5 4-1-2010 PRR # 189 - Five-Day Price Correction Time Horizon. Changes were made to section 8.1.6.2 of the BPM. 5 4-1-2010 PRR # 201 - Proposed parameter changes for April 1, 2010 Energy Bid Cap increase to $750. Changes were made to sections 2.2.2 and 6.6.5 of the BPM. 6 4-15-2010 PRR # 170 - Market Operations BPM changes related to RTM forbidden operating region (FOR) implementation. 7 5-12-2010 PRR # 132 - Market Operations BPM Updates related to PIRP 7 5-12-2010 PRR # 202 - Update hyperlink to market data 8 6-1-2010 PRR # 213 - Price Corrections Make Whole Payments. A new appendix E was added. 9 6-15-2010 PRR # 215 - Details related to the Forbidden Operating Region (FOR) implementation. Changes were made to sections 7.8.2.4, 7.10.4 and 7.10.4.1. TABLE OF CONTENTS
rare, it can be addressed by setting maximum procurement limits on each of the south of Path 26 AS sub-Region and the north of Path 15 AS sub-Region. Forecasted congestion on Path 15 in the south to north direction simultaneous with north to south Congestion on Path 26. While this scenario is expected to be rare, it can be addressed by setting minimum procurement limits on each of the south of Path 26 AS Sub-Region and the north of Path 15 AS sub-Region. For each of these conditions where congestion is assumed (Items 2 through 7 above), the AS Sub-Region may include the System Resources that are interconnected to that portion of the CAISO Controlled Grid. The determination of whether or not to include the System Resources in the AS Sub-Region depends on the nature of the system conditions, including the expected loading on the Transmission Interfaces that interconnect System Resources to the CAISO Controlled Grid Based on these criteria, there are eight AS Sub-Regions in addition to the Expanded System Region and the System Region, as follows: Exhibit 41: Summary of Initial AS Regions AS Region Name Description of AS Region (set of resources included in AS Region) AS Region Status Internal CAISO Balancing Authority Area Intertie Resources (current Scheduling Points) 1 Expanded System All internal Generators All Active 2 System All internal Generators None Active 3 South of Path 15 All Generators residing South of Path 15 None Active 4 Expanded South of Path 15 All Generators residing South of Path 15 NW3, SR3, NV3, NV4, AZ2, AZ3, AZ5, LC1, LC2, LC3, MX, LA1, LA2, LA3, LA4, LA7 Active 5 South of Path 26 All Generators residing South of Path 26 None Active 6 Expanded South of Path 26 All Generators residing South of Path 26 NW3, SR3, NV3, NV4, AZ2, AZ3, AZ5, LC1, LC2, LC3, MX, LA1, LA2, LA3, LA4, LA7 Active 7 North of Path 15 All Generators residing North of Path 15 None Active
if the instructions to the ISO establish differential priorities among ETC rights. For some ETC rights the ISO may use values below the stated scheduling run range if that is required for consistency with the instructions provided to the ISO by the PTO. Converted Right (CVR) self schedule 5500, 5500 750, -30 A CVR Self-Schedule is assigned the same priority as the typical value for ETC Self-Schedules. Ancillary Service Region Regulation-up and Regulation-down Minimum Requirements 2500 250 In the event of bid insufficiency, AS minimum requirements will be met in preference to serving generic demand, but not at the cost of overloading transmission into AS regions. Ancillary Service Region Spin Minimum Requirements 2250 250 Spinning reserve minimum requirement is enforced with priority lower than regulation up minimum requirement in scheduling run. Ancillary Service Region Non-Spin Minimum Requirements 2000 250 Non-spin reserve minimum requirement is enforced with priority lower than spin minimum requirement in scheduling run. Ancillary Service Region Maximum Limit on Upward Services 1500 250 In the event of multiple AS regional requirements having bid insufficiency, it is undesirable to have multiple constraints produce AS prices equaling multiples of the AS bid cap. An alternative way to enforce sub-regional AS requirements is to enforce a maximum AS requirement on other AS regions, thereby reducing the AS prices in the other regions without causing excessive AS prices in the sub-region with bid insufficiency. Self-scheduled CAISO demand and self-scheduled exports using identified supply resource 1500 750 Pursuant to section 31.4, the uneconomic bid price for self-scheduled demand in the scheduling run exceeds the uneconomic bid price for self-scheduled supply and self-scheduled exports not using identified non-RA supply resources. Self-scheduled exports not using identified non-RA supply resource 1200 750 The scheduling parameter for exports not using identified non-RA capacity is set below the parameter for generic self-schedules for demand. Regulatory Must-Run and Must Take supply curtailment -1125 -30 Regulatory must-run and must-take supply receive priority over generic for supply resources. Price-taker supply bids -825 -30 Generic self-schedules for supply receive
Exhibit 65: RUC Start Up, Minimum Load, & Availability Bid Eligibility Start-Up Costs Minimum Load Costs RUC Availability Bid Participating Generator Cost-Based Or Standing six-month Bid (CAISO Tariff: 30.4, 30.5.2.2) Cost-Based Or Standing six-month Bid (CAISO Tariff: 30.4, 30.5.2.2) RA Capacity = $0 Non RA Capacity is eligible to Bid (CAISO Tariff: 31.5.1.1, 31.5.1.2) Constrained Output Generator (COG) Cost-Based Or Standing six-month Bid (CAISO Tariff: 30.4, 30.5.2.2) Cost-Based Or Standing six-month Bid (CAISO Tariff: 30.4, 30.5.2.2) No RUC Availability Bid permissible; but accounted for in RUC based on Minimum Load cost bid (CAISO Tariff: 31.5.1.1) Resource-Specific System Resource Cost-Based Or Standing six-month Bid (CAISO Tariff: 30.4, 30.5.2.4) Cost-Based Or Standing six-month Bid (CAISO Tariff: 30.4, 30.5.2.4) RA Capacity = $0 Dynamic non-RA Capacity eligible to bid otherwise Other non-RA not eligible to bid into RUC (CAISO Tariff: 31.5.1.1) Non-Resource- Specific System Resource N/A (CAISO Tariff: 30.5.2.4) N/A (CAISO Tariff: 30.5.2.4) RA Capacity = $0 Dynamic non-RA Capacity eligible to bid otherwise Other non-RA not eligible to bid into RUC (CAISO Tariff: 31.5.1.1) Participating Load (using Full Participating Load Model) Not supported initially Not supported initially Not supported Initially Participating (Pump) Load (using model) N/A N/A N/A Non-Participating Load N/A N/A N/A
Execute Real-Time Applications The following Real-Time applications are executed by CAISO after bidding for the market closes: MPM-RRD (hourly) HASP(hourly) – incorporates RTUC #1 STUC (hourly) – incorporates RTUC #2 RTUC (every 15-min) – #3 & #4 RTED (every 5 minutes) RTCD (on demand) RTMD (on demand) The table shown by Exhibit 7-2 summarizes the execution of these applications. Exhibit 72: Real-Time Applications Application Periodicity Interval Time Horizon Task MPM – RRD Hourly Beginning at T-67.5’ 15-min 105 Market Power Mitigation and Reliability Requirement Determination for RTM Bids submitted at T–75’ for the Trading Hour from T to T+60’. MPM-RRD for the Time Horizon from T minutes to T+60’ HASP See Note 1 Hourly Beginning after MPM-RRD 15-min 105 min ’ Hourly pre-dispatch for Non-Dynamic System Resources for the Trading Hour from T to T+60’. Advisory 15-min dispatch for internal resources for the Trading Hour from T to T+60’. Advisory 15-min AS Awards for internal resources for the Trading Hour from T to T+60’. Binding hourly AS Awards for Non-Dynamic System Resources for the Trading Hour from T to T+60’. STUC See Note 2 Hourly Beginning at T – 52.5’ 15-min 270 min Unit Commitment for the Time Horizon from T–30’ to T+240’.