Price-Responsive Demand (PRD) Project

In this section

Project Overview

Project Implemented: 6/1/18

Under the PRD project, ISO New England completed the full integration of demand-response resources (DRRs) into the region’s wholesale electricity markets, allowing Market participants and demand designated entities (DDEs) with demand response assets to participate in the energy and reserve markets similar to the way generators do. DRRs are now eligible for Forward Capacity Market (FCM) shortage event penalties or credits, and peak energy rents. Affected participants were reminded to refer to the FCM Pay-for-Performance (PFP) Project webpage for related information and system changes that may impact PRD customers.

The PRD project:

Replaced the current real-time demand-response (DR) program
Integrated demand-response actions into the energy and reserve market systems. Specifically DRRs were able to
- Submit offers to day-ahead and real-time markets
- Impact the clearing of other resources, including generators
- Provide reserves
- Set the locational marginal price for the energy market
Modelled DRRs as supply to align their financial characteristics with those of a generator
Introduced the DRR desired dispatch point (DDP), which is a request to reduce consumption by a specified megawatt amount below the megawatt level of expected consumption during the dispatch interval
Allowed one or more demand-response assets (DRAs) to be mapped to a DRR, which may be mapped to an active-demand capacity resource (ADCR), creating a hierarchical interrelation between the entity types
Prohibited DRRs from self-scheduling load reductions that occur as a part of normal business operations
Prevented DRs from reoffering financial parameters during the intraday real-time reoffer period
Introduced the DRR-specific eMarket interface and offer parameters per the DRR tariff definitions and terms
Automated Unit Control Mode (UCM) updates to better determine when DRRs go “on line” and “off line”
Modelled DRRs outside of the network model release to allow for monthly configuration updates
Established DRR aggregation zones that will allow DRAs that are from multiple delivery points and less than 5 MW to be aggregated into a single DRR, provided the delivery points are within a single dispatch zone and reserve zone
Calculated new demand response baselines by:
- Using two additional day types of Saturday and Sunday/DR holidays
- Including the five most recent uninterrupted “like days” in the past 42 days, rather than using non-holiday weekdays, as implemented June 1, 2017
- Substituting days with interruptions if five uninterrupted like days are not available

Required Participant Actions

Affected market participants were required to take specific steps or adapt to changes in ISO Systems, as described below and should be mindful of additional time-bound items, some of which may require customers to take specific steps or adapt to changes in ISO systems after the project implementation date.

Please consider subscribing to Participant Readiness, Market Notices, Information Technology (IT) Notices, and MIS Report Issues to receive notices posted to the ISO calendar for future projects.

TIMING OR DEADLINE	SYSTEM	ACTION OR EVENT
May 15, 2018 - May 21, 2018	eMarket	Participants received June 1 real-time offer templates for their DRRs on May 17th and claim 30 seed values on May 18th. Completed templates were returned by May 21st for offers submitted for the June 1 operating day. If a completed template for a DRR was not received by the deadline the DRR status was “unavailable” on June 1. Please refer to the DRR Offer Template for the June 1, 2018 Operating Day presentation available under the Participant Training Opportunities section for more information.
May, 15 2018	Remote Terminal Units (RTUs)	RTU communication was disabled for the remaining days in May. OP-4 dispatch occurring between May 15 and May 31 was performed manually via a phone call from the ISO NE Control Room Operator directly to the DDE.
June 1, 2018	Remote Terminal Units (RTUs)	At go-live, limits sent via RTU during a dispatch were rounded to the whole MW although offers are made at the tenth of MW. This will not affect the DDP, only the limits sent via RTU. Example: DRR ZSWCT001 has a bid in Max Reduction of 0.2MW. A dispatch of .2 MWs is sent and the DDP is reflected accordingly, however the limits sent via the RTU would be 0.
Beginning mid-May	Citrix ShareFile LLC	Security administrators assigned the Citrix ShareFile LCC / Intercontrol Center Protocol role to users requiring access to XML files PRD_AssetAssociation<DDE>.xml PRD_DDE2ISOConfigTest<DDE>.xml PRD_ISO2DDEConfigTest<DDE>.xml PRD_ResourceAssociation<DDE>.xml PRD_RTUResourceAssetRelationship<DDE>.xml
Q3 2017 through April 2018	Remote Terminal Units (RTUs)	Q3 and Q4 2017: DDEs prepared test RTUs, per the draft of Appendix G, Demand Response Resource RTU Specification, of OP 18, Metering and Telemetering Criteria. Participant Support provided copies upon request of the confidential document. January 2018 to April 2018: Was the testing period for RTUs. RTUs configured to the previous OP 18, Appendix G specification were required to continue to be available for production during the testing period until the go-live in June.
Beginning March 1, 2018	Web services	Participants developed web services to test with application sandboxes, as they became available.
March 1, 2018 (Sandbox) June 1, 2018 (Production)	eMarket	Participants accessed the eMarket sandbox to create day-ahead (DA) and real-time (RT) schedules and portfolios and to test transaction submittals. Refer to the Technical Specifications and Documentation section below for draft guides and web services documentation.
December 2017 through May 1, 2018 April 2, 2018 (Sandbox) May 1, 2018 (Production)	CAMS	Actions performed in the ISO Customer and Asset Management System (CAMS): December 2017: Service area participants designated contacts responsible for confirming pnode information submitted with DRA registrations and responding to ISO inquiries regarding planned and forced curtailments. February 2018: ISO reviewed and confirmed cut-over asset data for production migration. April 2018: Access was allowed in CAMS sandbox to test DRA registration and DRR assignments. May 1, 2018: Access was allowed in CAMS production to register DRAs and process DRR assignments by May 15, 2018, to be effective June 1. Both the pre-PRD and post-PRD CAMS configurations were available during the cut over period. Subaccounts could be assigned to converted DRRs, if desired. LRP contact types were retired. Functionality was added to identify the 10 closest pNodes to a physical address that are in the same state along with the Load, Dispatch, and DR Aggregation Zones associated with that pNode.
To be removed after go-live (Date TBD)	Dispatch Zone Determination	Dispatch zone determination tool will be retired. This functionality was replaced by a new feature in CAMS.
April 2, 2018 (Sandbox) May 1, 2018 (Production) May 1, 2018 (Production) May 29, 2018 (Interval data)	DRMUI	Tested the new asset interval data upload/download and XML functionality. Tested the new resource interval data download and XML functionality. Viewed the new displays for asset interval and performance data. April 28 through May 28 interval data for assets in the May communications model were submitted via DRMUI by May 30, 2018.
April 2, 2018 May 1, 2018 (Production)	DRATT	Deadline to submit new real-time demand response resource audit requests for April via Demand Resource Audit and Testing Tool (DRATT). Requests received after this date would not be scheduled for audit until June.
June 1, 2018	FCTS	New PRD labels were added to the Forward Capacity Tracking System (FCTS) that will also appear in pre-PRD historical views.

Participant Training Opportunities

The ISO conducted online information sessions and other opportunities for affected customers to learn about changes and ask questions in advance of project implementation. Please consider subscribing to ISO Training to receive notices posted to the ISO calendar for future projects.

DATE	EVENT AND SUPPORTING MATERIALS
June 26, 2017 (call #1) September 20, 2017 (call #2) April 17, 2018 (call #3) May 15, 2018 (call #4)	Group conference calls Contacts in CAMS with DR or RTU contact types or application access assigned to their person record for active and previous DR providers were invited to attend. The agenda included: RTU requirements and timeline discussion Draft OP 18, Appendix G (confidential) review Participant-submitted question and answer sessions Cut over activities Sandbox UI and RTU testing progress DRR Offer Template for June 1 operating day The OP 18, Appendix G draft and related presentations wer made available to eligible organizations by contacting ISO Participant Support.
October through December 2017	Invitations were sent to participants to schedule individual calls with ISO personnel regarding RTU requirements.
Quarterly beginning Q3 2017	Quarterly Settlements Issues Forum (QSIF) Link to Q3-2017 Presentation Link to Q4-2017 Presentation Link to Q1-2018 Presentation
Beginning September 2017	Demand Resources Working Group September 27, 2017: Fully Integrated Price-Responsive Demand (part 1) October 23, 2017: Fully Integrated Price-Responsive Demand (part 2) May 2, 2018: DRR Offer Template for the June 1, 2018 Operating Day DRR Dispatch Timelines PRD Timeline and Cutover Implementation May 23, 2018 DRA Meter Issues
March 2, 2018	Demand Resources – Energy Market Offers and Asset Management Training includes an eMarket demonstration and related CAMS task Link to presentation Link to training video
March 22, 2018	Demand Response Registration Training will include CAMS tasks related to DR registration Link to presentation Link to recorded webinar
March 27, 2018	Demand Response Auditing Training will include DR-ATT tasks related to DR auditing Link to presentation Link to recorded webinar
March 29, 2018	Passive Demand Resource Registration and Auditing Training will include PRD-related changes for passive DR Link to presentation Link to recorded webinar
May 22, 2018	PRD – Real-Time Operational Expectations Training for DDRs and DDEs to include response to normal and emergency dispatch instructions, DRR real-time re-submittals, and communications with ISO New England system operators Completion of 2018 ROOT Demand Respose Resources to this webinar is recommended Link to presentation Link to recorded webinar

Please also see the following frequently asked questions (FAQs):

Technical Documentation, Rules, and Procedures

The following documents were provided to market participants affected by the project for specific instructions on completing related tasks or processes and helpful answers to frequently asked questions.

Technical Specifications and Documentation

DOCUMENT	NOTES (if necessary)
MIS report changes March 5, 2018 notice	As part of the project, MIS report descriptions, templates, and sample files were revised for the following reports: Revised reports: IO_UNITRTRSV SR_RTNCPCSTLMNTSUM SD_RTRANSACT5MIN SP_EQR SD_DACLEARED SD_DANCPCPYMT SD_DATRANSACT SD_RSVASTDTL SD_RSVDTL5MIN SD_RTASSET5MIN SD_RTTRANSACT SR_DALOCSUM SR_DANCPCSTLMNTSUM SR_RTCUSTSUM SR_RTCUSTSUM5MIN SR_RTLOCSUM SR_RTLOCSUM5MIN New reports: OI_UNITOPERDRR SD_RTNCPCDRRCS SD_DANCPCDRR SD_RTNCPCDRR5MIN SD_RTNCPCDRRDLOC SD_RTNCPCDRRPYMTHR SD_RTNCPCDRRPYMT5MIN SD_RTNCPCHSDRR SD_RTNCPCREALLOCATE The most recent version of each MIS report can be found on the MIS Report Descriptions, Template, and Samples webpage.
eMarket High-Level Changes effective 6-1-18	eMarket high-level changes for PRD, market open/close timeline changes, and load response retirement
eMarket User Guide	Version 7.2 reflecting capacity resource definition change
eMarket Data Exchange Specification	Version 10.6 updated for PRD
eMarket Web Service Definition v21, effective June 1st, 2018	Updated with changes for PRD
eMarket Client Sample Programs	Version 7 updated for PRD
CAMS User Guide for Demand Asset and Demand Resource Maintenance	Updated with changes for PRD
Demand Resource Audit and Testing Tool (DRATT) User Guide	Updated with changes for PRD
Demand Resource Market Interface User Guide (DRMUI)	Effective 5/1/2018, updated with new XML for querying asset interval data and resource interval data.
DRMUI WSDL	Updated for PRD
Demand Designated Entity (DDE) Registration Forms	DDE registration will be incorporated into the designated entity registration process. Forms to be retired: Demand Designated Entity Registration Form Demand Designated Entity Change Form

Rules and Procedures

DOCUMENT	NOTES (if necessary)
Operating Procedures – link to current, approved procedures Operating Procedure red-lines – link to procedure drafts	Operating procedures to be updated under the PRD project that are available on the ISO website: OP 1, Central Dispatch Operating Responsibilities and Authority OP 1, Appendix A, Assignment of Responsibilities OP 4, Action During a Capacity Deficiency OP 4, Appendix A, Estimates of Additional Generation and Load Relief OP 5, Generator, Dispatchable Asset Related Demand and Alternative Technology Regulation Resource Maintenance and Outage Scheduling OP 5, Appendix A, Operable Capacity Calculations OP 5, Appendix B, Outage Request Form OP 5, Appendix D, Demand Response Activation Analysis OP 9, Scheduling and Dispatch of External Transactions OP 13, Standards for Voltage Reduction and Load Shedding Capability OP 14, Technical Requirements for Generators, Demand Response Resources, Asset Related Demands, and Alternative Technology Regulation Resources OP 14, Appendix B, Generator Reactive Data Explanation of Terms and Instructions for Data Preparation for ISO Form NX-12D OP 14, Appendix C, Demand Response Holidays TO BE RETIRED OP 18, Metering and Telemetering Criteria OP 18, Appendix C, Minimum Accuracy Standards for New and Upgraded Metering, Recording and Telemetering Installations and for Calibration of Existing Equipment OP 19, Transmission Operations OP 19, Appendix K, Operating Voltage Limits by LCC OP 21, Energy Inventory Accounting and Actions During an Energy Emergency OP 23, Resource Auditing OP 23, Appendix J Reactive Capability Audit Waiver Request Form
OP 18, Appendix G, Demand Response Resource RTU Specification (effective June 1, 2018)	Confidential document updated with detailed configuration changes and communications requirements under the PRD project. Contact Participant Support to request a copy of the current draft and the final version when it is available.
Control Room Operating Procedures	Control room operating procedures (CROPs) to be updated with changes under PRD: CROP.10002, Implement Capacity Remedial Actions CROP.10004, Implement Transmission Remedial Actions CROP.24001, Respond to an RTNET Quadrant Alarm CROP.24002, Error or Failure of EMS or an EMS Application CROP.25004, Adjust the Short Term Load Forecast (STLF) CROP.25005, Minimum Generation CROP.25006, Dispatch Using UDS During RTUC Failure CROP.25007, Manual Dispatch CROP.25008, Demand Response CROP.27002, Telemetry and Topology Problems CROP.27004, RTU or ICCP Issue CROP.31002, Curtailing External Transactions CROP.32002, Generation Outages CROP.34001, Double C CROP.34006, Clogger Transmission Constraint and EMSOUT CROP.34009, Nightly Studies CROP.35001, Coordinate PRD Dispatch CROP.35003, Reserve Requirement Adjustment CROP.35005, Dispatch using RTUC and UDS CROP.36002, Redeclarations CROP.36003, Commitment De-Commitment, Self-Scheduling, and Self-Dispatch CROP.45002, Auditing CROP.50005, Capacity Analysis and Morning Report CROP.50009, Shift Items and Security Checklists
System Operating Procedures	System operating procedures to be updated with changes under PRD: SOP-OUTSCH.0010.0020, Scheduling Capability, Claim10/30 and MRR Audits SOP-OUTSCH.0030.0020, Perform Short-Term Outage Coordination SOP-OUTSCH.0030.0040, Perform Long-Term Outage Coordination—Generation SOP-OUTSCH.0040.0010, Create Demand Forecast SOP-OUTSCH.0040.0020, Create Seven-Day Capacity Margin Forecast SOP-RTMKTS.0050.0005, Determine Reliability Commitment for Real-Time SOP-RTMKTS.0050.0010, Perform Reserve Adequacy Assessment SOP-RTMKTS.0050.0030, Produce Forecast Daily Report SOP-RTMKTS.0110.0015, Flagging for RT Market Settlements SOP-RTMKTS.0120.0025, Implement Energy Emergency Actions SOP-RTMKTS.0125.0100, Coordinate CROPs and JTA Administration SOP-RTMKTS.0180.0030, Audit Resource Parameters SOP-RTMKTS.0180.0090, Facilitate Fast Start Change
Master and Local Control Center Procedures	Master and local control center (M/LCC) procedures to be updated with changes under PRD: M/LCC 2, Abnormal Conditions Alert M/LCC 20, Operating Plan for Operating Emergencies M/LCC 21, Total Failure of Energy Management System (EMS)—confidential document; contact Participant Support to request a copy
Transmission Planning Guides PP 5-1 and PP 5-6 red-lines – link to procedure draft PP 10 red-line – link to procedure draft Transmission Planning Technical Guide Appendix C red-lines – link to procedure draft Transmission Planning Technical Guide, Appendix I, Appendix J – link to procedure draft	Current, approved transmission planning guides and associated appendices to be updated with changes under PRD: Transmission Planning Process Guide PP 5-1, Procedure for Review of Governance Participant’s Proposed Plans PP 5-6, Interconnection Planning Procedure for Generation and Elective Transmission Upgrades PP 10, Planning Procedure to Support the Forward Capacity Market Transmission Planning Technical Guide Transmission Planning Technical Guide, Appendix C, Guidelines for Treatment of Demand Resources in System Planning Analysis Transmission Planning Technical Guide, Appendix I, Methodology Document for the Assessment of Transfer Capability Transmission Planning Technical Guide, Appendix J, Load Modeling Guide for ISO New England Network Model
Manuals	ISO manuals to be updated with changes under PRD: M-06, Financial Transmission Rights M-11, Market Operations M-20, Forward Capacity Market (FCM) M-28, Market Rule 1 Accounting M-35, Definitions and Abbreviations M-36, Forward Reserve and Real-Time Reserve M-MVDR, Measurement and Verification of Demand Reduction Values for Demand Resources M-REG, Regulation Market M-RPA, Registration and Performance Auditing

Project Development Materials

Federal Energy Regulatory Commission (FERC) Order 745, Demand Response Compensation in Organized Wholesale Energy Markets
FERC determinations on ISO compliance filings related to Order 745:
ER17-2164-000, Revisions to Implement Full Integration of Demand Response

See more on the Wholesale Markets Project Plan page, the Price-Responsive Demand Key Project page, and the Demand Response Working Group page.