Withdrawn Protocol Revision Requests (PRRs)
# Title Description Date Posted Urgent Protocol Sections Current Status
PRR213Dynamic Schedules GenerationRequests that a QF have a choice of QSE to maintain dynamic flexibility.03/28/2001Yes4.9.2Withdrawn
PRR242Waiver for Existing ContractsTNMP requests that Protocol Section 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.04/27/2001Yes10.3.2.3Withdrawn
PRR250NOIE Consumption by ESI-IDAllows the QSE for a NOIE to see the consumption data for an ESI-ID for that NOIE.06/20/2001No15.2 & 15.3Withdrawn
PRR276Adjust BENA ComputationAdjust the computation of the Balancing Energy Neutrality Adjustment to more accurately assign the payments and charges to Load Serving Entities.08/20/2001Yes9.6.1Withdrawn
PRR277Clarify SCF Fee DeterminationSec. 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.08/20/2001Yes7.3.3.1Withdrawn
PRR281Allowance 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.05/24/2002NovariousWithdrawn
PRR282Define OOME as an Instructed Deviation09/11/2001YesWithdrawn
PRR284Adjusted Computation of BENAAdjust 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.09/12/2001Yes9.6.1Withdrawn
PRR286Smoothing AlgorithmThis revision will change the calculation of the Schedule Control Error equation.09/12/2001No6.10.4.2Withdrawn
PRR290Balancing Energy Down BidsAn 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.10/04/2001No4.4.5Withdrawn
PRR293Uncontrollable Renewable ResourcesRequest Boxing of Existing Language since functionality does not exist to provide for this functionality and there is no viable manual work-around.10/10/2001Yes6.
PRR301Over scheduling Load Imbalance LimitsProvides an upper limit for Load Imbalance credits to QSEs when the QSEs load is significantly overscheduled.11/28/2001No6.9.5.2Withdrawn
PRR304Unexecutable Move-inThe 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_02.12/10/2001Yes15.1.4.5; [new]Withdrawn
PRR317Revise Computation Procedure for TCRsClarify and modify determination of CSC limits and TCRs.02/05/2002Yes7.5.2,,
PRR320Loads Participation in AS MarketThe 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.03/01/2002Yes6.10.3.2(4);; &
PRR331OOMC Floor PriceRevise OOMC Payment calculations so that such deployments are not pay as bid & establish the OOMC floor payment as discussed in the PRS recommendation of PRR285.05/06/2002Yes6.8.2Withdrawn
PRR339REC for OOM DownThis 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 25.173.05/20/2002Yes14.7Withdrawn
PRR340Remove Market Solution DefinitionThis 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.05/20/2002Yes2.1, 4.1.2, 4.5.3, 6.1.10, 6.1.11, 6.3.1, 6.4.2,,,, 6.7.8,, 7.1,, 7.3.2, 7.4.2,,,, 7.4.4, & 7.6Withdrawn
PRR353Change Control Classification UpdateEliminates 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.08/13/2002No19Withdrawn
PRR375AS Schedule TimesClarifies when AS schedules may be modified.12/23/2002No4.3.5; 4.4.8 & 4.4.14Withdrawn
PRR384Protocol Preamble and Process for Advisory OpinionThe 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.02/06/2003YesPreamble [new],1.5 [new], 1.6, 1.7, 1.8Withdrawn
PRR399IDR Replacement with Non-IDR Meter RequirementsThis 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.04/15/2003Yes18.6.1 & 18.6.6Withdrawn
PRR406Two Year CSC & Zone SelectionRevises the current one year forward establishment of CSCs and zones to a two year forward approach.04/18/2003Yes7.2Withdrawn
PRR412Distributed Generation With No Energy ExportThe 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 required04/01/2003No10.2.2Withdrawn
PRR418Creation of New CSCModify Section, create new section, Approval Process and add language related to a new CSC effective July 1, 2003 through the remainder of 2003.05/23/2003Yes7.2.1.3Withdrawn
PRR430Historical UsageThis PRR would add language that specifies usage provided for conversion/opt-in be reported in time intervals no longer than thirty-eight days.06/18/2003No19.3.1Withdrawn
PRR432Liability for LSE DefaultThis PRR would allocate responsibility for LSE default among Generation Entities, LSEs, and TDSPs.06/19/2003No2.1, 9.4.4Withdrawn
PRR434Adjustment to Allocation of REC Purchase RequirementThis 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.06/25/2003No14.1Withdrawn
PRR435Confidentiality of LSE Transaction DataThis 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 information06/30/2003No1.3.1Withdrawn
PRR438REC TimelinesRevises reporting, issuing and mandated retirements requirements based upon change for final settlement.07/02/2003No14.2, 14.4.2, 14.6.2, 14.7, 14.10, 14.10.5, 14.11.1, 14.13, 14.14Withdrawn
PRR455Liability for QSE default on obligations to ERCOT and Responsibility for ERCOT Administration FeeSpreads risk of default of a QSE and ERCOT costs among both Loads and Resources.08/25/2003No9.4.4; 9.7.1Withdrawn
PRR476Ramp Rate Adherence During Local CongestionCurrently, 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 0.11/13/2003Yes6.7.1.2, 6.10.7Withdrawn
PRR480Reporting of Switch and Move-In DataThis 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.12/04/2003No15.6 [new]Withdrawn
PRR494Revise Forecasted Load Profile Post timeERCOT 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.02/24/2004No18.3.3Withdrawn
PRR500OOME Down Payments - Verifiable CostsThe 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.03/17/2004No6.8.2.3Withdrawn
PRR503Section 8 Coordination of Resource Outage Due to TSPResource 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.03/19/2004No8.2.4Withdrawn
PRR505Elimination of OOME Down PaymentsThis 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.03/24/2004No6 & 7Withdrawn
PRR506Revision to Short Payment ProcessRevises the timeline for uplift of partial payments.03/29/2004No9.4.4Withdrawn
PRR511Clarification of PCR EligibilityThe 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.04/05/2004No7.5.6Withdrawn
PRR516Curtailment 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 congestionRequires new WPGRs locating in the McCamey area to install Special Protection Schemes to limit their output.04/30/2004No7.4.2, 7.8.8Withdrawn
PRR524Clarification of Timeline for Cost SubmissionMost 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.06/07/2004No6.8.1.11,,,,
PRR533Definition of Transmission Facility OwnerResponsibility 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.07/29/2004No2, 8.3.8,,,,,,,
PRR539OOMC Claw Back CorrectionPrevents payments for OOMC service from being negative (a charge)09/01/2004No6.8.2.2Withdrawn
PRR549Regulation Control During Abnormal Frequency EventsThis PRR revises Sections 6.5.3,, 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.10/08/2004No6.5.3,, 6.10.6         Withdrawn
PRR552Clarification of Relaxed Balanced SchedulesClarifies 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.10/18/2004No4.3.2Withdrawn
PRR553Scheduling Trading HubsModify ERCOTs scheduling requirements to accommodate transactions involving ERCOT Trading Hubs.10/20/2004No4.2, 4.3.1, 4.4.8, 4.7.2,
PRR554ERCOT Approval of Transmission System OutagesChanges 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.10/29/2004No8.3.1Withdrawn
PRR574Specify Effective Date for PRRsRevise 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.02/10/2005No21.1, 21.6Withdrawn
PRR602Ancillary Service Obligation for DC Tie ExportsThis revision removes the allocation of Ancillary Service to DC Tie exports and provides for curtailment of DC Tie exports at Step 2 of EECP05/18/2005No4.4.18.2,,, 5.6.7Withdrawn
PRR605SCE Performance Monitoring for Combined Cycle Resources 052705Revise Sections and subsections to change the SCE performance standard for combined cycle resources from 90% to 80%.05/27/2005No6.10.5.3Withdrawn
PRR608Improve Ancillary Service Performance ConditionsRevise section 6.10.6 of the protocols to include the impact of different ramp rates on the calculation of a QSEs SCE Performance Metric.06/01/2005No6.10.6Withdrawn
PRR615Direct Load Control ProgramsRequests 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 criteria07/07/2005No6.3.2, 18.7.2Withdrawn
PRR616Interim Solution for the Direct Assignment of Replacement Costs for System-wide Capacity InsufficiencyProvides 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.07/13/2005Yes6.1.6, 6.1.10,,
PRR626Monthly RMR Status ReportAdds 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.08/26/2005No6.5.9.2Withdrawn
PRR631Black Start Bid Procedures and Compensation for TestingThis 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, 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.09/06/2005No6.10.3.6Withdrawn
PRR645Customer Information RepositoryThis 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.)11/18/2005No15.1.2.9Withdrawn
PRR652Customer Information RepositoryThis 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.)03/08/2006No15.1.2.9, (new)Withdrawn
PRR678Allocation of RPRS Over-Collection to QSEsThis 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.07/28/2006Yes6.8.1.16 – Settlement of NSRS Over-Collection (New); – Replacement Reserve Uplift ChargeWithdrawn
PRR696MAPE PublicationThis 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 error10/17/2006No4.2, Scheduling-Related Duties of ERCOTWithdrawn
PRR712Local Congestion Replacement Reserve Payment MethodologyThis 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.02/19/2007No6., Specific Procurement Process Requirements for Replacement Reserve Service in the Adjustment Period;, Local Congestion Replacement Reserve Payment to QSE;, Capacity and Minimum Energy PaymentsWithdrawn
PRR715Simplifying the Dispute ProcessThis 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 grante03/27/2007No6.8.2.6, 9.1.2, 9.2.5, 9.5, 9.5.2, 9.5.3, 9.5.4, (new), (new)Withdrawn
PRR719Texas Regional Entity/NERC/FERC Penalties or AssessmentsAs 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.04/16/2007No2.1, 2.2, 9.7.9 (new), (new), (new)Withdrawn
PRR732Automatic Voltage Regulator (AVR) Status -- Compliance with NERC Reliability StandardsThis PRR adds a requirement for telemetry of Generation Resource AVR status to comply with NERC Reliability Standards.07/09/2007No6.5.7.2Withdrawn
PRR736Demand Response RevisionsThis Protocol Revision Request (PRR) revises existing Protocol language to facilitate Demand Response (DR) program(s) implementation.08/21/2007No2, 18Withdrawn
PRR745NERC-TRE Terminology UpdateThis PRR updates the Protocols to reflect changes in NERC terminology and governance and contains other conforming changes.11/05/2007No1.3.6, 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;, Resource Category Generic Costs;, Regulation; 6.10.4, Ancillary Service Deployment Performance Measures;, SCE Monitoring Criteria; 6.10.9, Reactive Power Supply from Generation Resources Required to Provide VSS Performance Criteria; 6.10.11, ERCOT Operations Performance;, Settlement Timeline and Dispute Process; and 9.8.2, Direct Current Tie Schedule InformationWithdrawn
PRR751Clarification to Definition of DUNS Number; Section 2, Definitions and AcronymsThis PRR revises and clarifies the definition of "DUNS Number" in Section 2 of the ERCOT Protocols.12/14/2007No2.1Withdrawn
PRR755Demand Response ProgramTo revise existing Protocol language to provide a short-term solution for the settlement of DR program(s).02/13/2008No2.1, Definitions, 2.2, Acronyms, and 9.6, Settlement ChargesWithdrawn
PRR791Shortage Pricing MechanismThis PRR creates "Virtual QSEs" that can establish pricing during periods of energy shortage.12/10/2008Yes6.5.2.2Withdrawn
PRR813FIP Definition RevisionThis 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."05/29/2009No2.1,,
PRR826Clarification of Resource Definitions and Resource Registration of Self-Serve Generators for Reliability PurposesThis 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.07/24/2009No2.1, 2.2, 5.3,, 5.4.3,,, 8.1.1, 8.1.2,, 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,
PRR834ERCOT Load Forecast AccuracyThis 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."09/24/2009Yes2.2, (new), (new), (new), 6.4.2Withdrawn
PRR838Fast 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.10/22/2009No2.1, 2.2, 6.5.4Withdrawn
PRR843Add Regional Planning Section to ProtocolsThis 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.12/18/2009No1.1, 2.1, 2.2, 3.5, 25 (new)Withdrawn