected | |
| PRR849 | Suspension of Annual CSC Determination | This Protocol Revision Request (PRR) revises Section 7.2.1 to suspend Commercially Significant Constraint (CSC) analyses for 2010. | 05/11/2010 | ERCOT | Yes | 7.2, 7.2.1, 7.2.2, 7.2.3, 7.5 | Approved |
07/01/2010
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| PRR850 | Weather Responsiveness Determination for Interval Data Recorders | This Protocol Revision Request (PRR) limits the applicability of the weather responsiveness test to Interval Data Recorder (IDR) Meters. | 08/11/2010 | COPS | Yes | 11.4.3, 11.4.3.1 | Approved |