EIM Settlements Load Customer Training September 13, 2016

Transcription

1 EIM Settlements Load Customer Training September 13, 2016

2 EIM Settlements Customer Training Review EIM 101 EIM terminology Participating / Non-Participating Base Schedules and etags Settlements and Disputes LAP / LMP and Losses Instructed Imbalance Energy Uninstructed Imbalance Energy Timelines Base Schedules Settlements Charge Codes explained Scenarios Additional resources for further information Questions? Appendix 2

3 PSE Fits Into An Expanding CAISO EIM Footprint The CAISO EIM went live with PacifiCorp in November PSE is preparing to join the CAISO EIM on October 1, Benefits are adding up: As of Q2 2016, the EIM's benefits total $88.2 million since the western EIM began on November 1,

4 PSE as EIM Entity is responsible for: Submitting balanced base schedules for all resources, loads, and intertie transactions to CAISO. Resource dispatch Deploying regulation and maintaining BA Area Control Error (ACE) to meet NERC balancing requirements Deploying contingency reserves (Spin, Supplemental Reserves) to meet WECC reliability requirements Keeping CAISO s Outage Management System (OMS) informed of derates and outages. Processing settlement and paying CAISO invoices for imbalance energy for all loads and non-participating resources and allocating applicable charges to transmission customers. 4

5 What Does EIM mean to Load Customers? Today EIM Customer Action Required Metering 15 or 60-minute metering No change. Scheduling E-Tag No change. Settlements Mid-C index day-ahead prices. LAP Hourly prices. Bill Frequency Monthly (around the 4 th of the month for the prior month). Monthly (around the 25 th of the month). *Preliminary weekly data reports for added transparency.* Customers must provide PSE notice of dispute 7 days prior to CAISO T+77B deadline. 5

6 EIM Terminology

7 Participating vs. Non Participating 7

8 Non-Participating Resource Non-Participating Resource Customers will maintain their relationship with PSE and will have limited interaction with CAISO (to submit base schedules). 8

9 Charge Codes EIM Charge Codes CAISO Charge Code Charge Code Description Daily or Monthly Time Interval Load Gen Resource Interchange e-tags EESC (not allocated) Dollar Impact OATT Section FMM Instructed Imbalance Energy EIM Settlement Daily 15 minute X X Large Sch 9, Real Time Instructed Imbalance Energy EIM Settlement Daily 5 minute X X Large Sch 9, Real Time Uninstructed Imbalance Energy EIM Settlement Daily 5 min & hourly X X Large Sch 4,4R, 9, Overscheduling and Underscheduling Charge Daily Hourly X Medium 8.4.1, GMC-EIM Transaction Charge Daily 5 minute X X Medium Sch 1-A Real Time Congestion Offset EIM Daily 5 minute X X Medium Real Time Imbalance Energy Offset EIM Daily 5 minute X X Medium Real Time Marginal Losses Offset EIM Daily 5 minute X X Medium Real Time Unaccounted for Energy EIM Settlement Daily 5 minute X Medium Under Scheduling and Over Scheduling Allocation Daily Daily X Medium Daily Neutrality Adjustment Daily Daily/Hourly X X Small Default Invoice Interest Charge Monthly Daily X Small Default Invoice Interest Payment Daily Daily X Small Default Loss Allocation Daily Daily X Small Financial Security Posting (Collateral) Late Payment Penalty Daily Daily X Small Forecasting Service Fee Monthly Monthly X Small Invoice Deviation Interest Allocation Daily Daily X Small Invoice Deviation Interest Distribution Daily Daily X Small Invoice Late Payment Penalty Daily Daily X Small Flexible Ramp Up Cost Allocation Daily Daily Small Monthly Flexible Ramp Supply Cost Allocation Reversal Monthly Monthly Small Monthly Flexible Ramp Supply Cost Allocation Monthly Monthly Small Monthly Neutrality Adjustment Monthly Monthly X X Small Real Time Bid Cost Recovery Allocation EIM Daily 5 minute X X Small Real Time Imbalance Energy Offset - System Daily 5 minute X X Small Shortfall Allocation Daily Daily X Small Shortfall Allocation Reversal Daily Daily X Small Shortfall Receipt Distribution Daily Daily X Small SMCR -Settlements, Metering, and Client Relations Daily Monthly X X Small Sch 1-A

10 Energy Imbalance Market Pricing Today imbalance is settled at day-ahead Mid-C ICE Index prices. In the EIM: Generation and E-tag Changes Settle at a 5 and 15 minute Locational Marginal Price (LMP). Locational Marginal Price (LMP) Load Changes Settle at an hourly Load Aggregation Point (LAP). Load Aggregation Point (LAP) These examples are not meant to reflect actual resource or load locations. 10

11 EIM Pricing What is LMP? Energy Locational + Congestion = Marginal + Losses Price (LMP) Note: A Greenhouse Gas Component applies to Participating Resources. 11

12 EIM Pricing What is LAP? Average Load of PSE BA = Aggregation LMPs Point (LAP) 12

13 Changed Settlements Components Schedule 1A EIM Administrative Costs Schedule 4 Energy Imbalance Schedule 4R Energy Imbalance for 449 customers Schedule 9 Generator Imbalance Schedule 12 Losses on WA area Currently a component of imbalance charge to 449 customers Schedule 12A Losses on Southern Intertie and Colstrip Attachment O, Section 8 Other EIM Charges 13

14 Washington Area Losses in the EIM 14

15 Imbalance Uninstructed Load The difference between And Is Billed on Charge Code [anything here to use from CAISO training?] Load Base Schedule Meter Uninstructed Imbalance Energy (UIE)

16 Timelines Base Schedules

17 Base Schedules Load and Generators A base schedule, which includes etags, is forecast information for all resources, Interchange and Intrachange. Base schedules are due 7 days before each operating day. Modifications to the base schedule may be made at any time and at least one update must be provided by 10:00 AM on the day before the operating day. Final base schedule submitted no later than 77 minutes before each operating hour. Modifications to base schedule may be made up to 57 minutes before the operating hour. 17

18 Base Schedules 18

19 Base Schedule Timeline Business HR Business MIN T-77 T-60 T-57 T-57 T-40 T-37.5 T-22.5 T-7.5 T-2.5 Submit base schedule 1st sufficiency test results published Update base schedule E-tag deadline Final sufficiency test run FMM run FMM award RTM run RT dispatch :43:00 23:00:00 23:03:00 23:03:00 23:20:00 23:22:05 23:37:05 23:52:05 23:57: :57:05 0:02: :02:05 0:07: :37:05 23:52:05 0:07:05 0:12: :12:05 0:17: :17:05 0:22: :52:05 0:07:05 0:22:05 0:27: :27:05 0:32: :32:05 0:37: :07:05 0:22:05 0:37:05 0:42: :42:05 0:47: :47:05 0:52: :43:00 0:00:00 0:03:00 0:03:00 0:20:00 0:22:05 0:37:05 0:52:05 0:57:05 19

20 Base Schedule Timelines Forecast Data Type Generation Forecast Data Method of Supplying Forecast Data Initial Submission Deadline Update Submission Deadline BSAP T-7 days 10 a.m. before Operating Day Proposed Final Submission Deadline Final Submission Deadline (Financially Binding) T-77 minutes T-57 minutes Interchange & Intrachange Forecast Data (Trans Customers with resources or load in PSE BAA) Interchange Forecast Data (Trans Customers without resources or load in PSE BAA) E-Tags T-7 days 10 a.m. before Operating Day T-77 minutes T-57 minutes E-Tags Not applicable Not applicable T-77 minutes T-57 minutes 20

21 Timelines - Settlements

22 Settlement Calendar CAISO Settlement calendar for EIM Markets o Initial Trade Date (T) + 3 Business Days (B) o Recalculation Trade Date + 12 Business Days o Recalculation Trade Date + 55 Business Days o Optional Recalculation Trade Date + 9 Months (M) o Optional Recalculation Trade Date + 18 Months o Optional Recalculation Trade Date + 35 Months o Optional Recalculation Trade Date + 36 Months o Optional Unscheduled Recalculation Settlement with 30 day notice Note: Resettlements can occur after the 36-month settlement. CAISO recently resettled the first day of MRTU for the third time after the 36-month settlement was posted. 22

23 CAISO Disputes Calendar CAISO supports disputes per the following timeline: Initial Settlement Trade Date (T) + 3 Business Days (B) Not Disputable. Recalculation T + 12 B All disputable except for estimated meter data through T + 26 B. Recalculation T + 55 B All disputable through T + 77 B. Optional Recalculation T + 9 Months (M) Only incremental values are disputable through T + 10 M. Optional Recalculation Trade Date + 18 M. Only incremental values are disputable through T + 19 M. Optional Recalculation Trade Date + 35 M Only incremental values are disputable for 7 calendar days. Optional Recalculation Trade Date + 36 M Not Disputable. Optional Unscheduled Recalculation Settlement with 30 day notice Only incremental values are disputable for 22 business days. 23

24 PSE Customer Disputes CAISO charge code allocation disputes between PSE and a Transmission Customer or Interconnection Customer, (Customer), will be resolved in accordance with the dispute resolution process set forth in PSE s Open Access Transmission Tariff, (OATT). If a PSE Customer disputes a CAISO charge or pass through billed by PSE, the Customer can not dispute the charge directly with CAISO, but PSE can on their behalf. In order for PSE to meet CAISO dispute deadlines, Customers disputing CAISO charges must provide PSE appropriate supporting documentation 7 business days prior to CAISO s deadline of T+77B (77 business days after disputed trade date). documentation to: Trans.Settlements@pse.com Common information requirements for supporting documentation: Trading Day and Settlement Period or Trading Hour(s) Charge Code Detailed description of dispute Supporting evidence in support of suggested correction 24

25 Customer Disputes, continued Notice of dispute between PSE and CAISO is posted on PSE s OASIS within 5 days of initiating dispute with CAISO. Upon resolution of any dispute, PSE will post notice on PSE s OASIS within 5 days of resolution, including nature of resolution and any settlement-related effects of the resolution on other Customers. Further information may be found in PSE s Open Access Transmission Tariff, (OATT), the CAISO Settlements Business Practice Manual and PSE EIM Business Practice Manual, all posted on PSE s OASIS site. 25

26 CAISO Dispute Timeline Statement Published by MO Settlement Dispute Deadline [w/ CAISO] Deadline for Notice to PSE EIM Entity * Settlement Dispute Data T+12B T+26B T+19B All but estimated meter data T+55B T+77B T+70B All T+9M (T+194B) T+10M (T+216B) T+209B Incremental changes only * Submit dispute materials to PSE Trans.Settlements@pse.com 26

27 EIM Charge Codes

28 Charge Code Real Time Uninstructed Imbalance CC Number: Dollar Impact: Large Occurrence: Daily CC Name: Real Time Uninstructed Imbalance Energy EIM Settlement CC Interval: 5 Minute Calculated Against: All Resources and Loads CC Application: All resources and loads, participating and non-participating, will be settled for uninstructed energy charges. All volume differences between hourly demand meter data and the sum of the base schedules will be settled at PSE s hourly LAP. 28

29 Charge Code Over and Under Scheduling Charge CC Number: 6045 Dollar Impact: Medium Occurrence: Daily CC Name: Overscheduling and Underscheduling Charge CC Interval: Hourly Calculated Against: Balancing Authorities CC Application: Overscheduling Penalties Tier 1 Threshold Overscheduled > 5% of Base Schedule volume then Penalty = 25% x RT LAP LMP x All over scheduled volume Tier 2 Threshold Overscheduled > 10% of Base Schedule volume then Penalty = 50% x RT LAP LMP x All over scheduled volume Underscheduling Penalties Tier 1 Threshold Underscheduled < 5% of Base Schedule volume then Penalty = 25% x RT LAP LMP x All under scheduled volume Tier 2 Threshold Underscheduled < 10% of Base Schedule volume then Penalty = 100% x RT LAP LMP x All under scheduled volume 29

30 Metered Demand & Measured Demand Measured Demand Metered demand plus export volumes from PSE Balancing Authority Area. Metered Demand Metered load volumes in PSE s Balancing Authority Area. 30

31 Scenarios

32 Scenario Interchange Assumption 1 PSE BA Assumptions: 1. There is no base schedule (tag) submitted. 2. Meter is 80 MW. 3. LAP is $50. Load, LAP $50 Settlement: 1. All energy is imbalance. 2. Losses are included in LAP. 3. Imbalance = Meter * LAP 80 MW * $50 = $4,

33 Scenario Interchange Assumption 2 POR on PSE BA border Load, LAP $50 PSE BA Assumptions: 1. Base schedule (tag) is submitted prior to T-57 for 75 MW. 2. Meter is 80 MW. 3. LAP is $50. Settlement: 1. Losses on base schedule is paid by the load: 75 MW * loss rate * LAP = 75 MW*2.7%*$50 = $ charge to customer. 2. Imbalance is calculated as: (Schedule less Meter) * LAP = (75 MW - 80 MW) * $50 = $250 charge to customer. 33

34 Scenario Interchange Assumption 3 POR on PSE BA border, LMP $30 PSE BA Assumptions: 1. Base schedule (tag) submitted prior to T-57 for 75 MW. 2. Tag was curtailed after T-57 down to 70 MW. 3. Meter is 70 MW. 4. LMP at POR is $ LAP is $50. Load, LAP $50 Settlement: 1. Losses on base schedule is paid by the load. 75 MW * loss rate * LAP = 75 MW*2.7%*$50 = $ charge to load customer. 2. Load imbalance = Base Schedule Meter. (75 MW 70 MW) * LAP = (75 MW 70 MW) * $50 = $250 payment to load customer. 3. etag imbalance = T-57 etag final etag (75 MW 70 MW) * LMP = (75 MW 70 MW) * $30 = $150 charge to tagging agent. 34

35 Additional Information and Resources

36 How will Settlements billing work? Allocated EIM charges rolled up in Excel by Settlement date and ed weekly to Customers for use in reconciling PSE statement. EIM-only statement sent out by PSE. All other (non-eim) transmission billing follows existing procedure. New Settlements Look for How to Read Your Bill webinars in early

37 Common EIM Acronyms ACE ADS BA BAA BPM CAISO DGAP EESC EIM FMM GMC IIE Area Control Error Automated Dispatch System Balancing Authority Balancing Authority Area Business Practice Manual California Independent System Operator Default Generation Aggregation Point EIM Entity Scheduling Coordinator Energy Imbalance Market Fifteen Minute Market Grid Management Charge Instructed Imbalance Energy 37

38 Common EIM Acronyms - continued ISO LAP LMP LSE MO OASIS PNODE RTD SC SQMD UIE VER Independent System Operator Load Aggregation Point Locational Marginal Price Load Serving Entity Market Operator Open Access Same Time Information System Pricing Node Real Time Dispatch Scheduling Coordinator Settlement Quality Meter Data Uninstructed Imbalance Energy Variable Energy Resource 38

39 Glossary Ancillary Services Balancing Authority Area CAISO Energy Imbalance Market EIM Area EIM Entity Imbalance Energy Instructed Imbalance Energy Load Aggregation Point Services necessary to support transmission capacity while maintaining reliable transmission operation. Collection of generation, transmission and loads within the metered boundaries of the Balancing Authority. (BAA) State-chartered non-profit public benefit corporation and market operator for the Energy Imbalance Market. Real-time market to manage transmission congestion and optimize energy procurement in order to balance supply and demand. (EIM) Combination of PSE s BAA, the CAISO BAA, and the balancing authority areas of any other EIM entities. A balancing authority entering in agreement with the market operator to enable EIM to occur in its balancing authority area. Deviation of supply or demand from Base Schedule, as measured by metered load, metered generation, or real time Interchange/Intrachange schedules. Operational adjustments to Interchange or Intrachange; resource imbalances created by manual dispatch; or adjustment to resource imbalances. (IIE) Set of pricing nodes used for submission of bids and settlement of demand in the Energy Imbalance Market. (LAP) 39

40 Glossary - continued Locational Marginal Price Manual Dispatch Market Operator Measured Demand Metered Demand Pricing Node Uninstructed Imbalance Energy Variable Energy Resource Marginal cost ($/MWh) of serving next increment of demand at that price node, consistent with existing transmission constraints. (LMP) An operating order used to address reliability or operational issues in BAA not addressed through economic dispatch or congestion management. Entity responsible for operation, administration, settlement and oversight of Energy Imbalance Market. (MO) Metered demand plus export volumes from PSE Balancing Authority Area. Metered load volumes in PSE s Balancing Authority Area. Single network node where physical injection or withdrawal is modeled by the Market Operator, used in calculating LMP. (PNode) Difference between base schedule or manual dispatch and meter data; or difference between base schedule and actual hourly load. (UIE) Electricity production from energy source that is renewable, unable to be stored, and has variability beyond control of facility owner or operator. (VER) 40

41 PSE s Transmission Website (OASIS) Tariff Information can be EIM Information found here can be found here EIM Information can be found here 41

42 PSE Information Links PSE s Transmission Website (OASIS) PSE Tariff PSE EIM Business Practice Manual Transmission Settlements box: Trans.Settlements@pse.com PSE EIM box: EIM@pse.com 42

43 CAISO Information Links CAISO EIM Resources: CAISO Business Practice Manual: Imbalance Market 43

44 Questions 44

45 Appendix - Additional Information

46 CAISO Demand Settlement for EIM Entities All loads submit meter data to OMAR. CAISO uses 4 charge codes to perform load settlement for EIM entities: CC 6478 is used to settled all EIM BA imbalance revenue neutrality. CAISO calculates the dollar differences between the instructed and uninstructed energy for all generation, demand and interties in a BA. The net difference is allocated to all demand in the BA. CC is used to account for Unaccounted For Energy (UFE). The difference between metered load and Base Schedule is settled in CC

47 Transmission Congestion in the EIM 47

48 Appendix - Real Time Work Flow

49 Real Time Work Flow What are the major milestones and requirements of the Real-Time Workflow for all three players: Intertie Schedules The EESC is required to aggregated and submit directional Base Schedules to CAISO for all BA Interties by T-75 with any adjustments submitted by T-40. The EESC will need to aggregate tags directionally, apply schedule ramping and submit 5 minute interval volumes to CAISO, including updates, through the upcoming 5 hours. These are referred to as Real-Time Schedules. The EESC will need to aggregate tags directionally after the hour has completed and submit an after the hour flow without ramping on a 5 minute interval basis. These volumes can be update to 168 hours after the hour concludes. Tagged Schedules All pending and approved intertie tags that will be included in Base Scheduling must be submitted and seen by the EESC by T-57 All tags must be submitted and approved by T-20 (note tags after T-57 are subject to imbalance charges). 49

50 Real Time Work Flow EESC BA A typical hourly Real-Time workflow would resemble the following: T - 90 to T - 75 One hour and 30 minutes before the start of the hour The BA will need to calculate Intertie Base Schedules and submit them to CAISO by T-75. o Base Schedules are calculated directionally and may be rolled together to neighboring BAs. o Intertie Schedules used in Base Schedules can be modified until T-57. o Both approved and pending intertie schedules are included in calculating Base Schedules. o CAISO does require group schedules into categories such as Mirror and ETSR besides the standing CAISO E-Tie and I-Tie. 50

51 Real Time Work Flow EESC Balancing Authority A typical hourly Real-Time workflow would resemble the following: (Continued) T - 55 to T minutes before the start of the hour. Items to be completed on or before T 40: Review CAISO s posted balancing results from the T-55 evaluation. Make any last minute Base Schedule balancing changes resulting from changes to forecasts and resource availabilities. Note CAISO s forecasts for VER and Load lock at T-60. Make Base Schedule adjustments for balancing and flexible requirement changes to pass the CAISO tests. 51

52 Real Time Work Flow EESC Balancing Authority A typical hourly Real-Time workflow would resemble the following: (Continued) T - 75 to T - 55 One hour and 15 minutes before the start of the hour. The EESC will need to review CAISO T-75 test results (sufficiency & flex ramp). If changes are desired to the resource plan, typically they are communicated to the affiliate PRSC who would make the changes before they are locked out at T-55. The BA will need to update the Intertie Base Schedules and submit them to CAISO by T-55. Note these Schedules shouldn t change after T

53 Real Time Work Flow EESC Balancing Authority T-40 to T+60 Base Schedule changes are locked at T-40 for the EESC. The EESC will need to provide Real-Time Schedules to CAISO on a 5 minute basis by registered intertie through the next 5 hours. The schedules are aggregated by registered tie with ramping applied. After the hour concludes through T the EESC will need to provide the schedules aggregated, unramped. Although Bids and Base Schedules are locked, the EESC will need to keep CAISO OMS up to date as soon as possible for Non-Participating Resources. OMS data is used in CAISO s clearing engine. The CAISO market clearing engine snaps the data from CAISO s OMS at the time it starts calculating each market run. What can be changed in CAISO s OMS: Outages & Derates Minimum and Maximum Limits Ramp Rates. CAISO starts each PRDT run 37.5 minutes before the start of the 15 minute interval and starts the RTD run 7.5 minutes before the start of the next 5 minute interval. 53