Behind the Meter Generation Common Issues Meeting. September 27, 2016

Transcription

1 Behind the Meter Generation Common Issues Meeting September 27, 2016

2 Purpose Purpose and Key Takeaways Educate stakeholders on behind the meter generation treatment in MISO processes Key Takeaways Processes have evolved over time MISO wants to collaborate with Stakeholders on desired next steps 2

3 Step through the Processes Transmission Planning and Service Resource Adequacy Modeling and Examples Day Ahead and Real- Time Markets 3

4 What is the difference between BTMG and btmg? BTMG references the Module A Tariff definition Lowercase btmg has similar meaning Behind the Meter Generation (BTMG): Generation resources used to serve wholesale or retail load located behind a CPNode that are not included in the Transmission Provider s Setpoint Instructions and in some cases can also be deliverable to Load located within the Transmission Provider Region using either Network Integration, Point- To-Point Transmission Service or transmission service pursuant to a Grandfathered Agreement. These resources have an obligation to be made available during Emergencies. 4

5 CPNodes not included in Setpoint instructions DRR Type 1 Load Zone 5

6 Transmission Planning

7 Planning Sub-processes Generator Interconnection Transmission Service MTEP Generator Retirement

8 Generator Interconnection for BTMG/btmg Similar to any other Generator, a BTMG/btmg needs to go through MISO GI process (Attachment X) only if connecting to MISO Transmission System* Fast track process (Section 14 of Attachment X) for small generators (< 5MW) If a BTMG/btmg is connecting to a non-miso Transmission Facility (or distribution facilities), interconnection customer needs to work with local utility for any evaluation that may be required *MISO Transmission System include Facilities with functional control transferred to MISO through TOA Appendix H and Non-transferred facilities under agency agreement through TOA Appendix G 8

9 Generator Interconnection Products Customer may elect Energy Resource Interconnection Service (ERIS) or Network Resource Interconnection Service (NRIS) ERIS is required in order to connect to the MISO Transmission System NRIS is required in order for a load to use the resource to provide for its Network Integration Transmission Service (NITS) If a Generation Resource connected to the MISO Transmission System desires to be a Capacity Resource for RA purposes, it must either have NRIS interconnection service or ERIS with firm transmission service If a Generation Resource connected to non-miso Transmission Facility desires to be a Capacity Resource for RA purposes, it must procure External NRIS from MISO by entering MISO Interconnection queue (Attachment X) MISO can work with stakeholders to determine interconnection requirements for a BTMG seeking to be a Network Resource for a remote load in the same or different LRZ. 9

10 Transmission Service for BTMG/btmg Transmission customer can use BTMG/btmg as source to procure Transmission Service (PTP or NITS) Typically, customer selects nearest CPNode as source since MISO OASIS has only CPNodes as eligible internal source for Transmission Service Requests (TSRs) Evaluation of Long-term Transmission Service considers BTMG/btmg to the extent that the resources are included in the planning models Long-term TSRs are evaluated using source specific granularity 10

11 Treatment of BTMG/btmg in MTEP MTEP studies explicitly model: All generators with an interconnection agreement pursuant to Attachment X Legacy Designated Network Resources of MISO member utilities All generators that are sources for long-term Firm Point-To-Point Transmission Service Requests Some BTMG may be netted with load when LSE/TO submits load information in planning models. 11

12 What are the appropriate reporting requirements for BTMG/btmg retirement? Currently, there is no requirement for BTMG to notify MISO of its intention to retire. MISO has considered whether some type of notification should be required, and may seek stakeholder input on this issue in the future (no specific timing for this has been contemplated). 12

13 Resource Adequacy

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16 Registering as a BTMG type LMR Submit generator test annually and outage data in PowerGADs application through the Portal Register the BTMG annually in MECT* Assign to load Cpnode w/ same Asset Owner Load Forecast should exclude resource output *MECT is the Module E Capacity Tool 16

17 BTMG type LMR Performance Requirements Must be available and respond per MISO s Emergency Operating Procedures Minimum 12 hour notification time Available 5 times annually during the Summer Runs for at least 4 hours during each implementation Submit status daily in the MISO Communication System (MCS) 17

18 Modeling

19 Model Purpose/goal MISO Modeling Build accurate EMS models that strike a balance between modeling detail and model performance. MISO BA load BA load is calculated in Real time as generation minus tie-lines. MISO Transmission MISO transmission is generally 100kV and above 19

20 BTMG modeling MISO Modeling Explicitly model all generators greater than 5 MW and directly connected to MISO Transmission. (this generation must have telemetry - MW, MVAR, status) Local Balancing Authority load forecast must be calculated with same set of generators present in the MISO model. Practically, should all BTMG be modeled? This would require modeling in much greater detail, the effort of which would exceed the benefit. 20

21 Does btmg need to be registered? If explicitly modeled, the btmg needs to be registered as a DRR Type II or Elemental pricing node of a DRR Type I or Load Zone If not explicitly modeled, the impact of the btmg will be seen through the load zone Registration is required to participate in the Resource Adequacy Construct 21

22 BPM 010 Attachment D Examples 22

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28 Day-Ahead and Real-time Markets

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30 BTMG/btmg Use during Max Gen Events MISO utilizes SO-P-EOP MISO Market Capacity Emergency Procedure to manage Max Gen events BTMG/btmg Expectations during a Max Gen Event Alert/Warning LMR/EDRs update offers in MCS DRR-I and DRR-II update offers in Portal Event Step 1 DRR-I and DRR-II committed Event Step 2 LMR/EDRs committed 30

31 Max Gen Emergency Procedure Progression Tier I Offer Floor Event - Step 1: a) Commit AME b) Implement Emergency Max Limits c) Declare NERC Energy Emergency Alert (EEA) 1 - All available non-emergency resources in use Tier II Offer Floor Event Step 2: a) Declare NERC EEA 2 - Load Mgmt procedures in effect b) Implement LMR (BTMG & DR) & Load Management Measures (LMM) Stage 1 c) Commit Emergency Demand Response (EDR) d) Implement Emergency Energy Purchases Event - Step 3: a) Utilize Operating Reserves b) Instruct load reduction of Load Management Measures (LMM) Stage 2 31

32 How do you verify accounting for BTMG/btmg? BPM 26 describes DRR Performance Assessment in section 4.8 EDR Performance Assessment in section 5.5 LMR Performance Assessment in section 6.3 Appendix A: Consumption Baseline Examples in Section 9 Measurement and Verification Procedures are documented in Sections 6-8 of Schedule 30 for EDRs 32

33 Next Steps Questions? Review Action Items Contacts Kim Sperry Justin Stewart 33