Rejected Nodal Protocol Revision Requests (NPRRs)
# Title Description Date Posted Sponsor Urgent Protocol Sections Current Status Effective Date(s)
NPRR018 Separate LaaR and Generator MCPCs for RRS Modify the nodal protocols to provide separate RRS MCPCs for LaaRs and generators when the service is oversubscribed by LaaRs, as per the WMS vote taken on May 17, 2006. 08/11/2006 No 4.5.1, 4.5.3, Rejected
NPRR021 Reduce Timeline for Notice and Cure and Create a Working Credit Limit Reduces time to post collateral from two Bank Business Days to one (exception: Municipalities, Electric Cooperatives, or an Entity created under Texas Water Code (TWC) §222.001, may continue to take two Bank Business Days to post collateral agreements). Creates a working credit limit which allows an entity to utilize up to 85% of posted collateral + unsecured credit limit (rather than 100%). Reduces time to cure a payment breach under QSE, LSE and TCR. 08/28/2006 Credit Work Group No 16.11.5, 16.11.6, 22H Rejected
NPRR053 Creation of a New Trading Hub at Venus Switching Station Creates a new trading hub at Venus Switching Station. 03/12/2007 Constellation Energy Commodities Group No, Venus 345 kV Hub (Venus 345) (New) Rejected
NPRR056 Modify Competitive Load Zones This Nodal Protocol Revision Request (NPRR) changes the Competitive Load Zones to be the Congestion Zones in effect when ERCOT transitions to the nodal market. 03/28/2007 Coral Power, LLC No 3.4.1 Load Zone Types Rejected
NPRR079 Remove Shift Schedule Posting Requirement This PRR eliminates the posting requirement in Section 6.3.1 and 08/15/2007 ERCOT Staff No 6.3.1, Activities for the Adjustment Period and, Centralized Dispatch Rejected
NPRR216 Allow ERCOT Option to Cancel Commitments Previously Issued Through RUC This Nodal Protocol Revision Request (NPRR) adds statements allowing ERCOT the option of cancelling commitments, prior to breaker close, previously issued through RUC. Additional non-substantive administrative revisions, such as correcting defined term and acronym usage, are shown with the author "ERCOT Market Rules." 03/22/2010 ERCOT No 2.1, 5.1, 5.3, 5.4, 5.5.2, 5.5.3, 5.7.3 Rejected
NPRR287 Real-Time Market Price Delivery Consistency This Nodal Protocol Revision Request (NPRR) proposes to remove Locational Marginal Prices (LMPs) from Inter-Control Center Communications Protocol (ICCP) communications, based on emerging concerns regarding the inconsistent timeframes for price delivery in Real-Time. 10/18/2010 ERCOT No 6.3.2 Rejected
NPRR300 Municipal Owned Utility Addition to Determination of Total Potential Exposure for a Counter-Party This Nodal Protocol Revision Request (NPRR) adds Municipally Owned Utilities (MOUs) to the list of Entities exempt from the requirement to grant ERCOT a first priority security interest in order for Total Potential Exposure (TPE) of a Counter-Party to be based on the algebraic sum of the Counter-Party’s current and future credit exposures. 12/03/2010 City of Garland No Rejected
NPRR308 Deployment Procedures for Non-Spin Resources This Nodal Protocol Revision Request (NPRR) will require Non-Spinning Reserve (Non-Spin) Service deployments to respect Resource Parameters as registered with ERCOT. 01/13/2011 City of Garland No Rejected
NPRR309 Providing STWPF to QSEs Contractually Affiliated with WGR The Nodal Protocols currently enable a Wind-powered Generation Resource (WGR) and the Qualified Scheduling Entity (QSE) representing that WGR to receive ERCOT’s Short-Term Wind Power Forecast (STWPF) for that WGR via the Messaging System and the Market Information System (MIS) Certified Area. This Nodal Protocol Revision Request (NPRR) would require ERCOT to provide the WGR forecast to any QSE contractually affiliated with that WGR. 01/14/2011 Lower Colorado River Authority (LCRA) No 4.2.2 Rejected
NPRR315 Revision of Responsive Reserve Measure to High Emergency Limit (formerly "Revision of Responsive Reserve Measure to Net Dependable Capability) This Nodal Protocol Revision Request (NPRR) changes Responsive Reserve (RRS) Service 20% limit to check against High Emergency Limit (HEL) instead of High Sustained Limit (HSL). 02/02/2011 Morgan Stanley Yes 3.18, Rejected
NPRR336 Authorize ERCOT to Procure Additional RRS During Severe Cold Weather This Nodal Protocol Revision Request (NPRR) allows ERCOT to procure additional Responsive Reserve (RRS) during cold weather conditions. 03/09/2011 TNMP No 2.1, Rejected
NPRR349 Clarification of Ancillary Service Provider’s Responsibilities, Addition of Penalty Factor Charge for Failure to Provide, and Addition of Ancillary Service Capacity Compliance Performance Criteria This Nodal Protocol Revision Request (NPRR) addresses several issues related to Ancillary Services. First, this NPRR revises Protocol Section to add the following description regarding the timing associated with a Qualified Scheduling Entity’s (QSE’s) obligation to deliver the physical Ancillary Service capacity that it has self-arranged or sold to ERCOT from its designated Resources during the Operating Hour. The QSE’s obligation begins at the top of each Operating Hour and ends with the top of the next Operating Hour and is continuous throughout the Operating Hour. Secondly, this NPRR introduces a penalty factor to increase charges to each QSE that fails to provide Ancillary Service capacity as described in Protocol, Replacement of Ancillary Service Due to Failure to Provide. The penalty factor is defined as a multiplier that is applied to each of the charge calculations defined in Section 6.7.2. The penalty factor equals ten for Regulation Up (Reg-Up), Regulation Down (Reg-Down), and Responsive Reserve Services (RRS) and five for Non-Spinning Reserve (Non-Spin) Service. Finally, this NPRR: Adds an ERCOT monitoring requirement to the Section 8.1 grey box for Ancillary Service capacity performance metrics for failure to provide Ancillary Service capacity; and Adds performance criteria to Section that apply to events that occur when QSEs are unable to meet their Ancillary Service Obligations because of an inability to deliver an Ancillary Service due to a failure to provide (refer to Protocol Section Protocol Section allows the QSE the opportunity to replace this undeliverable Ancillary Service capacity, within a time frame acceptable to ERCOT or, otherwise, ERCOT is authorized to use the Supplemental Ancillary Services Market (SASM) or emergency operations processes to replace the Ancillary Service capacity. The additions to Section allow ERCOT the option to revoke a QSEs Ancillary Service qualification and/or a Resource’s Ancillary Service qualification to provide Ancillary Services when the undeliverable Ancillary Services capacity is not replaced by the QSE, and when such events have occurred more than three times in a month, aggregated for all such events that occur in the month. 04/06/2011 ERCOT No, 6.7.2, 8.1, Rejected
NPRR363 Revision to EEA Level 2B ERCOT Requirements During the EILS VDI This Nodal Protocol Revision Request (NPRR) adds an additional requirement for ERCOT to indicate which time period is being dispatched during their Emergency Interruptible Load Service (EILS) Verbal Dispatch Instruction (VDI) to the Qualified Scheduling Entity (QSE) Hotline during EEA Level 2B. 05/04/2011 APX Power Markets No Rejected
NPRR367 Shaping of PTP Options Taken to Real-Time to Match Forecasted Load This Nodal Protocol Revision Request (NPRR) requires an Entity taking Point-to-Point (PTP) Options to Real-Time to shape the volume of the instruments to follow its Load forecast. 05/12/2011 CPS Energy Yes Rejected
NPRR368 Clarification of the Purpose of Point-to-Point Options The proposed addition would explicitly state the intention of Point-to-Point (PTP) Options going to Real-Time is to hedge Non-Opt-In Entities (NOIEs) serving their Load. 05/12/2011 CPS Energy Yes 4.4.5 Rejected
NPRR386 Reduce the Frequency of Unregistered Distributed Generation Reports At the May 10, 2011 COPS meeting, Market Participants expressed interest in reducing the frequency of the unregistered DG reports. Section 16.5 currently requires ERCOT to produce quarterly reports based on the quarterly reports filed by Non-Opt-In Entities (NOIEs). Based on the last report published for Q1 of 2011, the maximum capacity of unregistered DG in any Load Zone is less than 1.4 MW. The amount of man hours spent by ERCOT and Market Participants to collect and report this data will be reduced significantly if the reports are required annually rather than quarterly. 06/15/2011 Harika Basaran on behalf of COPS No 10.2.2, 16.5, Rejected
NPRR418 Reporting of Resource Forced Outages This Nodal Protocol Revision Request (NPRR) will require all Resource Forced Outages to be entered into the Outage Scheduler. 10/05/2011 ERCOT No, Rejected
NPRR440 Consideration of Generation Availability in RMR Analyses The Nodal Protocol Revision Request (NPRR) modifies provisions that relate to Reliability Must-Run (RMR) analysis to ensure generation availability is assessed by ERCOT in RMR evaluations over at least a five year planning horizon. 01/30/2012 Paul Rocha on behalf of CenterPoint Energy No 3.14.1, Rejected
NPRR444 Supplemental Reliability Deployments Generation and Load Resources deployed for reliability purposes often result in market distortions that artificially lower prices when market conditions would call for prices to be at a higher level. This Nodal Protocol Revision Request (NPRR) works to remove those influences from the market for more accurate price formation. 02/22/2012 Morgan Stanley Capital Group Yes,, 4.4.11, 6.3,,, 6.6.12 (new), (new), (new), (new), (new), (new), (new), (new), (new) Rejected
NPRR494 Load Resource Proration Report This Nodal Protocol Revision Request (NPRR) provides a report of the amount of Responsive Reserve (RRS) procured from different types of Resources, as well as the hourly proration quantity in the Day-Ahead Market (DAM) of Load Resources on high-set under-frequency relays. 10/29/2012 MIS User Group No 4.5.3 Rejected
NPRR508 Setting of Real-Time LMPs During EEA ERS/Load Resource Deployment This Nodal Protocol Revision Request (NPRR) will administratively set Locational Marginal Prices (LMPs) at the System-Wide Offer Cap (SWCAP) during Security-Constrained Economic Dispatch (SCED) executions in which ERCOT has deployed Emergency Response Service (ERS) Resources and/or Responsive Reserve (RRS) Service supplied by Load Resources. 12/06/2012 GDF Suez Marketing NA No 6.3,,, 6.6.12 (new), (new), (new) Rejected
NPRR537 ERS Clearing Price This Nodal Protocol Revision Request (NPRR) modifies Section to provide that Emergency Response Service (ERS) offers will be awarded at the market clearing price rather than on a pay-as-bid process. 04/19/2013 DSWG No, Rejected
NPRR544 Energy Offer Curve Requirements for Generation Resources Assigned Non-Spin Responsibility This Nodal Protocol Revision Request (NPRR) adds a requirement for the Energy Offer Curve to be offered above a linear curve that starts at $120 and ends at $3,000. If the Ancillary Service Resource Responsibility for Non-Spinning Reserve (Non-Spin) is reassigned to a Generation Resource during the Adjustment Period in accordance with Section 6.4.6, QSE-Requested Decommitment of Resources and Changes to Ancillary Service Resource Responsibility of Resources, the Qualified Scheduling Entity (QSE) shall submit an Energy Offer Curve that meets the requirements of Section for the Generation Resource’s newly assigned Ancillary Service Resource Responsibility for Non-Spin prior to the end of the Adjustment Period. If the Ancillary Service Resource Responsibility for Non-Spin is reassigned in accordance with Section 6.4.6 from a Generation Resource that experiences a Forced Outage, Derate, or Startup Loading Failure during the Operating Period, the QSE shall submit an Energy Offer Curve that meets the requirements of Section as soon as reasonably practicable after the event. QSE updates to an Energy Offer Curve entered at the end of the Adjustment Period become effective in ERCOT systems at the next Operating Period. Therefore, if Non-Spin is moved from one Generation Resource to another in the QSE's portfolio during an Operating Hour, any change to the Energy Offer Curve will be effective in the next Operating Period. There will not be any validation rules to verify the requirements added by this NPRR. The onus is on all QSEs to make the submission/telemetry changes needed to implement these new requirements. 05/14/2013 GDF Suez NA No Rejected
NPRR574 Removal of Offer Curve Flexibility for DAM-Committed Resources This Nodal Protocol Revision Request (NPRR) reverses the ability of a Qualified Scheduling Entity (QSE) representing a Resource(s) to make intra-day changes to the Resource’s Energy Offer Curve if it has been committed by the Day Ahead Market (DAM). 10/23/2013 Mercuria Energy America No Rejected
NPRR582 Refinements to Testing ERS This Nodal Protocol Revision Request (NPRR) establishes a limit on the number of MW that ERCOT can test for Emergency Response Service (ERS) at any particular point in time. As ERS grows in MW, types, distribution, and use by ERCOT, the potential impact created by testing ERS grows. The intent of this NPRR is to balance the needs for testing to validate parameters for ERS as set forth in the Protocols and Other Binding Documents, while recognizing that ERCOT-instructed interruption of Load for testing purposes can impact Real-Time energy price formation. 11/13/2013 Edison Mission No Rejected
NPRR605 Ancillary Service Make-Whole Payments Under a Watch This NPRR requires ERCOT to implement a Make-Whole Payment for Qualified Scheduling Entities (QSEs) that are unable to hedge the cost of serving Load due to a reassignment of capacity from energy to Ancillary Services that could occur under a Watch. Starting June 1, 2014, the Real-Time Locational Marginal Price (LMP) will be capped at $9,000 (including the Option B+ adder), and Day-Ahead offers will be capped at $7,000. If a Market Participant believes there is a certainty that Real-Time LMPs will go to the cap, it is unlikely to offer all its generation at a $2,000 discount in the Day-Ahead Market (DAM) to the price it has to pay for its Loads and energy trades exposure in Real-Time. This includes Ancillary Services. A generator would choose to receive $9,000 Real-Time LMPs over $7,000 Day-Ahead Market Clearing Prices for selling Ancillary Services. This could lead to a situation whereby ERCOT cannot procure enough Ancillary Service to meet its Ancillary Service Plan. It can issue a Supplementary Ancillary Service Market (SASM), but this has the same problem in that the SASM offer cap is $7,000, which could be lower than Real-Time energy price. Thus the only alternative left to ERCOT to meet its North American Electric Reliability Corporation (NERC) requirements of spinning reserves is to Reliability Unit Commitment (RUC) units for Ancillary 03/17/2014 Exelon Generation Yes 2.1,, 6.7.5, 6.7.6 Rejected
NPRR627 Augmented ORDC to Include Reliability Factor Methodology The Nodal Protocol Revision Request (NPRR) introduces the reliability factor which will be used to augment the ORDC to place a higher value on Real-Time operating reserves during defined periods of increased system risk to adequately price the increased risk; and provides the process for modifying the methodology used to determine the reliability factor. The price after the addition of the Real-Time On-Line Reserve Price Adder to Locational Marginal Prices (LMPs) approximates the pricing outcome of Real-Time energy and Ancillary Service co-optimization since the Real-Time On-Line Reserve Price Adder captures the value of the opportunity cost of reserves based on the defined ORDC and adjusted for the reliability factor. The reliability factor methodology requires ERCOT to provide advance notice prior to modifying the reliability factor for an Operating Day and advance posting of the reliability factor for the applicable Operating Day to the Market Information System (MIS). The timing values are represented as "X" and will be determined through the stakeholder process prior to approval of this NPRR. 05/19/2014 GDF SUEZ Energy NA No Rejected
NPRR667 Ancillary Service Redesign This Nodal Protocol Revision Request (NPRR) improves Regulation-Up Service (Reg-Up) and Regulation-Down Service (Reg-Down); and replaces Non-Spinning Reserve (Non-Spin) and Responsive Reserve Service (RRS) Ancillary Services with a combination of four new Ancillary Services: Fast Frequency Response Service (FFRS), Primary Frequency Response Service (PFRS), Contingency Reserve Service (CRS), and Supplemenetal Reserve Service (SRS). 11/18/2014 ERCOT No This NPRR includes dozens of changes within Sections 2, 3, 4, 6, 8, and 9 of the Protocols. Please see the NPRR submission form under "Key Documents" for a complete list of impacted Sections. Rejected
NPRR751 Clarifications for Distributed Generation Resources This Nodal Protocol Revision Request (NPRR) updates the definition of Distributed Generation (DG) and creates a definition for Aggregate Distributed Generation (ADG). 01/21/2016 SunPower / GDF Suez No 2.1 and 2.2 Rejected
NPRR784 Mitigated Offer Caps for RMR Units This NPRR establishes a process to set the Mitigated Offer Cap for RMR Units that is consistent with the adopted policy of ensuring that out-of-market units do not interfere with market outcomes. The proposed language provides ERCOT with a flexible process to set and update a Mitigated Offer Cap for RMR Units that allows Security-Constrained Economic Dispatch (SCED) to Dispatch RMR Units for congestion as far back in the Dispatch order as possible but well below the System-Wide Offer Cap (SWCAP). The value of the Mitigated Offer Cap for RMR Units, and any subsequent changes, will be communicated to Market Participants through a Market Notice. 06/01/2016 NRG Texas Yes and 5.6.1 Rejected
NPRR798 Additional CRR Accounts Request The Nodal Protocol Revision Request (NPRR) requests ERCOT to provide Market Participants with additional and unlimited Congestion Revenue Right (CRR) accounts. Currently, Market Participants are limited to three CRR accounts. This is becoming a limitation for BP Energy Company based on our business structure and needs. 08/24/2016 BP Energy Company No 7.5.2 Rejected
NPRR828 Include Fast Frequency Response as a Subset of Responsive Reserve This Nodal Protocol Revision Request (NPRR) introduces Fast Frequency Response (FFR) as a subset of Responsive Reserve (RRS). FFR is designed to support frequency at 59.8 Hz instead of 59.7 Hz leaving existing Load Resources other than Controllable Load Resources providing RRS intact at 59.70 Hz so that they will have higher probability of being available for the next worst event. Once deployed, FFR can reset in 15 minutes and be ready for the next event. 04/26/2017 E.ON No 2.1, 2.2, 3.9.1, 3.17.2, 3.18,,,,,,,,,,,,, and Rejected
NPRR848 Separate Clearing Prices for RRS This Nodal Protocol Revision request (NPRR) will create separate pricing for Load Resources and Primary Frequency Response capable Resources providing Responsive Reserve (RRS) Service. 09/26/2017 Morgan Stanley No 4.5.1, 4.5.3, Rejected
NPRR853 Availability of ERCOT Estimated Interval Meter Data This Nodal Protocol Revision Request (NPRR) codifies the proposed availability of an ERCOT extract providing ERCOT estimated interval data for Advanced Metering System (AMS) meters and Interval Data Recorder (IDR) Meters used in the Settlement process. 11/14/2017 Alliance for Retail Markets (ARM) No 10.12 (reference,) 10.12.1 (reference), 10.12.2 (reference), 10.12.3 (reference), 10.12.4 (new) Rejected
NPRR913 Generator Interconnection Neutral Project Classification This Nodal Protocol Revision Request (NPRR) addresses the neutrality of projects required to interconnect generation to the ERCOT Transmission Grid, and projects for the reliable operation of the generation under particular conditions described in North American Electric Reliability Corporation (NERC) Standard TPL-001-4 – Transmission System Planning Performance Requirements. 12/07/2018 The WInd Coalition No Rejected
NPRR919 Exemption from Governor Primary Frequency Response Control for Certain Resources in Private Use Networks This Nodal Protocol Revision Request (NPRR) allows a Resource in a Private Use Network whose primary function is providing steam to a host, and is not participating in the ERCOT energy market, to be exempted from Primary Frequency Response service requirements. The Governor will still be in service, but may be allowed to be in pressure control instead of Primary Frequency Response control. 01/18/2019 Formosa Utility Venture, Ltd No Rejected
NPRR991 Day-Ahead Market (DAM) Point-to-Point (PTP) Obligation Bid Clearing Price Clarification This Nodal Protocol Revision Request (NPRR) clarifies the impact on the Day-Ahead Market (DAM) Point-to-Point (PTP) Obligation bids awarded when the administrative price floor is introduced. 01/27/2020 ERCOT No 4.5.1 Rejected
NPRR1025 Remove Real-Time On-Line Reliability Deployment Price from Ancillary Service Imbalance Calculation This Nodal Protocol Revision Request (NPRR) amends Sections 6.7.5 and 6.7.6 to remove the Real-Time On-Line Reliability Deployment Price (RTRDP) from Ancillary Service imbalance Settlement. 06/04/2020 Lower Colorado River Authority (LCRA) Yes 6.7.5 and 6.7.6 Rejected
NPRR1056 Market Impact Generic Transmission Constraint (GTC) Notification This Nodal Protocol Revision Request (NPRR) increases transparency with respect to Generic Transmission Constraints (GTCs) with a large market impact. The information released pursuant to Section, Use of Generic Transmission Constraints and Generic Transmission Limits, shall only be accessible to users of the ERCOT Market Information System (MIS) Secure Area. 11/23/2020 Invenergy No and Rejected
NPRR1072 Post Pre-Assigned Congestion Revenue Right (PCRR) Allocation Results to the ERCOT Website This Nodal Protocol Revision Request (NPRR) requires ERCOT to post Pre-Assigned Congestion Revenue Right (PCRR) allocation results to the ERCOT website. 03/31/2021 Yes Energy No 7.5.1 and 7.5.3 Rejected
NPRR1088 Applying Forward Adjustment Factors to Forward Market Positions and Un-applying Forward Adjustment Factors to Prior Market Positions This Nodal Protocol Revision Request (NPRR) removes the Real-Time Forward Adjustment Factor (RFAF) and the Day-Ahead Forward Adjustment Factor (DFAF) from being applied to prior market positions and instead applies the RFAF and DFAF to ongoing market positions. 07/26/2021 Grand Oak Capital Partners, LP No 4.4.10 and Rejected