Release User Group Agenda

Transcription

1 Release User Group Agenda August 20th, 2013 Time) 10:00 a.m. 11:00 a.m. (Pacific Web Conference Information URL: Meeting Number: Access Code: Conference Call Information Domestic Call In: (866) International Call In: (216) Access Code:

2 Release User Group Agenda August 20 th :00 a.m. 11:00 a.m. (Pacific Time) Time Topic Facilitator 10:00 10:05 Agenda & ISO Roll call Janet Morris 10:05 10:30 Release Plan Adrian Chiosea Elizabeth Johnston Cindy Blehm Jeff Dawson Jeremy Malekos Kristen Kelley Luai Bseiso Natasha Sodhi Chris McIntosh Eureka Cullado Indu Nambiar LuAnn Rivera Yinka Ajede 10:30 11:00 FERC 764 Implementation Working Group Li Zhou Jeremy Malekos Janet Morris Page 2

3 The ISO offers comprehensive training programs Date September 17 September September 20 Training Introduction to ISO Markets Market Transactions Welcome to the ISO Web Training Training calendar - Contact us - markettraining@caiso.com Page 3

4 Release Plan 2013 Fall 2013 Post Emergency Filing BCR changes / Mandatory MSG is combined with RIMPR-Phase 1 / BCR Mitigation Measures / Bid Floor Cap Commitment Cost Refinements 2013 Ancillary Services Buy-Back PIRP Logic Change FERC 755 Pay for Performance API Report CMRI CRN Report New API Independent Efforts Access and Identity Management RIMS Generation Replacement Requirements for Scheduled Generation Outages Phase 2 GMT Page 4

5 Release Plan 2014 (proposed) Spring 2014 Circular Scheduling FERC Order 764 Compliance / 15 Minute Market / Dynamic Transfers ADS User Interface Replacement RDRP activation / FERC 745 Compliance DRS API Deployment Fall 2014 Energy Imbalance Market (EIM) Full Network Model Expansion Outage Management System Replacement (OMS) Flexible Resource Adequacy Criteria and Must Offer Obligation Subject to further release planning: Contingency Modeling Enhancements Subset of Hours Acceptable Use Policy Flexible Ramping Product idam (simultaneous IFM and RUC) Price Corrections Publishing Expanding Metering and Telemetry Enterprise Model Management System Page 5

6 2013 Release Schedule *Mandatory MSG Market Sim occurs one week per month through October 1 st 2013.

7 MAP-Stage Outages and SIBR-Lite MAP-Stage will be unavailable for external access from August 1-26, 2013 The ISO intends to keep SLIC available during this outage (may experience a short maintenance window) SIBR-Lite will be re-instated as of August 1, 2013 and will be installed with the Production version of SIBR Page 7

8 2013 SLIC JDK 1.7 Support What to Expect: SLIC web client support for all Java versions including JDK 1.7 SLIC RTAM client support for all Java versions including JDK 1.7 Fix for Password could not be saved error that occurs during the Configure Client Password step of the web client installation process Target Date: Mid-August 2013 Impact to Users: There is no mandatory action required of users Users will be able to upgrade to JDK 1.7 and then re-install the SLIC web and/or RTAM client Installation steps will remain the same and can be found on caiso.com: Page 8

9 Fall 2013 RIMPR Phase 1 / BCR Mitigation / Bid Floor Application Software Changes Implementation Impact Assessment IFM/RTM: Energy Bid Floor to -$150/MWh MQS: Modify MLC calculation and cost allocation rules. Change DA MLC determination Program PUIE calculation (may need to change MQS energy algorithm) Split netting between DA and RT markets. Settlements: Requires a tune-up on formulas to determine the ON criteria for resources, and the eligibility for Bid Cost Recovery. Modify and build up to 12 charge codes to implement new BCR netting rules and MLC. Program PUIE (persistent UIE) calculation. Program new RT PM (performance metric) calculation. Offset DA MLC by MLE revenues. Develop a number of BCR mitigation measurements SIBR: SIBR rule changes will be needed to change the bid floor from -$30 (soft) to -$150 (hard). CMRI: RTM to publish all advisory schedules including current and next hour in the horizon for RTPD runs Post relevant startup or transition time period for each startup cost or transition cost period from MQS in the commitment cost report Post energy allocation based on the default energy bid Post relevant startup ramp time or transition ramp time periods from MQS Monthly Market Reports incorporating greater granularity in reporting BCR components have been made available. Page 9

10 Fall 2013 RIMPR Phase 1 / BCR Mitigation / Bid Floor Milestone BPM Changes Business Process Changes Board Approval Date Settlements & Billing, Market Operation, Market Instrument Manage Billing and Settlements, Market Performance Bid Floor and BCR netting: December 15-16, 2011 Post Emergency BCR / Mandatory MSG: Feb 15, 2012 BCR Mitigation Measures: December, 2012 External Business Requirements April 19, 2013 (Post Emergency BCR posted on Feb 1, 2013) Technical Specifications July 10, 2013 Draft Configuration Guides - draft July 10, 2013 Updated BPMs August 26, 2013 Market Simulation September 10, 2013 September 27, 2013 Tariff filing date Mandatory MSG Filed July 30, 2013 RI-MPR August 28, 2013 Production Activation November 1, 2013 Page 10

11 Fall 2013 Commitment Cost Refinement Milestone Application Software Changes BPM Changes Business Process Changes Date Masterfile: Adding the Min. Load, Startup Major Maintenance Adder (MMS) and Grid Management Charge (GMC) to the projected proxy calculations. Settlements: Operational Flow Orders, NOx, and Sox penalties must be submitted ex post under circumstances attributable to exceptional dispatch and real-time commitments. These costs will be included in a re-evaluation of the real-time BCR calculation for that day with the Operational Flow Orders (OFO) costs added into the calculation of the generator s net shortfall or surplus over that day. The long-term service agreement costs refer to the major maintenance costs. The ISO is working with POTOMAC to develop a template and will share the template with Stakeholders at first quarter of Market Instruments Billing & Settlements Manage Reliability Requirements Board Approval May 2012 External Business Requirements April 30, 2013 Updated BPMs August 26, 2013 Market Simulation August 26, 2013 September 13, 2013 Tariff filing date August 23, 2013 Production Activation November 1, 2013 Page 11

12 Fall 2013 AS Buy Back Milestone Application Software Changes Description/Date RTM: Operators will have the ability to manually force a buy back due to resource or transmission constraints. Settlements: Settlements will need to map to the new payload element that will indicate the reason for disqualification. Fourteen Charge Codes related ancillary services are impacted. MQS will need to correct the new output from RTM BPM Changes Business Process Changes Settlements & Billing, Market Operations N/A Board Approval July 13, 2012 External Business Requirements February 28, 2013 Updated BPMs N/A - explained in procedures 1210 and 2210 Technical Specifications N/A Draft Configuration Guides July 10, 2013 Tariff Filed January 3, 2013 Approved Thursday June 27, 2013 Market Simulation August 26, 2013 September 13, 2013 Production Activation November 1, 2013 Page 12

13 Fall PIRP Logic Change Milestone Date Application Software Changes BPM Changes Business Process Changes RTM: Dispatch VER based on its economic energy bid with the forecast as its Pmax. PIRP: Provide the hourly PIRP forecast for RTM. Determine if the PIRP hourly eligibility in UIE monthly netting based on PIRP s RTM DOT and the hourly forecast For the PIRP unit and/or hours that continues to use self schedule to participate, the existing production logic stays the same Settlements: Continue to perform PIRP resource monthly UIE netting based on the hourly eligibility determined by PIRP. Market Operations, Market Instrument Manage Billing and Settlements, Market Performance Board Approval May 15, 2013 External Business Requirements May 20, 2013 Technical Specifications Not Applicable Updated BPMs August 30, 2013 Market Simulation August 26, 2013 September 13, 2013 Draft Tariff Production Activation November 1, 2013 August 9, 2013 ( ProductReview-BCRMitigationMeasuresTariffCallAug22_2013.htm) Slide 13

14 Fall FERC Order 755 pay for performance Milestone Description/Date Emergency BPM Changes See PRR 673 System Mileage Production Report UI Jul 1 deployment to production System Mileage Production Report API Fall 2013 Technical Specification Jul 15 OASIS API technical specification Business Process Changes DATA MILEAGE REQUESTS AS Certification AGC signal certification process Submit mileage data requests through CIDI - Due to resource limitations, the maximum data request will be for one trade date,for one resource, per SC, per month.

15 Fall 2013 Release - CMRI APIs (RIMPR & CRN) Market notice: Page 15

16 Fall 2013 Release - CMRI APIs (RIMPR & CRN) Market notice: Page 16

17 Fall 2013 Release - CMRI APIs (RIMPR & CRN) Technical docs posted: CMRI Fall 2013 Interface Specifications document CMRI Fall 2013 Artifacts Package Market participants currently utilizing the ISOCommitmentCostDetails and ExpectedEnergyAllocationDetails GoLive API versions or downloading CRN report XML files from the SFTP site must upgrade to the supported versions (preferably the latest v1) to continue retrieving market results from the ISO. Page 17

18 Fall 2013 Release - OASIS APIs OASIS affects: California ISO Demand Forecast report Adding the seven day-ahead (7DA) hourly forecast publication Mileage Calculation Components report New API AS_MILEAGE_CALC available (FERC755) - system performance accuracy, average instructed mileage and system mileage multiplier publication Flex Ramp report Correction of the data element name from MKT_START_HE to INT_OPR_HR on the XML output files Page 18

19 Fall 2013 Release - OASIS APIs Technical docs posted: OASIS Fall 2013 Interface Specifications document OASIS Fall 2013 Artifacts Package _12_0.zip Sample XML Files: Page 19

20 Fall 2013 Market Simulation Plan Fall Release 2013 Market Simulation Plan Posted - nv1_0.pdf Timelines - Kickoff call 8/15 In scope initiates and simulation type 8/27 9/13 AS Buy Back Structured Commitment Cost Refinements 2013 Unstructured RRSGO Phase 2 Annual Unstructured PIRP Logic Change (Includes FERC 755 OASIS AS Report and Load Forecast Report API) - Unstructured In scope initiates and simulation type 9/10 9/27 RI-MPR Phase 1 with BCR-Post Emergency and Mandatory MSG (Includes CMRI CRN API) Unstructured Page 20

21 Access and Identity Management (AIM) Milestone Application Software Changes Date The goal of the AIM project is to improve upon the existing approach for establishing, updating and terminating access to applications as well as providing visibility (transparency), ease of use and self-service where appropriate to POCs (Points of Contact), internal ISO users, business units and IT to manage this process from end to end. AIM: New system with UI and workflow BPM Changes Definitions and Acronyms (For AIM Release 1) Business Process Changes Board Approval IT Access Mgmt. - Certificate based application access; Metering systems access N/A External Business Requirements Jan 31, 2013 Updated BPMs Market Simulation Tariff N/A N/A N/A Production Activation September 9 th, 2013 (Release 1) Page 21

22 2013 RIMS Generation Milestone Application Software Changes BPM Changes Business Process Changes Board Approval Date RIMS Generation module will be changed, including a revamp of the external user interface. Changes include pre-programmed notifications (based on approaching deadlines, status changes, new project creation), canned reporting and ability to push reports to project contacts. External access will be granted with an ability to upload data and attachments directly to the system. Dashboard will be enhanced to provide accurate project statuses, filtering and export functions. N/A Manage New Participating Generator Interconnections N/A External Business Requirements April 10, 2013 Technical Specifications Updated BPMs Market Simulation Tariff N/A because there is no API. However, there will be an external UI for participants, and a user guide related to this UI will be provided before go-live date. N/A N/A N/A Production Activation November 15 th, 2013 Page 22

23 2013 Replacement Requirement for Scheduled Generation Outages Phase 2 (RRSGO P2) Milestone Application Software Changes BPM Changes Next Monthly RR Workshop Date Board Approval July 12, 2012 Updated External Business Requirements IRR: Moving Annual IRR functionality to new CIRA (CAISO Interface for Resources Adequacy) Application Replacement Requirements Resource Adequacy Resource Planned Outage Reporting September 9, 2013, 2:00 pm Posted July 19, 2013 (includes Annual and Monthly) CIRA User Guide Draft Posted August 16, 2013 Training Market Simulation Tariff August 22, 2013 (webinar) August 26 September (unstructured) FERC Compliance Filing December 19, 2012 Request for Rehearing December 19, 2012 MSG Tariff Change for RRSGO Draft Final Proposal Posted August 6, 2013 Stakeholder comments due August 16, 2013 FERC Filing August 30, 2012 Production Activation Annual October, Page 23

24 GMT Milestone Application Software Changes BPM Changes Board Approval External Business Requirements Date OASIS and CMRI All APIs will be provided with GMT option N/A N/A N/A Technical Specifications October 7, 2013 Updated BPMs Market Simulation Tariff N/A November (unstructured) N/A Production Activation December 2013 Page 24

25 Spring 2014 Circular Scheduling Milestone Date Application Software Changes BPM Changes Business Process Changes Masterfile: Creation of new field to capture attestation letter submission. Change to Intertie RDT to allow participants to view the new field. CAS: Identify the circular schedules MW, import/export resource IDs for the single e-tag, with source/sink at the same BAA; the BAA could be CAISO or other BAA; Exclude dynamic, DC segment, open intertie, Wheeling through for load. CRR Claw Back/MQS: Identify the SC s affiliation for single SC and circular schedule MW. Build new rule of calculate value the claw-back CRR in dollars. Settlement: Identify the SC s affiliation for single SC. Identify the circular schedule Import applicable IFM and HASP scheduled MW. Build Settlement rule the settle the import schedule at lower LMP of Import/export. Circular schedule is not eligible for BCR for the interval. Market Operations, Market Instruments, Settlements & Billing Manage Interchange Scheduling, Manage MQS, Manage Billing and Settlements Board Approval March 2012 External Business Requirements March 22, 2013 Updated BPMs December 6, 2013 Technical Specifications Master File - August 2013 Draft Configuration Guides Dec 2013 initial draft Market Simulation Feb 3 Mar 7, 2014 Tariff Filed November 21, 2012 Approved January 30, 2013 Production Activation Spring 2014 (April 1, 2014) Page 25

26 Spring FERC 764 Application Software Changes Implementation Impact Assessment MasterFile: Identify variable energy resources and their selection of using ISO VER forecast or their own VER forecast. IFM/RTM: A new 15-Minute market with financially binding energy and AS awards for internal generators, imports/exports, and participating loads. Real time bid submission process remains same Cleared against the CASIO forecast of real time demand Executed 37.5 minutes prior to the start of the binding interval, 15 minutes earlier than the current 22.5 minute prior to the binding of RTUC run Allow a number of bidding options for an intertie A new hourly process to produce the advisory hourly block schedule for the non-dynamic intertie transaction that will be used for subsequent 15-minute market. Convergence bidding will be allowed on intertie scheduling point. All convergence bids will be settled between the day-ahead market and the 15-minute market The physical only constraint at the scheduling point of the dual constraints not enforced in the IFM but enforced in RUC. RUC establishes the number of etags it can accept for day-ahead physical market awards. 15-minute market and 5-minute market dispatch VER based on its economic energy bid and use forecast as its upper operation limit Support Primary/Alternative ITC for DS/PTG Slide 26

27 Spring FERC 764 Application Software Changes Implementation Impact Assessment CAS: Perform scheduling check-out based on the 15-minute based schedules and tag energy profile Perform the tag update/approval by the hourly deadline T-20 for various intertie bidding options Receive and consume the RUC cleared capacity for day-ahead tagging checkout purpose Receive and consume the RTPD 15-minute schedules for tagging check-out purpose Automatically match retag DS/PTG schedule from the primary ITC to the alternative ITC when the primary ITC become open ADS As the HASP will be replaced the hourly process to accept the block schedule and the hourly process schedule is advisory, no more HASP predispatch schedules will be issued through ADS Settlements: 15-minute energy settlements will be based on the 15-minute schedule and the day-ahead energy schedule. 5-minute energy settlement will be based on the difference of 15-minute schedule and 5-minute dispatch. All metering related settlement will be changed to 5-minute base. Real-time Inter-SC trades based on 15-minute price. Metering: 10-minute metering data changed to 5-minute metering data SIBR: Allow market participants to submit 5-minute VER forecast with a 2-hour lookahead window Allow an intertie various additional bidding options: An hourly block schedule A single curtailment for the remainder of the hour with block schedule Option to determine 15-minute market participation if not accepted in the Slide 27 hourly process

28 Spring FERC 764 Milestone BPM Changes Date Market Operation, Market Instruments Settlements & Billing, Definitions & Acronyms Business Process Changes Manage Master file: Identify variable energy resources and their selection of using ISO VER forecast or their own VER forecast DA and RT processes: A new financially binding 15 minute scheduling market run for import, export, internal resources and loads Settlements: 15-minute market settlement Price Correction and Validation: Price Validation and correction tools and/or proposed MVT tool shall be modified to include 15-minute market Price validation. Interchange Scheduling: Update/approval etag hourly transmission profile and the 15-minute energy profile for various intertie bidding options. Manage Metering: Metering data for settlement for both CAISO ME polled data and SC submitted data are changed to 5-minute. Analysis Dispute and Resolution: expanded to include validation rules and corrections for the 15-minute market solution. Market Performance (MAD/DMM): expanded to monitor market performance related to the 15-minute market scheduling and settlement. Training: Training will be needed to train Operator/Analysts on the 15-minute market scheduling and settlement. Slide 28

29 Spring FERC 764 Milestone External Business Requirements Date Board Approval May 15, 2013 External Data Requirements Specification Technical Specifications May 20 th MasterFile and SIBR May 24 th Metering and Settlements June 3 rd ADS, OASIS and CMRI Complete BRS: June 21, 2013 Jul 22 nd MasterFile, SIBR, ADS, CMRI and OASIS Jul 23 rd RUG walkthrough each application Aug 30 th - SIBR Aug 30 th - MasterFile Sep 16 th OASIS Sep 30 th - CMRI Oct - ADS TBD ADS Framework Oct Metering Draft Updated BPM s Dec 12, 2013 Draft Configuration Guides Dec 2013 initial draft Market Simulation Feb 3 Mar 7, 2014 Draft Tariff Nov 12, 2013 Production Activation Spring 2014 (April 1, 2014) Slide 29

30 Spring 2014 ADS User Interface Replacement Milestone Application Software Changes BPM Changes Board Approval External Business Requirements Technical Specifications Date Port client from Delphi to new common user interface (ADS Query Tool and Real Time Functionality) Conform APIs to current ISO standards None N/A N/A TBD Updated BPMs N/A Market Simulation Feb 3 Mar 7, 2014 Tariff N/A Production Activation Spring 2014 (April 1, 2014) Page 30

31 Spring RDRP Activation / FERC 745 Compliance Milestone Application Software Changes BPM Changes Board Approval External Business Requirements Technical Specifications Date Activation of Reliability Demand Response Product (RDRP) including FERC Order 745 compliance. Metering (re-include what was originally removed) Market Operations Not required See: ndresponseproduct.aspx See slide on DRS API Updated BPMs Dec 2014 Market Simulation Feb 3 Mar 7, 2014 Tariff Aug 19 th, 2013 Compliance filing Production Activation Spring 2014 (April 1, 2014) Page 31

32 Spring 2014 Demand Response System (DRS) API Milestone Application Software Changes BPM Changes Board Approval External Business Requirements Date DRS - Addition of API to support automated registration, and potentially for reporting on baseline and performance. TBD N/A N/A-API will follow existing DRS workflow. Technical Specifications - Registration October 2013 Updated BPMs Market Simulation Registration API Baseline & Performance API Tariff Production Activation Registration API Baseline API Performance API TBD Feb 3 Mar 7, 2014 Feb 3 Mar 7, 2014 (if needed) N/A Spring 2014 Spring 2014 (if needed) Spring 2014 (if needed) Page 32

33 Fall 2014 Energy Imbalance Market (EIM) Milestone Application Software Changes Date Master File: Register EIM entity, EIM resources, EIM resource emission rate, EIM Interties SIBR: Accept and validate submitted EIM resource plan and load base schedule, EIM resource bids. ALFS: Forecast EIM load, EIM VER. EMS: Model updates EIM BAA, model EIM NSI. DAM/RTM: Perform the DCPA for each BAA for the constraint in the BAA and the test and mitigate the resources in the BAA; Decompose the LMP congestion by the constraint belong the same BAA; option for EIM entity unit commitment; All LMPs will not include marginal loss contributions from external network losses; The EIM entity access the interface to submit exceptional dispatch with EIM type ; send the latest valid prior RTD advisory results to EIM when ISO run RTCD. Model Greenhouse Gas (GHG) emission for EIM to ISO; Calculate BAAs transfers; Perform flexible ramping requirement sufficiency test. Meet flexible ramping requirement by BAA and total. MQS: Calculate resource unit contribution on congestion cost for real time congestion balance account. OMS: EIM submission of resource and transmission Outages Settlement: settle 15 minute and 5 minute markets IIE and UIE at LMP ; Calculate EIM LAP hourly volumetric weighted average LMP weighted by the load forecast deviations bounded by the min/max LMPs; Settle EIM administrative cost; create real-time congestion balancing account for each BAA; Collect and allocate underschedule penalty by month. Settle EIM resource BCR. Allocate uplift to the BAA shared by the transfers. Pay the flexible ramping capacity use current formula, allocate the cost prorata to the requirements. CMRI/OASIS/ADS: Publish the market results for EIM BAA and resources. Page 33

34 Fall 2014 Energy Imbalance Market (EIM) Milestone Date BPM Changes Market Operations, Market Instruments, Settlements and Billing Board Approval November 8, 2013 External Business Requirements September 1, 2013 Technical Specifications April 1, 2014 Updated BPMs TBD Market Simulation July 8, 2014 Tariff February 28, 2014 Production Activation October 1, 2014 Page 34

35 Fall 2014 Full Network Model Expansion Milestone Application Software Changes BPM Changes Date Board Approval November 2013 External Business Requirements September 1, 2013 Technical Specifications February 3, 2014 Updated BPMs Master File: Define external BAA scheduling point as Generation Aggregated Point (GAP) and GDF SIBR: Submit and create transaction ID for the SC Bids on Scheduling Points-BAA dynamically; Allow the SC bids at same BAA-SP to bid to different interties. DAM/RTM: Receive the dynamically formed transaction ID attributes from bid, perform contingency analysis for some critical external BAA resources and transmission equipment. Incorporate external BAA critical outages, Enforce both flow and schedule Intertie constraints, Model HVDC line. CRR: CRR market run on expanded Full Network Model. CMRI/ADS/OASIS/Settlement: Receive and process the dynamically formed transaction ID. Market Operations, Market Instruments, Managing FNM TBD Market Simulation July 8, 2014 Tariff TBD Production Activation Fall 2014 Page 35

36 Fall 2014 Outage Management System (OMS) Milestone Application Software Changes BPM Changes Date MPP and OASIS: Modified outage reports posted. OMS: New OMS replaces SLLIC and current OMS (transmission) with a single outage management system. Application Programming Interfaces (APIs) will be modified to support new data structures and functionality, and a new user interface will be provided. Managing Full Network Model Market Instruments Outage Management Market Operations Straw Proposal Posted August 7, 2013 Comments due on Straw Proposal August 20, 2013 Draft Final Proposal Posted September 9, 2013 Stakeholder Comments on Final Proposal Due September 16, 2013 Board Approval November 2013 Page 36

37 Fall 2014 Outage Management System (OMS) Milestone Date External Business Requirements Posted June 28, 2013 Technical Specifications Posted November 1, 2013 Business Process Changes Manage Generation Outages Manage Transmission Outages Updated BPMs September 2014 Market Simulation July 8 July 29, 2014 Tariff ~ August 2014 Production Activation October 1, 2014 Page 37

38 TBD - Acceptable Use Policy Milestone Application Software Changes BPM Changes Board Approval External Business Requirements Technical Specifications Updated BPMs Market Simulation Tariff Production Activation Date Currently Planning to do a proof of concept and based on results, implementation and technical solution will be communicated through TUG & RUG. This policy will impact all external applications. N/A N/A N/A N/A N/A TBD N/A TBD Page 38

39 Release User Group Agenda July 23rd, :00 a.m. 11:00 a.m. (Pacific Time) Time Topic Facilitator 10:00 10:05 Agenda & ISO Roll call Janet Morris 10:05 10:30 Release Plan Adrian Chiosea Elizabeth Johnston Cindy Blehm Jeff Dawson Jeremy Malekos Kristen Kelley Luai Bseiso Natasha Sodhi Chris McIntosh Eureka Cullado Indu Nambiar LuAnn Rivera Yinka Ajede 10:30 11:00 FERC 764 Implementation Working Group Li Zhou Jeremy Malekos Janet Morris Page 39

40 FERC Order 764 Market Changes Readiness The ISO will help participants track implementation efforts and share their needs for readiness support The Release Users Group (RUG) bi-weekly call will be used for this purpose All stakeholders are invited to participate RUG discussions focus on the proper level of technical detail for the FERC Order 764 project Slide 40

41 Spring FERC 764 Item Review Interchange Scheduling process Business Process review Spring 2014 Market Simulation Open Discussion Action Interchange Scheduling Presentation Li Zhou Sep 3 rd Variable Energy Resource Forecast Certification Process Dec 15 th 2013 SIBR Lite available to MP s Jan 27 th Jan 31 st, 2014 Map-Stage connectivity testing Feb 3 rd, 2014 Market sim begins 6 week duration Mar 14, 2014 Market Sim ends Slide 41

42 FERC Order 764 Inter-Tie Tagging Li Zhou Power System Technology Development August 19, 2013

43 Day-Ahead Tagging 1. No Change for Timeline 2. Tags based on RUC Capacity Schedule, not IFM schedule Page 43

44 Hourly Process for Real-Time Market T-75: Real-Time Bid Submission Deadline T-52.5: HASP DOTs issued through ADS and Advisory Schedules through CMRI T-47.5: MPs can accept/partial accept/decline HASP Schedules in ADS (default to accept) T-20: Intertie Transmission Profile for the hour and Energy Profile for the first 15-minute T T = Start of the HASP Hour No Energy Schedules are Financially Binding from Hourly Process Page 44

45 Tagging based on Different Options (Hourly Process) 1. Self-scheduled hourly block 2. Self-scheduled variable energy resource forecast 3. Economic bid hourly block 4. Economic bid hourly block with single intra-hour change 5. Economic bid in 15-minute market 6. Dynamic Transfer When submitting real-time bids, market participants need only to specify hourly (or Not) and/or single intra-hour change (or Not) options. The rest of options are derived based on bid/self schedules and MF definitions. CAISO will show these derived options to market participants. Page 45

46 Tagging based on Different Options (Hourly Process) 1. Market Participants will continue to get HASP Hourly DOT from ADS 2. Decline is based on, for Self-scheduled hourly block, Economic bid hourly block, Economic bid hourly block with single intra-hour economic schedule change, and Economic bid with participation in 15-minute market SC shall be allowed to specify a MW value from 0 to max (RUC Schedule, the HASP schedule) 3. The SC specified value shall be fed back to RTM in the following RTUC/RTD runs. And this value shall be used to update the market energy award in CAS Page 46

47 Tagging based on Different Options (Hourly Process) T-20 Tag for HOUR beginning at T Transmission and energy profiles shall be tagged according to the rules depending on options (slides 9 15) Transmission profile is hourly and set by T-20 before the hour. It will be used for subsequent RTPD run as the maximum capacity Energy Profile can be 15-minute base and is set by T-20 for the first 15-minute of the hour Page 47

48 15 Minute Process for Real-Time Market T-37.5: RTPD Optimization Starts T-22.5: RTPD clears and CAISO automatically updates energy profile T-20: Market Participants can update energy profile by T Minutes Financially Binding T Binding 15-minute 37.5 Minutes T = Start of the binding 15-minute Page 48

49 Tagging based on Different Options (RTPD) Energy profile will be updated starting 22.5 minutes before the start of 15-minute interval CAISO will use RTPD 15-minute schedule to automatically update the energy profile by 22.5 minutes before the start of 15-minute interval; Market Participants can update the 15-minute energy profile between 22.5 and 20 minutes before the 15- minute interval. Subsequent RTD runs will dispatch inter-tie schedules to check-out energy profile except dynamics (as in production) Page 49

50 Tagging based on Different Options - Self-scheduled hourly block T-20 (before the Hour) Tag Transmission profile = hour ahead process schedule Energy Profile = hour ahead process schedule On 15-minute base, T-20 (before the 15-minute interval) Energy Profile can be updated intra-hour due to reliability curtailments Page 50

51 Tagging based on Different Options Self-scheduled variable energy resource forecast T-20 (before the Hour) tag, Transmission profile = maximum 15-minute interval from hour ahead process Energy Profile = 15-minute market schedule On 15-minute base, T-20 (before the 15-minute interval) Energy Profile updated Page 51

52 Tagging based on Different Options Economic bid hourly block T-20 (before the Hour) Tag Transmission profile = hour ahead process schedule Energy Profile = hour ahead process schedule On 15-minute base, T-20 (before the 15-minute interval) Energy Profile can be updated intra-hour due to reliability curtailments Page 52

53 Tagging based on Different Options Economic bid hourly block with single intra-hour increment T-20 (before the Hour) Tag Transmission profile >= hour ahead process schedule Energy Profile = hour ahead process schedule unless changed in first 15-minute market If 15-minute market increments or decrements, then Energy Profile is updated 20 minute prior to flow and remains unchanged for balance of hour Page 53

54 Tagging based on Different Options Economic bid in 15-minute market T-20 (before the Hour) Tag Transmission profile >= maximum MW bid submitted Energy Profile = 15-minute market schedule On 15-minute base, T-20 (before the interval) Energy Profile can be updated based on RTPD schedules Page 54

55 Tagging based on Different Options Economic bid with participation in 15-minute market only if cleared in hourly process for block schedules This option will not be explicitly indicated At T-20 (before the Hour) Tag, if market participants do not put in transmission profile due to zero HASP schedule, subsequent RTPD will clear at zero. Page 55

56 Tagging based on Different Options Dynamic Transfer T-20 (before the Hour) Tag Transmission profile >= maximum MW bid submitted Final Energy Profile will be updated in the hour after scheduling hour (Dynamic Tag) Page 56