Reserves Scheduling, Reporting and Loading RE Module. Interconnection Training Program PJM State & Member Training Dept.

Transcription

1 Disclaimer This training presentation is provided as a reference for preparing for the PJM Certification Exam. Note that the following information may not reflect current PJM rules and operating procedures. For current training material, please visit: PJM 2014

2 Reserves Scheduling, Reporting and Loading RE Module Interconnection Training Program PJM State & Member Training Dept. 1

3 Agenda Basics Reserve Categories/Terminology IRC Reporting Loading of Reserves Shared Reserve Agreements Appendix 2

4 Basics MW MW Capacity Requirement Operating Reserve Requirement External Bilateral Sales Reserve Generation committed by PJM Pool Scheduled and Committed Energy Requirement PJM OI Load Forecast Self-Scheduled External Bilateral Purchases Requirement 3 Generation Supply

5 Scheduling Reserves On a daily basis, PJM must schedule enough capacity to cover the forecast load plus expected sales of energy off the system and operating reserves RFC Day-ahead Scheduling Reserve VACAR Day-ahead Scheduling Reserve 4

6 Purpose of Reserve Generation Reserve requirements are values of reserve which enable the system to operate reliably and economically while providing protection against load variations, forecast error and equipment failure. Enables control area to restore tie lines to pre-contingency state within 10 minutes of a contingency that causes an imbalance between load and generation 5

7 Agenda Basics Reserve Categories/Terminology IRC Reporting Loading of Reserves Shared Reserve Agreements Appendix 6

8 Reserve Terminology Synchronous Reserve (a.k.a. Spinning Reserve) Increase in output energy level of a synchronized generator which can be attained in 10 min. Or decrease in a Load Response Resource Max energy output achieved in 10 min by a unit operating as a synchronous condenser Quick-start Reserve Not synchronized to system Includes maximum energy output level of a unit that can be attained in 10 min. from the PJM request Generally run-of-river hydro, pumped hydro, combustion turbines, combined cycle and diesel type units 7

9 Reserve Terminology Contingency Reserve (a.k.a. Primary Reserve) Synchronous Reserve - Spinning (Generation) - Customer Demand Response - Quick-Start Reserve All MW available within 10 minutes 8

10 Reserve Terminology Supplemental Reserve (a.k.a. Secondary Reserve) The reserve capability that can be fully converted into energy in >10 to 30 minute interval following a request by PJM Equipment does not need to be synchronized to the system Secondary reserve is tracked and reported in real-time for the entire PJM footprint via Instantaneous Reserve Checks, or IRC s 9

11 Reserve Terminology Operating Reserve Generation available from either offline or online units within 30 minutes Scheduled to meet Operating Reserve requirements in Day- Ahead Market Contingency Reserve + Supplemental Reserve Calculated on an annual basis involving variables that adversely impact system reliability: - Load Forecast Error - Generator Forced Outage Rates Day Ahead Scheduling Reserves = Load Forecast Error + Generator Forced Outage Rates 10

12 Reserve Terminology Load Forecast Error: - Based on a 3-year average of underforecasted load forecast error - Underforecasted LFE can result in capacity deficiencies - Underforecasted LFE is based on the 80 th percentile of the rolling 3-year average - Effective January 1, 2011, the LFE component of the Day- Ahead Scheduling Reserve will be 1.87% 11

13 Reserve Terminology Forced Outage Rate: - Based on a rolling 3-year average of forced outages that occur on the scheduling day (18:00) through the operating day (20:00) - PJM dispatch has the ability to schedule additional reserves during Hot and Cold Weather Alerts - Effective January 1, 2010, the Forced Outage Rate component for the Day-Ahead Scheduling Reserve is 5.23% 12

14 Reserve Terminology Day-Ahead Scheduling Reserve Requirement: - PJM performs the calculations annually during November - Calculations cover a 3-year window from November 1 (year 3) through October 31 (current year) - Reserve calculations are implemented annually on January 1 - Effective January 1, 2011, the Day-Ahead Scheduling Reserve is 7.11% 13

15 Reserve Terminology 0 to 10 Minutes Operating Reserves Contingency Reserve Synchronized Reserves Quick-Start Reserves 10 to 30 Minutes Supplemental Reserve 14

16 Reserve Requirements RRO Control Zone Day-Ahead Schedule Contingency (Primary) Synchronized Reserve Regulation (Operating) RFC Annual % 150% Largest Unit Largest Unit 1% Peak Mid- Atlantic Annual % 1700 MW Largest Unit 1% Peak SERC Dominion VACAR VACAR VACAR 1% Peak ARS % ARS % ARS % 15

17 Dominion Reserve Requirement VACAR Requirements VACAR Contingency Reserve (15 min) Largest Unit in VACAR 1.5 DVP Contingency Reserve (15 min) 422 MW for 2011 VACAR Operating Reserve Peak Load Share (VACAR) DVP Synchronized Reserve (10 Minute) DVP Contingency Reserve (15 min) DVP 15 minute Non-Synchronized Resources 16

18 Agenda Basics Reserve Categories/Terminology IRC Reporting Loading of Reserves Shared Reserve Agreements Appendix 17

19 Instantaneous Reserve Check Instantaneous Reserve Check (IRC) is used to verify reserve situation ALL generators must report their reserve information to PJM when requested Request for IRC data submittal given via PJM All-Call Data submittal for IRC through edart application IRC results used to initiate some emergency procedures IRCs performed at least 3 times per day 18

20 Instantaneous Reserve Check Instantaneous Reserve Check (IRC) reporting will be by PJM Region MidAtlantic Traditional PJM zones Western Region AP, AEP, DPL, ComEd, DLCO Southern Region DVP 19

21 Instantaneous Reserve Check Data Entry Form All regulating and non-regulating reserve values are replaced by the Synchronized Reserve Value Synchronized Reserve is equal to the lesser of: (Synchronized Ramp Rate x 10) Or (Synchronized Maximum Limit Current Output) The Reserve > 30 row will now be hidden East Synchronous Reserve and Load values will not be displayed under Pool Totals For Ancillary Service Markets with only one Control Zone, the Control Zone will be hidden 20

22 Instantaneous Reserve Check Report 21

23 edata Instantaneous Reserve Check Report 22

24 Agenda Basics Reserve Categories/Terminology IRC Reporting Loading of Reserves Shared Reserve Agreements Appendix 23

25 100% Synchronized Reserve Definition Implement 100% Synchronized Reserves and/or Contingency Reserves if the unit loss is equal to or greater than 80% of the largest unit contingency and there is insufficient regulation and economic generation to recover the Area Control Error within the Disturbance Control Standard of NERC 24

26 100% Synchronized Reserve Purpose PJM orders to recover the ACE so that tie line schedules are maintained following disturbance conditions (i.e., loss of generation and/or steam lag) NERC Standards: Control Performance Standard 1 & BAAL Disturbance Control Standard OR To return the reactive transfers or other thermal limitations to within the appropriate limits 25

27 100% Synchronized Reserve Implementation: Request made via the PJM ALL-CALL, Procedures allow for calling of a percentage (25, 50, 75, 100%) of Synchronized Reserve May limit loading of synchronous to certain geographic areas (Eastern PJM, spinning reserve zones) If quick start is required, will also direct its loading 26

28 100% Synchronized Reserve Member Actions: Without regard to price and as quickly as possible, load the requested percentage of Synchronized Reserve (and Quick-Start if specifically requested). PJM Members continue to load generation until directed by the PJM OI dispatcher to discontinue. If regulating units are increased above regulation bands, they MUST be returned to regulation when regulation signal starts to lower from full raise 27

29 Agenda Basics Reserve Categories/Terminology IRC Reporting Loading of Reserves Shared Reserve Agreements Appendix 28

30 Shared Reserves Purpose To assist a neighboring system in recovering from a large sudden loss of generation or energy purchase. To achieve recovery from such a loss faster than otherwise achieved, thereby improving the reliability of the interconnected system 29

31 Shared Reserves PJM Mid-Atlantic Region Manual Reference for Shared Reserve: M-12, Dispatching Operations Manual Section 4 IESO MARITIMES Participants PJM Mid-Atlantic Region ISO New England New York ISO Independent Electricity System Operator (IESO, formerly Ontario Hydro) Maritimes NY-ISO PJM-ISO ISO-NE 30

32 Shared Reserves PJM Mid-Atlantic Region Highlights of the agreement NYISO is plan coordinator Shared reserves involves the use of unloaded on-line capacity (spinning reserves) Can be requested when lost generation is equal to or greater than 500 MW in any amount up to 50% of the loss (300 MW for the Maritimes) Is expected to be delivered within 10 minutes of request; termination is within 10 minutes but no longer than 30 minutes Payback of reserve energy is currently not required 31

33 Synchronized Reserve Markets The current Synchronized Reserve Market has two Synchronized Reserve Zones and one sub-zone RTO Synchronized Reserve Zone Mid-Atlantic Sub-Zone Southern Synchronized Reserve Zone (existing) The limiting factor between the RTO market and Mid-Atlantic Sub-Zone is the AP-South Reactive Transfer Interface This functions the same way the Eastern Sub-Zone did previously but includes the entire Mid-Atlantic region The limits and flows on these will be summed to provide west-to-east transfer capability No changes to the Regulation Market 32

34 RTO Synchronized Reserve Zone DLCO Synchronized Reserve Market Areas ComEd AEP AP Mid Atlantic Synchronized Reserve Sub-zone DAY Control Zone Ancillary Service Region DOM Southern Synchronized Reserve Zone 33

35 Synchronized Reserve Requirements The RTO (except DOM) will have a single requirement DVP will remain separate and will keep the same requirement as today When AP-South transfers are near the limit: Mid-Atlantic Sub-Zone will have a locational requirement Will result in a higher clearing price in the Mid-Atlantic, similar to the old Eastern sub-zone 34

36 Requirements RTO Synchronized Reserve Zone (excluding Dominion) Requirement is the greater of: Calculated RFC minimum requirement OR Largest contingency in RTO Synchronized Reserve Zone Expected to be about 1350 MW (RFC) Mid-Atlantic sub-zone requirement is equal to: Largest contingency in Mid-Atlantic region Normally 1300 MW 35

37 Shared Reserves PJM Southern Region VACAR Reserve Sharing Dominion, Duke, South Carolina Electric and Gas, Progress Carolinas, South Carolina Public Service Authority Telephone request for reserve energy Up to 12 hours PJM schedules delivery between PJM and CPL Dominion Virginia Power Performs billing and provide compensation for energy deliveries 36

38 Operational Considerations Request for Synchronized Reserve in Eastern Reserve subzone is no longer an option If limited on the AP-South Interface, call for Synchronized Reserve in Mid-Atlantic subzone only Be aware of possible over-response as more units will be providing spinning reserve when the RTO Synchronized Reserve zone is called PJM discussing with Operating Committee the use of less than 100% synchronized reserve if this continues to be an issue 37

39 Operational Considerations For loss of unit in Dominion, call for Synchronized Reserve in Southern Synchronized Reserve Zone only If needed, request VACAR reserve sharing Same as existing procedure For loss of a unit in any area other than Dominion, call for Synchronized Reserve in RTO Synchronized Reserve Zone Call only Mid-Atlantic sub-zone if limited on transfer interfaces Initiate the NPCC reserve sharing, if needed For low ACE, call for Synchronized Reserve in Spinning Reserve zone with largest negative ACE Southern Synchronized Reserve Zone OR RTO Synchronized Reserve Region Entire RTO may be requested if needed 38

40 Shared Reserves Summary RTO - Triggers Dominion, RFC, and Mid-Atlantic Sub-Zone RFC - Triggers RFC and Mid-Atlantic Sub-Zone PJM Mid-Atlantic Region Reserve sharing with NYISO, NEISO, IMO, Maritimes PJM Southern Region Reserve sharing with other VACAR members 39

41 Questions? 40

42 Disclaimer: PJM has made all efforts possible to accurately document all information in this presentation. The information seen here does not supersede the PJM Operating Agreement or the PJM Tariff both of which can be found by accessing: For additional detailed information on any of the topics discussed, please refer to the appropriate PJM manual which can be found by accessing: 41