October 30, Secretary. above. that. attached. Folsom, CA. 250 Outcropping Way

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1 California Independent System Operator October 30, 2012 The Honorable Kimberly D. Bose Secretary Federal Energy Regulatory Commission 888 First Street, NE Washington, DC Re: California Independent System Operator Corporation Docket Nos. ER , and EL July 2012 Exceptional Dispatch Report (Chartt 2 data) Dear Secretary Bose: Pursuant to the September 2, 2009 and Mayy 4, 2010 orders in the above referenced docket, the California Independent System Operator Corporation submits the attached report. The attached report provides Exceptionall Dispatch information that the Commission directed be included in Chart 2, which was set forth in Appendix A to the September 2 Order, as modified the Commission s May 4 Order. The attached report provides Chart 2 data for the month of July The attached Chart 2 report also includes the price impact analysiss for the month of July 2012 required by Paragraph 44 of the September 2 Order as well as the degree of mitigation analysis required by ISO tariff section for the month of July Respectfully submitted, By: /s/ Sidney M. Davies Nancy Saracino General Counsel Sidney M. Davies Assistant General Counsel California Independent System Operator Corporation 250 Outcropping Way Folsom, CA Tel: (916) Fax (916) sdavies@casio.com Outcropping Way, Folsom, CA

2 Exceptional Dispa atch Report Table 2: July 2012 ISO Market Analysis and Development Oct 30, 2012 CAISO 250 Outcropping Wayy Folsom, California (916)

3 TABLE OF CONTENTS Introduction... 3 The Nature of Exceptional Dispatch... 3 Appendix A: Explanation by Example Example 1: Exceptional Dispatch Instructions Prior to DAM Example 2: Incremental Exceptional Dispatch Instructions in RTM Example 3: Decremental Exceptional Dispatch Instructions in RTM Appendix B: Price Impact Analysis Appendix C: Exceptional Dispatch Bid Mitigation Analysis LIST OF TABLES AND FIGURES Table 1: Exceptional Dispatches in July Table 2: Instructions Prior to Day-Ahead Market Table 3: FERC Summary of Instructions Prior to DAM Table 4: Incremental Exceptional Dispatch Instructions in RTM Table 5: FERC Summary of ED Instructions in RTM Table 6: Decremental Exceptional Dispatch Instructions in RTM Table 7: FERC Summary of Decremental ED Instructions in RTM Table 8: Price Impact Analysis Information for Pricing Node A in PGAE LAP Table 9: Price Impact Analysis Information for Pricing Node B in SCE LAP Table 10: Bid Mitigation Analysis for July CAISO\MktAnls&Dvpmt Page 2

4 Introduction This report is filed pursuant to FERC s September 2, 2009, and May 4, 2010, orders in ER These orders require two monthly Exceptional Dispatch reports one issued on the 15 th of each month and one issued on the 30 th of each month. This report provides data on the frequency, reasons and costs for Exceptional Dispatches issued in July In addition, this report contains a price impact analysis as prescribed by FERC in its September 2 order. The price impact analysis for the month of July is presented in Appendix B. This report also includes the degree of mitigation analysis for July 2012 required by section of the ISO tariff. As it has previously explained, the ISO indicated that it would start including the degree of mitigation analysis beginning with the month of August 2009 when the more limited Exceptional Dispatch bid mitigation took effect. This analysis will compare those Exceptional Dispatches subject to bid mitigation ( i.e. Exceptional Dispatches to address noncompetitive constraints and Delta Dispatch), and determine the cost difference between the Exceptional Dispatch bid mitigation settlement rules and what the settlement amount would have been had the Exceptional Dispatches not been subject to bid mitigation. The Exceptional Dispatch bid mitigation analysis for July is presented in Appendix C. The Nature of Exceptional Dispatch The ISO can issue exceptional dispatch instructions for a resource as a pre-dayahead unit commitment, a post day-ahead unit commitment or a real-time exceptional dispatch. A pre-day-ahead unit commitment is an exceptional dispatch instruction committing a resource at or above its physical minimum (Pmin) operating level in the day-ahead market. A post-day-ahead unit commitment is an exceptional dispatch instruction committing a resource at or above its (Pmin) operating level in the real-time market. A real-time exceptional dispatch instructs a resource to operate at or above its physical minimum operating point. For the purposes of this report, a real-time exceptional dispatch above the resource s day-ahead award is considered an incremental exceptional dispatch instruction and a real-time exceptional dispatch below the day-ahead award is considered a decremental dispatch instruction. The ISO issues exceptional dispatch instructions primarily to manage transmission constraints that are not modeled in the market software. In addition to constraints, the ISO also issues exceptional dispatch instructions relating to reliability requirements and, on occasion, software failures. Reliability requirements are calculated for both local area and the system wide needs, and are classified into various requirements including local generation, transmission management, nonmodeled transmission outages, ramping and intertie emergency assistance. Whenever the ISO issues an exceptional dispatch instruction, these instructions are logged by the operators into the scheduling and logging system (SLIC), including an associated reason for each exceptional dispatch instruction. CAISO\MktAnls&Dvpmt Page 3

5 In July 2012, the ISO issued exceptional dispatches for the following local area generation requirement: (1) 7630, SCE area generation requirements. Exceptional dispatch instructions were also issued for the following transmission management requirements: (1) 6510, Southern California import transmission (SCIT) nomogram; (2) 6610, Lugo-Victorville 500 kv Line and Sylmar Transformer Banks Operation; (3) 7110, transmission facilities in Humboldt area; (4) 7230, transmission facilities in Palermo Rio-Oso area; (5) 7320, transmission facilities in Bay Area; (6) 7430, transmission facilities in Fresno area; ; (7) 7720, Julian Hinds-Mirage 230 kv line overload mitigation & Eagle Mountain bank emergency mtigation; (8) 8710, Hoodoo Wash-N.Gila 500 kv line flow mitigation; and (9) other transmission outages in PG&E, SCE and SDG&E area. Most of the generation procedures are internal to the ISO and not available publically on the ISO website; however, all of the transmission procedures are available on the ISO website. 1 The following additional reasons for exceptional dispatch instructions in July 2012 were not related to specific generation or transmission operating procedures: (1) Software Limitation, when an exceptional dispatch instruction was used to bridge schedules across days for resources with a minimum down time of 24 hours, as the ISO software does not handle multi day commitment. For instance, a resource has a day-ahead schedule from 0600 till 2300, and then is shut down in If this resource had a minimum down time of 24 hours and it is required the following day, then the ISO issues an exceptional dispatch to commit this resource in 2400 so that it can be dispatched economically in the following day. Software limitation reason was also used for exceptional dispatches to manually issue shut down instructions to a resource because of a temporary Automatic Dispatch System ( ADS ) failure, or similar issues; and (2) Market Disruption, when the exceptional dispatch instructions were issued due to HASP failures; and (3) Ramp Rate, when exceptional dispatch instructions were issued to dispatch a resource above its physical minimum to a level where the resource has significantly higher ramp rate capability. For example, a resource could have a ramp rate of 2 MW/min at its physical minimum of 100 MW, but a significantly higher ramp rate of 10 MW/min at 250 MW. The operators could issue an exceptional dispatch for this resource to be dispatched to 250 MW, so that the resource could respond to the anticipated steep load ramp or to a potential contingency. There were a few other reasons used to explain exceptional dispatch instructions injuly, which are self explanatory. As mentioned earlier, the data shown in Table 1 is based on a template specified in the September 2009 order. 2 This table contains all the information published 1 A list of all of the ISO s Operating Procedures and all the publicly available Operating Procedures are available at the following link: CAISO\MktAnls&Dvpmt Page 4

6 in Table 1 of the first report for July. In addition, it contains volume (MWh) and cost information. Each entry in Table 1 is a summary of exceptional dispatches classified by (1) the reason for the exceptional dispatch; (2) the location of the resource by Participating Transmission Owner (PTO) service area; (3) the Local Reliability Area (LRA) where applicable; (4) the market in which the exceptional dispatch occurred (day-ahead vs. real-time); and (5) the date of the exceptional dispatch. For each classification the following information is provided: (1) Megawatts (MW); (2) Commitment; (3) Inc or Dec; (4) Hours; (5) Begin Time; (6) End Time; (7) Total Volume (MWh); (8) Min Load Cost; (9) Start Up Cost; (10) ; (11) ED Volume (MWh INC/DEC); (12) INC; (13) DEC; (14) CC6482; (15) CC6488; and (16) CC6620. Each column is defined as follows: The MW column shows the range of exceptional dispatch instruction in MW for the classification. The Commitment column specifies if there was a unit commitment for the classification. The INC/DEC/NA column specifies if there was an incremental dispatch (INC), a decremental dispatch (DEC), or only a unit commitment (NA). The Begin Time and End Time columns show the start and end time of exceptional dispatch for the classification respectively. The Hours column is the time difference between begin time and end time rounded up to the next hour. The total volume column shows the total MWh dispatch quantity dispatched for that classification. This quantity includes the minimum load quantity, the imbalance energy quantity, and the exceptional dispatch quantity. The Min-Load Cost column shows eligible minimum load cost for the classification. The Start-Up Cost column shows the eligible start up cost for the classification. Please note that the ISO does not explicitly pay resources for its start up and minimum load costs; however, it ensures that resources are compensated adequately through its bid cost recovery process. 3 The column shows the total imbalance energy costs for the classification. This cost contains the portion of exceptional dispatch instruction that was settled as optimal energy by virtue of its bid price being less than the LMP in that specific settlement interval. The ED Volume MWh (MWh INC/DEC) column shows the incremental or the decremental portion of the real-time exceptional dispatch MWh for the classification. The -INC shows that portion of incremental 2 The data in Table 1 is principally SLIC information supplemented with data from the Market Quality System (MQS) and Settlements database. The volume and cost information is based on t+51b Recalculation Statements. 3 For further details regarding the Bid Cost Recovery process please refer to section 11.8 of the ISO tariff. CAISO\MktAnls&Dvpmt Page 5

7 exceptional dispatch instruction which is settled at the resource specific LMP. The -DEC column shows that portion of decremental exceptional dispatch instruction which is settled at the resource specific LMP. Both these charge codes are portion of the real-time instructed imbalance energy charge code (6470). 4 The CC6482 column shows the real-time excess cost for the classification. 5 The CC6488 column shows the real-time exceptional dispatch uplift settlement for the classification. 6 The CC6620 shows the bid cost recovery payment for the classification. This cost is shown for all pre-day-ahead unit commitments only. Charge codes 6470, 6470 INC, 6470 DEC, 6482 and 6488 are shown in Table 1 because all these charge codes pertain to real-time exceptional dispatch MWH quantities. The classification of data is further explained by way of example in Attachment A. There was no designation of capacity under Exceptional Dispatch Capacity Procurement Mechanism (CPM) in July For further details please refer to the BPM configuration Guide: Real-Time Instructed Imbalance Energy Settlement published on the ISO s website. 5 For further details please refer to the BPM configuration Guide: Real Time Excess Cost for Instructed Energy Settlement published on the ISO s website. 6 For further details please refer to the BPM configuration Guide: Real Time Exceptional Dispatch Uplift Settlement published on the ISO s website. CAISO\MktAnls&Dvpmt Page 6

8 Num ber Mark et Type Reason Location 1 RT 6510 SCE Local Reliability Area Big Creek Ventura Big Creek Ventura Table 1: Exceptional Dispatches in July 2012 California Independent System Operator Corporation Exceptional Dispatch Report October 30, 2012 Chart 2: Table of Exceptional Dispatches for Period 01/July/ /July/2012 Trade Date MW Comm itment INC_ DEC Hou rs Begin Time End Time Total MWH Min Load Cost 20 Jul No DEC 2 20:20 21: $0 Start Up Cost $0 $1,387 ED MWH(INC/ DEC) INC DEC CC6482 CC6488 CC $0 $0 $0 $0 $0 2 RT 6510 SCE 20 Jul No INC 3 18:40 20: $ ($1,825) $0 $0 $0 $0 $0 ($1,264) ($132,94 ($127,304 3 RT 6510 SCE LA Basin 9 Jul Yes INC 11 9:00 19: $32, $0 $0 $0 $0 $0 1) ) ($90,012 4 RT 6510 SCE LA Basin 11 Jul Yes INC 12 7:50 18: $32, ($70,879) $0 $0 $0 $0 5 RT 6510 SCE LA Basin 16 Jul No INC 4 16:20 19: $0 $0 ($5,880) ($5,880) $0 $0 $0 $0 ($232,06 ($231,724 6 RT 6510 SCE LA Basin 18 Jul No INC 10 10:45 19: $ $0 $0 $0 $0 $0 7) ) 7 RT 6510 SCE LA Basin 19 Jul Yes DEC 15 7:20 21: $0 $0 ($4,773) 0.00 $0 $0 $0 $0 $0 ($588,03 ($406,537 8 RT 6510 SCE LA Basin 19 Jul Yes INC 15 7:20 21: $ $0 $0 $0 $0 $0 0) ) 9 RT 6510 SCE LA Basin 20 Jul No DEC 11 11:50 21: $0 $0 ($10) 0.00 $0 $0 $0 $0 $0 ($446,25 ($208,669 ($13,94 10 RT 6510 SCE LA Basin 20 Jul Yes INC 19 5:00 23: $97, $0 $0 $0 $0 6) ) 3) 11 RT 6510 SCE LA Basin 21 Jul No DEC 9 12:15 20: $0 $0 $8, $0 $0 $0 $0 $0 ($161,25 ($129, RT 6510 SCE LA Basin 21 Jul No INC 9 12:15 20: $ $0 $0 $0 $0 $0 8) ) 13 RT 6510 SCE LA Basin 22 Jul No DEC 11 11:35 21: $0 $0 $3, $0 $0 $0 $0 $0 ($96, RT 6510 SCE LA Basin 22 Jul No INC 11 11:35 21: $ ($96,122) $0 $0 $0 $0 15 RT 6510 SCE LA Basin 25 Jul No DEC 14 8:40 21: $0 $0 $4, $0 $0 $0 $0 $0 ($141,87 ($141, RT 6510 SCE LA Basin 25 Jul No INC 14 8:40 21: $ $0 $0 $0 $0 $0 5) ) ($72, RT 6510 SCE LA Basin 30 Jul No INC 7 12:25 18: $ ($72,831) $0 $0 $0 $0 ($190,06 ($190, RT 6510 SCE LA Basin 31 Jul No INC 10 9:10 18: $ $0 $0 $0 $0 $0 8) ) ($11, RT 6510 SDG&E San Diego 16 Jul No INC 5 16:45 20: $44, ($28) $0 $0 $0 $0 CAISO\MktAnls&Dvpmt Page 7

9 Num ber Mark et Type Reason Location Local Reliability Area Trade Date MW Comm itment INC_ DEC Hou rs Begin Time 20 RT 6510 SDG&E San Diego 19 Jul No INC 15 7:20 21: $18,169 ($441,39 4) ($13,364) $0 $0 $0 $0 21 RT 6510 SDG&E San Diego 20 Jul No INC 10 12:00 21: $802 $0 $117, ($0) $0 $0 $0 $0 22 RT 6510 SDG&E San Diego 21 Jul Yes DEC 1 23:53 23: $0 $0 $ $0 $0 $0 $0 $0 23 RT 6510 SDG&E San Diego 21 Jul No INC 4 20:05 23: $7,088 $0 ($7,638) 1.92 ($65) $0 $0 $0 $0 $6,13 ($34, RT 6510 SDG&E San Diego 22 Jul Yes INC 24 0:00 23: $96, $0 $0 $0 $0 $0 8 ) $2,20 ($16, RT 6510 SDG&E San Diego 31 Jul No INC 8 14:45 21: $32, ($143) $0 $0 $0 $0 0 ) Big Creek 26 RT 6610 SCE 31 Jul No DEC 1 12:41 12: $ $0 $42 $0 $0 $0 Ventura $0 ($1,073) ($11, RT 6610 SCE N/A 31 Jul No INC 1 12:36 12: $ $0 $0 $0 $0 $0 28 RT 7110 PG&E Humboldt 16 Jul No INC 3 14:26 16: $974 $0 ($398) 0.18 ($4) $0 $0 ($2) $0 29 RT 7110 PG&E Humboldt 17 Jul No INC 2 14:26 15: $433 $0 ($431) 8.66 ($176) $0 $0 ($44) $0 30 RT 7110 PG&E Humboldt 18 Jul No INC 9 8:15 16: $3,607 $0 $1, $0 $0 $0 $0 $0 ($29, RT 7110 PG&E Humboldt 19 Jul No INC 18 6:20 23: $15, ($4,242) $0 $0 ($826) $0 32 RT 7230 PG&E Sierra 1 Jul Yes INC 4 13:45 16: $4,070 $0 ($1,448) 0.00 $0 $0 $0 $0 $0 ($3, RT 7230 PG&E Sierra 2 Jul No DEC 5 17:17 21: $ $0 ###### $0 $0 $0 ($1,534) ) 34 RT 7230 PG&E Sierra 4 Jul No INC 1 14:20 14: $0 $0 ($414) 5.91 ($151) $0 $0 ($38) $0 ###### 35 RT 7230 PG&E Sierra 6 Jul No DEC 5 17:45 21: $ $0 ###### $0 $0 $0 $73,509 # 36 RT 7230 PG&E Sierra 7 Jul No DEC 4 18:45 21: $0 $0 $2, $0 $2,105 $0 ($704) $0 37 RT 7230 PG&E Sierra 10 Jul No DEC 1 16:26 16: $0 $0 $ $0 $46 $0 ($0) $0 38 RT 7230 PG&E Sierra 10 Jul 12 0 No INC 1 16:26 16: $0 $0 $ $0 $0 $0 $0 $0 ($11, RT 7230 PG&E Sierra 11 Jul No DEC 3 13:39 15: $ $0 ###### $0 ($7) $0 ###### 40 RT 7230 PG&E Sierra 12 Jul No DEC 7 16:52 22: $ $0 ###### $0 $0 $0 $295,835 # ($46, RT 7230 PG&E Sierra 12 Jul No INC 6 17:04 22: $ $0 $0 $0 $0 $0 ($3, RT 7230 PG&E Sierra 13 Jul Yes DEC 10 12:10 21: $ $0 $4,583 $0 $0 $0 $6,090 ) ($35, RT 7230 PG&E Sierra 13 Jul Yes INC 10 12:10 21: $4, $0 $0 $0 $0 $0 44 RT 7230 PG&E Sierra 15 Jul Yes INC 1 22:05 22: $1,110 $0 ($279) 0.26 ($5) $0 $0 ($3) $0 45 RT 7230 PG&E Sierra 22 Jul Yes DEC 9 15:10 23: $0 $0 $35, $0 ###### $0 ###### $0 End Time Total MWH Min Load Cost Start Up Cost $7,07 1 ED MWH(INC/ DEC) INC DEC CC6482 CC6488 CC66 20 CAISO\MktAnls&Dvpmt Page 8

10 Num ber Mark et Type Reason Location Local Reliability Area Trade Date MW Comm itment INC_ DEC Hou rs Begin Time 46 RT 7230 PG&E Sierra 22 Jul Yes INC 11 13:30 23: $2,220 $0 ($4,098) ($555) $0 $0 ($585) $0 47 RT 7230 PG&E Sierra 25 Jul Yes DEC 2 20:10 21: $0 $0 $ $0 $0 $0 $0 $0 48 RT 7230 PG&E Sierra 25 Jul Yes INC 2 20:10 21: $1,850 $0 ($656) 3.40 ($76) $0 $0 ($41) $0 49 RT 7230 PG&E Sierra 31 Jul 12 8 Yes DEC 2 16:52 17: $0 $0 ($11) 0.00 $0 $0 $0 $0 $0 50 RT 7230 PG&E Sierra 31 Jul Yes INC 4 15:51 18: $0 $0 ($3,019) 0.00 $0 $0 $0 $0 $0 51 RT 7320 PG&E Bay Area 21 Jul No INC 2 11:00 12: $698 $253 ($548) 1.92 ($53) $0 $0 ($0) $0 52 RT 7320 PG&E Bay Area 27 Jul No INC 3 20:36 22: $1,832 $73 ($733) 6.89 ($145) $0 $0 ($96) $0 53 RT 7430 PG&E Fresno 1 Jul 12 0 No INC 6 11:40 16: $0 $0 $ $0 $0 $0 $0 $0 54 RT 7430 PG&E Fresno 5 Jul No INC 5 0:35 4: $0 $0 ($1,072) 0.00 $0 $0 $0 $0 $0 55 RT 7430 PG&E Fresno 9 Jul Yes DEC 1 21:35 21: $0 $0 $ ($83) $0 $0 ($44) $0 56 RT 7430 PG&E Fresno 9 Jul Yes INC 2 21:45 22: $0 ($1, ($3,582) $0 $0 $0 ($5,671) ) $0 57 RT 7430 PG&E Fresno 10 Jul No DEC 4 18:45 21: $0 $0 $ $0 $0 $0 $0 $0 58 RT 7430 PG&E Fresno 11 Jul No DEC 8 14:16 21: $0 $0 $19, ($185) $0 $0 ($34) $0 59 RT 7430 PG&E Fresno 11 Jul No INC 3 15:35 17: $0 ($2, ($9,110) $0 $0 $0 ($9,809) ) $0 60 RT 7430 PG&E Fresno 12 Jul Yes DEC 7 14:05 20: $0 $0 $1, ($475) $0 $0 ($565) $0 61 RT 7430 PG&E Fresno 12 Jul Yes INC 8 14:27 21: $11,664 ($98,753 ($6, ($15,525) $307 $0 $583 ) ) $0 62 RT 7430 PG&E Fresno 13 Jul Yes DEC 6 16:20 21: $0 $0 $14, $0 $0 $0 $0 $0 63 RT 7430 PG&E Fresno 13 Jul Yes INC 5 17:20 21: $9,078 ($1, ($2,880) $0 $0 $500 ($5,364) ) $0 64 RT 7430 PG&E Fresno 14 Jul Yes DEC 6 16:50 21: $0 $0 $8, $0 $0 $0 $0 $0 65 RT 7430 PG&E Fresno 14 Jul Yes INC 5 17:05 21: $4,539 $500 ($2,387) ($1,116) $0 $0 ($546) $0 66 RT 7430 PG&E Fresno 16 Jul Yes DEC 1 20:30 20: $0 $0 $ ($33) $0 $0 ($3) $0 67 RT 7430 PG&E Fresno 16 Jul Yes INC 6 17:35 22: $7,449 $0 ($5,283) ($2,255) $0 $0 ($693) $0 68 RT 7430 PG&E Fresno 17 Jul 12 3 No DEC 15 6:35 20: $0 $0 $ $0 $1,030 $0 ($928) $0 69 RT 7430 PG&E Fresno 18 Jul 12 2 No DEC 20 1:10 20: $0 $0 $ $0 $763 $0 ($679) $0 70 RT 7430 PG&E Fresno 18 Jul No INC 20 1:10 20: $0 $0 ($142) 0.00 $0 $0 $0 $0 $0 71 RT 7430 PG&E Fresno 19 Jul Yes INC 2 22:14 23: $0 ($1, ($2,954) $0 $0 $0 ($2,917) ) $0 72 RT 7430 PG&E Fresno 20 Jul Yes INC 4 20:40 23: $10,158 $2,33 3 ($8,768) ($2,084) $0 $0 ($305) $0 73 RT 7430 PG&E Fresno 21 Jul Yes DEC 15 9:55 23: $0 $0 $2, $0 $0 $0 $0 $0 74 RT 7430 PG&E Fresno 21 Jul Yes INC 15 9:25 23: $25,780 $1,14 ($44,876 ($3, ($2,499) $0 $0 3 ) ) $0 75 RT 7430 PG&E Fresno 22 Jul Yes DEC 4 11:49 14: $0 $0 ($95) 0.00 $0 $0 $0 $0 $0 End Time Total MWH Min Load Cost Start Up Cost ED MWH(INC/ DEC) INC DEC CC6482 CC6488 # CC66 20 CAISO\MktAnls&Dvpmt Page 9

11 Num ber Mark et Type Reason Location Local Reliability Area Trade Date MW Comm itment INC_ DEC Hou rs Begin Time 76 RT 7430 PG&E Fresno 22 Jul Yes INC 13 11:49 23: $8,126 $0 ($4,092) ($643) $0 $0 ($508) $0 77 RT 7430 PG&E Fresno 23 Jul Yes DEC 1 21:35 21: $0 $0 $1, $0 $0 $0 $0 $0 78 RT 7430 PG&E Fresno 23 Jul Yes INC 24 0:00 23: $24,601 ($10, ($1,650) $0 $0 ($537) $0 79 RT 7430 PG&E Fresno 24 Jul Yes INC 4 20:00 23: $18,961 ($19,234 ($1, ($5,467) $0 $0 ) $0 80 RT 7430 PG&E Fresno 25 Jul Yes DEC 17 7:35 23: $0 ($2, $0 $2,609 $0 $0 $2,528 ) $0 81 RT 7430 PG&E Fresno 25 Jul Yes INC 3 20:45 22: $15,916 $1,58 3 ($8,399) ($3,416) $0 $0 ($861) $0 82 RT 7430 PG&E Fresno 26 Jul Yes DEC 4 16:15 19: $0 $0 $1, ($102) $0 $0 ($12) $0 83 RT 7430 PG&E Fresno 26 Jul Yes INC 13 10:50 22: $23,024 ($24,975 ($5, ($13,610) $0 $0 ) $0 84 RT 7430 PG&E Fresno 27 Jul Yes INC 4 19:14 22: $29,518 $1,72 ($22,224 ($1, ($9,271) $0 $0 7 ) ) $0 85 RT 7430 PG&E Fresno 28 Jul 12 2 No DEC 15 7:45 21: $0 $0 $ $0 $668 $0 ($541) $0 86 RT 7430 PG&E Fresno 29 Jul No DEC 17 7:25 23: $0 ($2, $0 $2,592 $0 $0 $2,737 ) $0 87 RT 7430 PG&E Fresno 30 Jul No DEC 15 0:00 14: $0 ($2, $0 $2,283 $0 $0 $2,407 ) $0 88 RT 7430 PG&E Fresno 31 Jul Yes INC 4 20:27 23: $11,560 $1,00 ($16,441 ###### ($4,223) $0 $0 0 ) # $0 89 RT 7430 PG&E Sierra 15 Jul Yes DEC 7 16:25 22: $0 $0 $ $0 $0 $0 $0 $0 90 RT 7430 PG&E Sierra 15 Jul Yes INC 7 16:25 22: $1,110 $0 ($209) 2.05 ($42) $0 $0 ($16) $0 91 RT 7430 SCE Big Creek 23 Jul No DEC 1 11:10 11: $0 Ventura $0 $1, $0 $0 $0 $0 $0 92 RT 7630 SCE LA Basin 16 Jul Yes DEC 6 14:00 19: $0 $0 $10, $0 $0 $0 $0 $0 93 RT 7630 SCE LA Basin 16 Jul 12 0 Yes INC 6 14:00 19: $0 $0 $ $0 $0 $0 $0 $0 94 RT 7630 SCE LA Basin 20 Jul 12 0 Yes DEC 11 8:45 18: $0 $0 ($90) 0.00 $0 $0 $0 $0 $0 95 RT 7630 SCE LA Basin 20 Jul Yes INC 11 8:45 18: $1,793 $0 ($1,712) 0.00 $0 $0 $0 $0 $0 96 RT 7720 SCE N/A 19 Jul No DEC 7 13:45 19: $0 ###### $0 ###### $0 $0 $75,669 # $0 97 RT 7720 SCE N/A 19 Jul No INC 2 13:45 14: $0 $0 ($509) 0.00 $0 $0 $0 $0 $0 98 RT 8710 SDG&E N/A 17 Jul Yes INC 2 10:55 11: $0 $0 ($4,793) ($442) $0 ($29) $0 $0 99 RT 8710 SDG&E San Diego 3 Jul No INC 3 12:11 14: $17,680 ($75, ($11,481) $0 $0 $0 $0 100 RT 8710 SDG&E San Diego 14 Jul No INC 24 0:00 23: $64,376 ($131,96 $0 2) 0.00 $0 $0 $0 $0 $0 101 RT 8710 SDG&E San Diego 15 Jul No INC 24 0:00 23: $142,521 $0 ($44, $0 $0 $0 $0 $0 End Time Total MWH Min Load Cost Start Up Cost ED MWH(INC/ DEC) INC DEC CC6482 CC6488 CC66 20 CAISO\MktAnls&Dvpmt Page 10

12 Num ber Mark et Type Reason Location Local Reliability Area Trade Date MW Comm itment INC_ DEC Hou rs Begin Time ) ($36, RT 8710 SDG&E San Diego 16 Jul No INC 24 0:00 23: $143, ($24) $0 $0 $0 $0 ($17, RT 8710 SDG&E San Diego 17 Jul No INC 7 15:45 21: $18, ($673) $0 ($265) $0 $0 $508 ) 104 RT 8710 SDG&E San Diego 18 Jul Yes INC 1 22:10 22: $1,973 $0 ($3,101) ($545) $0 ($19) $0 $0 $8,48 ($442, RT 8710 SDG&E San Diego 19 Jul No INC 17 7:00 23: $21, ($13,364) $0 $0 $0 $0 5 2) ($20, RT Bridging Schedules PG&E N/A 31 Jul No INC 4 20:00 23: $19, $0 $0 $0 $0 $0 107 RT Bridging Schedules SCE LA Basin 11 Jul Yes INC 4 20:00 23: $23,728 $0 ($5,744) 0.00 $0 $0 $0 $0 $0 108 RT Bridging Schedules SCE LA Basin 12 Jul Yes INC 4 0:00 3: $23,728 $0 ($4,563) 0.00 $0 $0 $0 $0 $0 109 RT Bridging Schedules SDG&E San Diego 14 Jul No INC 7 17:00 23: $0 $0 ($4,908) 0.00 $0 $0 $0 $0 $0 110 RT Bridging Schedules SDG&E San Diego 21 Jul No INC 2 22:00 23: $0 $0 ($1,521) 0.00 $0 $0 $0 $0 $0 111 RT COI mitigation Intertie N/A 19 Jul No DEC 1 0:10 0: $0 $0 ($402) $0 ($402) $0 $0 $0 ($1, RT Contingency Intertie N/A 24 Jul No INC 1 0:04 0: $ ($961) $0 $0 $0 $0 ($1,220) ) 113 RT Contingency PG&E Fresno 24 Jul No INC 1 0:07 0: $0 $0 ($490) ($186) $0 ($384) $0 $0 114 RT Contingency PG&E Humboldt 5 Jul No INC 2 17:18 18: $0 $0 $ $0 $188 $0 ($181) $0 115 RT Contingency PG&E N/A 24 Jul No INC 1 0:10 0: $2,618 $0 ($2,491) ($657) $0 ($285) $0 $0 116 RT Contingency PG&E Sierra 24 Jul No INC 1 0:09 0: $0 $0 ($441) 5.95 ($119) $0 ($107) $0 $0 Big Creek 117 RT Contingency SCE 24 Jul No DEC 1 0:08 0: $ $0 $0 $0 $0 $0 Ventura $0 ($0) 118 RT Contingency SCE N/A 4 Jul No INC 1 0:20 0: $0 $0 ($868) 0.00 $0 $0 $0 $0 $0 119 RT Contingency SDG&E San Diego 23 Jul No DEC 3 13:10 15: $0 $0 $4, $0 $3,012 $0 ($500) $0 120 RT Contingency SDG&E San Diego 23 Jul No INC 1 13:10 13: $0 $0 $ $0 $850 $0 ($239) $0 121 RT Contingency SDG&E San Diego 24 Jul No INC 1 0:06 0: $2,620 $0 ($1,434) ($587) $0 ($514) $0 $0 122 RT Fire SCE LA Basin 7 Jul No DEC 5 15:45 19: $0 $0 $27, $0 $0 $0 $0 $0 ($27,132 ###### 123 RT Fire SCE LA Basin 7 Jul No INC 5 15:35 19: $ ($26,371) $0 $0 $0 ## 124 RT Generation Outage SCE LA Basin 13 Jul No DEC 13 11:00 23:59 $ $0 ###### $0 $0 $ $0 $42, RT Generation Outage SCE LA Basin 13 Jul 12 0 No INC 13 11:00 23: $0 $0 $ $0 $0 $0 $0 $0 Intertie Emergency 126 RT Intertie N/A 5 Jul Yes INC 1 12:25 12: $ $0 $0 $0 $0 $0 Assistance $0 $0 Intertie Emergency 127 RT Intertie N/A 29 Jul No INC 1 13:20 13: $ $0 $0 $0 $0 $0 Assistance $0 $0 ($281, RT Load Forecast Uncertainty SCE LA Basin 9 Jul Yes INC 22 2:00 23: $129, ($74,772) $0 $0 $0 $0 $0 9) End Time Total MWH Min Load Cost Start Up Cost ED MWH(INC/ DEC) INC DEC CC6482 CC6488 CC66 20 CAISO\MktAnls&Dvpmt Page 11

13 Num ber Mark et Type Reason Location Local Reliability Area Trade Date MW Comm itment INC_ DEC Hou rs Begin Time 129 RT Load Forecast Uncertainty SCE LA Basin 10 Jul No DEC 1 0:00 0: $0 $0 $2, $0 $0 $0 $0 $0 ($120, RT Load Forecast Uncertainty SCE LA Basin 10 Jul Yes INC 24 0:00 23: $231, ($32,520) $0 $0 $0 $0 $0 9) ($25, RT Load Forecast Uncertainty SCE LA Basin 12 Jul Yes INC 24 0:00 23: $121, $0 $0 $0 $0 $0 132 RT Market Disruption Intertie N/A 3 Jul Yes INC 1 3:00 3: $0 $0 $ $0 $0 $0 $0 $0 133 RT Market Disruption Intertie N/A 5 Jul No DEC 1 1:00 1: $0 $0 $ $0 $0 $0 $0 $0 134 RT Market Disruption Intertie N/A 5 Jul Yes INC 1 1:00 1: $0 $0 $ $0 $0 $0 $0 $0 135 RT Market Disruption Intertie N/A 19 Jul No INC 1 3:00 3: $0 $0 $ $0 $0 $0 $0 $0 136 RT Over Generation PG&E Bay Area 3 Jul No INC 7 2:41 8: $0 $0 $13, $0 ($885) $0 $0 $0 137 RT Over Generation PG&E Fresno 12 Jul No DEC 1 21:02 21: $0 $0 ($354) $0 $307 $0 $0 $0 138 RT Over Generation PG&E Fresno 12 Jul Yes INC 1 21:02 21: $757 $83 ($1,472) 0.00 $0 $0 $0 $0 $0 Big Creek 139 RT Path 15 SCE 23 Jul No DEC 1 13:15 13: $ ($479) $0 $0 ($83) $0 Ventura $0 ($814) 140 RT Path 26 SCE LA Basin 13 Jul No INC 13 6:00 18: $0 $0 ($6,968) 0.00 $0 $0 $0 $0 $0 141 RT Path 66 Intertie N/A 24 Jul No DEC 3 0:06 2: $0 $0 ($1,543) $0 ###### $0 $0 $0 142 RT Pumped Storage PG&E Fresno 1 Jul No DEC 1 8:00 8: $0 $0 $ $0 $0 $0 $0 $0 Big Creek ($136,06 ($117, RT Ramp Rate SCE 11 Jul Yes INC 9 11:15 19: $54, $0 $0 $0 $0 Ventura $0 0) ) 144 RT Ramp Rate SCE LA Basin 9 Jul Yes DEC 10 11:00 20: $0 $0 $5, $0 $0 $0 $0 $0 ($18, RT Ramp Rate SCE LA Basin 9 Jul Yes INC 10 11:00 20: $20, ($14,170) $0 $0 $0 $0 ($55, RT Ramp Rate SCE LA Basin 10 Jul Yes INC 9 11:00 19: $53, ($32,049) $0 $0 $0 $0 $6,97 ($108, RT Ramp Rate SDG&E San Diego 2 Jul No INC 14 10:22 23: $62, ($742) $0 $0 $0 $0 0 2) ($76, RT Ramp Rate SDG&E San Diego 3 Jul No INC 17 5:25 21: $56, ($1,328) $0 $0 $0 $0 ($15, RT Ramp Rate SDG&E San Diego 4 Jul No INC 11 10:10 20: $46, ($0) $0 $0 $0 $0 ($41, RT Ramp Rate SDG&E San Diego 5 Jul No INC 10 11:15 20: $43, ($0) $0 $0 $0 $0 151 RT Ramp Rate SDG&E San Diego 9 Jul No INC 13 11:55 23: $802 $0 ($3,095) 0.24 ($8) $0 $0 $0 $0 152 RT Ramp Rate SDG&E San Diego 10 Jul No INC 22 0:00 21:59 $ ($17) $0 $0 $0 $ $0 $132, RT Ramp Rate SDG&E San Diego 12 Jul No INC 13 7:15 19:59 $14, ($4) $0 $0 $0 $ $0 $62,623 ($10, RT Ramp Rate SDG&E San Diego 14 Jul No INC 4 18:15 21: $16, ($0) $0 $0 $0 $0 End Time Total MWH Min Load Cost Start Up Cost ED MWH(INC/ DEC) INC DEC CC6482 CC6488 CC66 20 CAISO\MktAnls&Dvpmt Page 12

14 Num ber Mark et Type Reason Location Local Reliability Area Trade Date MW Comm itment INC_ DEC Hou rs Begin Time 155 RT Ramp Rate SDG&E San Diego 15 Jul No INC 5 18:40 22: $19,792 $0 ($5,594) 0.00 $0 $0 $0 $0 $0 156 RT Reverse Commitment SDG&E San Diego 9 Jul 12 0 Yes INC 3 9:47 11: $0 Instruction $0 $ $0 $0 $0 $0 $0 157 RT Risk Predictor SCE Big Creek ($160,45 ($117, Jul Yes INC 14 10:00 23: $86, Ventura $0 9) ) $0 $0 $0 $0 158 RT Risk Predictor SCE LA Basin 11 Jul Yes INC 24 0:00 23: $134,274 ($300,48 $0 6) ($70,879) $0 $0 $0 $0 159 RT SCE SOB 204 SCE Big Creek 3 Jul No DEC 3 19:20 21: $0 Ventura $0 $4, $0 $0 $0 $0 $0 160 RT SCE SOB 204 SCE Big Creek 9 Jul No DEC 4 19:30 22: $0 Ventura $0 $ $0 $0 $0 $0 $0 161 RT SCE SOB 204 SCE Big Creek 9 Jul 12 0 No INC 3 19:45 21: $0 Ventura $0 $ $0 $0 $0 $0 $0 162 RT SCE SOB 204 SCE Big Creek 10 Jul No DEC 3 16:15 18: $0 Ventura $0 $3, ($1,957) $0 $0 $0 $0 163 RT SCE SOB 204 SCE Big Creek ($17, Jul No INC 7 15:20 21: $0 Ventura ($16,694) $0 $0 ($601) $0 164 RT SCE SOB 204 SCE Big Creek 11 Jul No DEC 11 11:00 21: $0 Ventura $0 $4, ($1,738) $0 $0 ($381) $0 165 RT SCE SOB 204 SCE Big Creek ($12,462 ($3, Jul No INC 11 13:05 23: $ ($12,221) $0 $0 Ventura ) $0 166 RT SCE SOB 204 SCE Big Creek 12 Jul No DEC 11 10:45 20: $0 Ventura $0 $13, $0 $0 $0 $0 $0 167 RT SCE SOB 204 SCE Big Creek ($14,321 ($3, Jul No INC 23 0:20 22: $ ($13,283) $0 $0 Ventura ) $0 168 RT SCE SOB 204 SCE Big Creek ($89,891 ###### 13 Jul No INC 21 1:05 21: $ ($37,325) $0 $0 Ventura # $0 169 RT SCE SOB 204 SCE Big Creek 19 Jul No DEC 2 22:30 23: $0 Ventura $0 $ ($5) $0 $0 $0 $0 170 RT SCE SOB 204 SCE Big Creek 19 Jul No INC 7 17:40 23: $0 Ventura $0 ($7,057) ($10,853) $0 $0 ($163) $0 171 RT SCE SOB 204 SCE Big Creek ($109,42 ($1, Jul No INC 9 15:30 23: $ ($54,595) $0 $0 Ventura $0 0) ) $0 172 RT SCE SOB 204 SCE Big Creek ($19,639 ($3, Jul No INC 10 14:50 23: $ ($26,373) $0 $0 Ventura ) $0 173 RT SCE SOB 204 SCE Big Creek 23 Jul No DEC 11 12:00 22: $0 Ventura $0 ($1,331) ($1,715) $0 $0 ($437) $0 174 RT SCE SOB 204 SCE Big Creek ($29,083 ($9, Jul No INC 21 0:00 20: $ ($24,779) $0 $0 Ventura ) $0 175 RT SCE SOB 204 SCE Big Creek 24 Jul No DEC 4 16:10 19: $0 Ventura $0 $6, ($1,629) $0 $0 ($490) $0 End Time Total MWH Min Load Cost Start Up Cost ED MWH(INC/ DEC) INC DEC CC6482 CC6488 CC66 20 CAISO\MktAnls&Dvpmt Page 13

15 Num ber Mark et Type Reason Location 176 RT SCE SOB 204 SCE 177 RT SCE SOB 204 SCE 178 RT SCE SOB 204 SCE Local Reliability Area Big Creek Ventura Big Creek Ventura Big Creek Ventura Big Creek Ventura Big Creek Ventura Big Creek Ventura Trade Date MW Comm itment INC_ DEC Hou rs Begin Time End Time Total MWH Min Load Cost 24 Jul No INC 4 19:15 22: $0 25 Jul No DEC 2 22:25 23: $0 25 Jul No INC 3 20:15 22: $0 Start Up Cost $0 ($12,045 ) $0 ($595) $0 ($7,559) ED MWH(INC/ DEC) INC DEC CC ($10,477) $0 $0 CC6488 ($4,396 ) CC ($140) $0 $0 ($3) $ ($3,848) $0 $0 ($727) $0 179 RT SCE SOB 204 SCE 26 Jul No DEC 1 20:20 20: $0 $0 ($3,628) ($340) $0 $0 ($56) $0 180 RT SCE SOB 204 SCE 26 Jul No INC 3 18:55 20: $0 ($15,712 ($2, ($10,349) $0 $0 ) $0 181 RT SCE SOB 204 SCE 31 Jul No INC 9 15:55 23: $0 ($32, ($16,949) $0 $0 ($917) $0 182 RT SP26 Capacity SCE LA Basin 14 Jul 12 0 No INC 22 2:00 23: $0 $0 ($8,382) 0.21 ($7) $0 ($30) $0 $0 183 RT SP26 Capacity SCE LA Basin 20 Jul Yes INC 22 2:00 23: $64,064 ($362,77 ($112, $0 0) ) $0 $0 $0 $0 184 RT SP26 Capacity SCE LA Basin 23 Jul Yes INC 22 2:00 23: $64,064 ($20, $0 $0 $0 $0 $0 185 RT Software Limitation PG&E Fresno 2 Jul 12 0 Yes INC 18 6:00 23: $2,270 $375 ($374) 0.00 $0 $0 $0 $0 $0 186 RT Software Limitation PG&E Fresno 3 Jul 12 0 No INC 1 0:00 0: $0 $0 $ $0 $0 $0 $0 $0 187 RT Software Limitation PG&E Fresno 7 Jul 12 0 Yes INC 2 22:35 23: $2,270 $0 ($719) 0.00 $0 $0 $0 $0 $0 188 RT Software Limitation PG&E Fresno 11 Jul No DEC 1 0:30 0: $0 $0 $2, $0 $0 $0 $0 $0 189 RT Software Limitation PG&E Fresno 11 Jul 12 0 No INC 1 0:06 0: $0 $0 $ $0 $0 $0 $0 $0 190 RT Software Limitation PG&E Fresno 13 Jul 12 0 No INC 2 22:50 23: $0 $0 $ $0 $0 $0 $0 $0 191 RT Software Limitation PG&E Fresno 17 Jul 12 0 No INC 2 10:30 11: $0 $0 ($0) 0.00 $0 $0 $0 $0 $0 192 RT Software Limitation PG&E Fresno 19 Jul 12 0 Yes INC 2 22:00 23: $0 $0 ($0) 0.00 $0 $0 $0 $0 $0 193 RT Software Limitation PG&E Fresno 25 Jul No INC 1 15:43 15: $975 $0 ($753) 5.33 ($228) $0 $0 $0 $0 194 RT Software Limitation PG&E N/A 11 Jul No DEC 2 6:30 7: $0 $0 $ $0 $0 $0 $0 $0 195 RT Software Limitation PG&E N/A 11 Jul No INC 7 1:25 7: $1,484 $0 ($5,907) 0.00 $0 $0 $0 $0 $0 ($10, RT Software Limitation PG&E N/A 12 Jul Yes INC 6 0:27 5: $4, $0 $0 $0 $0 $0 197 RT Software Limitation PG&E N/A 20 Jul No DEC 3 3:00 5: $0 $0 $ $0 $0 $0 $0 $0 ($23, RT Software Limitation PG&E N/A 23 Jul No INC 10 1:35 10: $26, ($2,538) $0 $0 $0 $0 ##### ($26, RT Software Limitation PG&E N/A 30 Jul No INC 13 0:15 12: $42, $0 $0 $0 $0 $0 # ) Big Creek 200 RT Software Limitation SCE 2 Jul 12 0 Yes INC 2 20:50 21: $ $0 $0 $0 $0 $0 Ventura $42 ($75) Big Creek 201 RT Software Limitation SCE 12 Jul 12 0 Yes INC 5 0:27 4: $1, $0 $0 $0 $0 $0 Ventura $0 ($183) $0 CAISO\MktAnls&Dvpmt Page 14

16 Num ber Mark et Type Reason Location 202 RT Software Limitation SCE 203 RT Software Limitation SCE 204 RT Software Limitation SCE 205 RT Software Limitation SCE Local Reliability Area Big Creek Ventura Big Creek Ventura Big Creek Ventura Big Creek Ventura Trade Date MW Comm itment INC_ DEC Hou rs Begin Time End Time Total MWH Min Load Cost 13 Jul Yes DEC 6 0:45 5: $0 13 Jul 12 0 Yes INC 11 0:45 10: $4, Jul Yes DEC 6 0:20 5: $0 14 Jul 12 0 Yes INC 18 0:20 17: $289 Start Up Cost $0 ($221) $0 ($2,293) $0 $220 ED MWH(INC/ DEC) INC DEC CC6482 CC6488 CC $0 $0 $0 $0 $ $0 $0 $0 $0 $ $0 $220 $0 $0 $ $0 $0 $0 $0 $0 $22 ($1,182) 206 RT Software Limitation SCE LA Basin 6 Jul 12 0 Yes INC 2 18:45 19: $0 $0 ($37) 0.00 $0 $0 $0 $0 $0 207 RT Software Limitation SCE LA Basin 7 Jul 12 0 Yes INC 2 21:15 22: $0 $0 ($304) 0.00 $0 $0 $0 $0 $0 208 RT Software Limitation SCE LA Basin 12 Jul 12 0 Yes INC 2 19:30 20: $0 $0 ($36) 0.00 $0 $0 $0 $0 $0 209 RT Software Limitation SCE LA Basin 14 Jul No DEC 2 0:00 1: $0 $0 $ $0 $0 $0 $0 $0 210 RT Software Limitation SCE LA Basin 14 Jul 12 0 Yes INC 2 17:45 18: $0 $24 ($93) 0.00 $0 $0 $0 $0 $0 211 RT Software Limitation SCE LA Basin 16 Jul 12 0 Yes INC 2 12:45 13: $0 $26 ($69) 0.00 $0 $0 $0 $0 $0 212 RT Software Limitation SCE LA Basin 18 Jul 12 0 Yes INC 1 10:25 10: $0 $5 ($28) 0.00 $0 $0 $0 $0 $0 213 RT Software Limitation SCE LA Basin 19 Jul 12 0 Yes INC 9 12:30 20: $0 $0 ($224) 0.00 $0 $0 $0 $0 $0 214 RT Software Limitation SCE LA Basin 21 Jul 12 0 Yes INC 2 21:45 22: $0 $0 ($80) 0.00 $0 $0 $0 $0 $0 215 RT Software Limitation SCE LA Basin 23 Jul 12 0 Yes INC 2 16:45 17: $0 $0 ($31) 0.00 $0 $0 $0 $0 $0 216 RT Software Limitation SCE LA Basin 25 Jul 12 0 Yes INC 2 18:45 19: $0 $0 ($38) 0.00 $0 $0 $0 $0 $0 217 RT Software Limitation SCE LA Basin 26 Jul 12 0 Yes INC 2 18:55 19: $0 $0 ($39) 0.00 $0 $0 $0 $0 $0 218 RT Software Limitation SCE LA Basin 29 Jul 12 0 Yes INC 4 18:38 21: $776 $0 ($1,801) 0.00 $0 $0 $0 $0 $0 219 RT Software Limitation SCE LA Basin 31 Jul 12 0 Yes INC 2 21:15 22: $0 $0 ($91) 0.00 $0 $0 $0 $0 $0 220 RT Software Limitation SCE N/A 12 Jul 12 0 Yes INC 3 21:40 23: $208 $0 ($106) 0.00 $0 $0 $0 $0 $0 221 RT Software Limitation SCE N/A 13 Jul 12 0 No INC 5 0:00 4: $0 $0 $ $0 $0 $0 $0 $0 222 RT Software Limitation SDG&E San Diego 11 Jul No INC 1 23:40 23: $0 $0 $ $0 $0 $0 $0 $0 223 RT Software Limitation SDG&E San Diego 12 Jul No INC 1 0:00 0: $0 $0 $ $0 $0 $0 $0 $0 224 RT Software Limitation SDG&E San Diego 20 Jul 12 0 No INC 13 10:10 22: $0 $0 $ $0 $0 $0 $0 $0 225 RT Software Limitation SDG&E San Diego 28 Jul No INC 2 0:46 1: $894 $0 ($1,164) 0.00 $0 $0 $0 $0 $0 226 RT Stranded A/S or RUC Intertie N/A 2 Jul No DEC 2 7:59 8: $0 $0 $ $0 $0 $0 $0 $0 227 RT Stranded A/S or RUC Intertie N/A 2 Jul 12 0 No INC 2 7:59 8: $0 $0 $ $0 $0 $0 $0 $0 228 RT Stranded A/S or RUC PG&E Sierra 13 Jul Yes DEC 15 7:00 21: $0 ($3, $0 $3,813 $0 $0 $5,542 ) $0 229 RT Stranded A/S or RUC PG&E Sierra 13 Jul Yes INC 15 7:00 21: $8,880 ($38, $0 $0 $0 $0 $0 230 RT System Energy Intertie N/A 7 Jul Yes INC 1 16:00 16: $0 $0 $ $0 $0 $0 $0 $0 231 RT System Energy Intertie N/A 10 Jul Yes INC 1 18:00 18: $0 $0 $ $0 $0 $0 $0 $0 232 RT System Energy Intertie N/A 11 Jul Yes INC 10 14:00 23: $0 $0 $ $0 $0 $0 $0 $0 233 RT System Energy Intertie N/A 12 Jul Yes INC 21 0:00 20: $0 $0 $ $0 $0 $0 $0 $0 CAISO\MktAnls&Dvpmt Page 15

17 Num ber Mark et Type Reason Location Local Reliability Area Trade Date MW Comm itment INC_ DEC Hou rs Begin Time 234 RT System Energy Intertie N/A 22 Jul Yes INC 1 3:00 3: $0 $0 $ $0 $0 $0 $0 $0 ($27, RT Thermal Margin PG&E N/A 1 Jul No INC 13 11:00 23: $ $0 $0 $0 $0 $0 ($29, RT Thermal Margin PG&E N/A 2 Jul Yes INC 11 13:00 23: $114, $0 $0 $0 $0 $0 ($85, RT Thermal Margin PG&E N/A 3 Jul Yes INC 24 0:00 23: $243, ($1) $0 ($1) $0 $0 ($67, RT Thermal Margin SCE LA Basin 1 Jul No INC 24 0:00 23: $129, $0 $0 $0 $0 $0 ($66, RT Thermal Margin SCE LA Basin 2 Jul Yes INC 17 7:00 23: $34, $0 $0 $0 $0 $0 ($23, RT Thermal Margin SCE LA Basin 3 Jul Yes INC 24 0:00 23: $48, ($4) $0 ($2) $0 $0 ($11, RT Thermal Margin SCE LA Basin 4 Jul Yes INC 24 0:00 23: $50, ($5) $0 ($3) $0 $0 ($21, RT Thermal Margin SCE LA Basin 5 Jul Yes INC 24 0:00 23: $19, ($3) $0 ($1) $0 $0 243 RT Thermal Margin SCE LA Basin 9 Jul Yes DEC 5 19:00 23: $0 $0 $ $0 $0 $0 $0 $0 244 RT Thermal Margin SCE LA Basin 9 Jul Yes INC 5 19:00 23: $11,518 $0 ($4,368) ($1,949) $0 $0 $0 $0 ##### ($108, RT Thermal Margin SDG&E San Diego 2 Jul No INC 15 9:00 23: $58, ($742) $0 $0 $0 $0 # 9) ($116, RT Thermal Margin SDG&E San Diego 3 Jul No INC 23 1:00 23: $78, ($8,723) $0 ($1) $0 $0 $0 8) ($27, RT Thermal Margin SDG&E San Diego 4 Jul No INC 24 0:00 23: $88, ($2) $0 ($1) $0 $0 ($46, RT Thermal Margin SDG&E San Diego 5 Jul No INC 24 0:00 23: $74, ($2) $0 ($3) $0 $0 249 RT Transmission Outage Other PG&E Humboldt 17 Jul No INC 2 4:09 5: $0 $0 $ $0 $352 $0 ($297) $0 250 RT Transmission Outage Other PG&E Humboldt 23 Jul No INC 4 5:13 8: $1,026 $0 ($672) 9.63 ($196) $0 $0 ($117) $0 251 RT Transmission Outage PG&E PG&E Bay Area 2 Jul No INC 8 7:55 14: $3,638 $539 ($995) 0.00 $0 $0 $0 $0 $0 252 RT Transmission Outage PG&E PG&E Bay Area 3 Jul No INC 14 8:35 21: $10,994 $272 ($4,110) ($312) $0 $0 ($196) $0 ($18, RT Transmission Outage PG&E PG&E Fresno 22 Jul No INC 13 11:50 23: $16, $0 $0 $0 $0 $0 $257 ) ($19, RT Transmission Outage PG&E PG&E Fresno 23 Jul No INC 14 9:12 22: $41, ($183) $0 $0 ($127) $0 $283 ) ($10, RT Transmission Outage PG&E PG&E Fresno 24 Jul No INC 15 9:40 23: $24, ($10) $0 $0 ($10) $0 $268 ) ($14, RT Transmission Outage PG&E PG&E Fresno 25 Jul No INC 12 12:48 23: $24, ($228) $0 $0 $0 $0 $268 ) 257 RT Transmission Outage PG&E PG&E Fresno 26 Jul No INC 13 11:45 23: $21,091 $268 ($10, $0 $0 $0 $0 $0 End Time Total MWH Min Load Cost Start Up Cost ED MWH(INC/ DEC) INC DEC CC6482 CC6488 CC66 20 CAISO\MktAnls&Dvpmt Page 16

18 Num ber Mark et Type Reason Location Local Reliability Area Trade Date MW Comm itment INC_ DEC Hou rs Begin Time ) 258 RT Transmission Outage PG&E PG&E Fresno 27 Jul No INC 13 11:00 23: $19,609 ($10,404 $278 ) 0.00 $0 $0 $0 $0 $0 259 RT Transmission Outage PG&E PG&E Fresno 28 Jul No INC 11 12:25 22: $19,879 ($11,298 $268 ) 0.00 $0 $0 $0 $0 $0 260 RT Transmission Outage PG&E PG&E Fresno 29 Jul No INC 8 14:05 21: $20,171 ($59,612 $268 ) 0.00 $0 $0 $0 $0 $0 261 RT Transmission Outage PG&E PG&E Fresno 30 Jul No INC 13 11:30 23: $28,556 ($20,220 $268 ) 0.00 $0 $0 $0 $0 $0 262 RT Transmission Outage PG&E PG&E Fresno 31 Jul No INC 14 10:45 23: $33,538 ($32,284 $268 ) 0.00 $0 $0 $0 $0 $0 263 RT Transmission Outage PG&E PG&E Humboldt 2 Jul No INC 4 9:50 12: $1,524 $0 ($637) ($246) $0 $0 ($510) $0 264 RT Transmission Outage PG&E PG&E Humboldt 9 Jul No INC 7 11:49 17: $0 ($6, $0 $6,382 $0 $0 $7,145 ) $0 265 RT Transmission Outage PG&E PG&E Humboldt 10 Jul No INC 1 12:40 12: $0 $0 $ $0 $0 $0 $0 $0 266 RT Transmission Outage PG&E PG&E Humboldt 11 Jul No INC 10 13:07 22: $1,136 $114 $4, ($147) $59 $0 ($165) $0 267 RT Transmission Outage PG&E PG&E Humboldt 12 Jul No INC 8 15:00 22: $111 ($10, ($1) ###### $0 ($121) $0 268 RT Transmission Outage PG&E PG&E Humboldt 17 Jul No INC 21 3:30 23: $0 $0 $ $0 $570 $0 ($327) $0 269 RT Transmission Outage PG&E PG&E Humboldt 18 Jul No INC 24 0:00 23: $10,321 $0 $4, $0 $0 $0 $0 $0 270 RT Transmission Outage PG&E PG&E Humboldt 19 Jul No INC 18 0:00 17: $5,499 $0 $2, $0 $0 $0 $0 $0 271 RT Transmission Outage PG&E PG&E Humboldt 20 Jul No INC 24 0:00 23: $14,442 ($28,109 ($1, ($3,578) $0 $0 ) $0 272 RT Transmission Outage PG&E PG&E Humboldt 21 Jul No INC 24 0:00 23: $6,195 ($13, ($2,521) $0 $0 ($554) $0 273 RT Transmission Outage PG&E PG&E Humboldt 22 Jul No INC 24 0:00 23: $8,615 ($2, ($251) $0 $0 $0 ($3,107) ) $0 274 RT Transmission Outage PG&E PG&E Humboldt 23 Jul No INC 24 0:00 23: $7,405 ($1, ($1,393) $0 $0 $0 ($4,367) ) $0 275 RT Transmission Outage PG&E PG&E Humboldt 24 Jul No INC 24 0:00 23: $18,770 ($12,426 ($3, ($4,950) $0 $0 ) $0 276 RT Transmission Outage PG&E PG&E Humboldt 25 Jul No INC 1 0:00 0: $704 $0 ($616) 8.25 ($210) $0 $0 ($70) $0 277 RT Transmission Outage PG&E PG&E Humboldt 26 Jul No INC 9 7:53 15: $0 $0 $2, $0 $1 $0 $0 $0 278 RT Transmission Outage PG&E PG&E Humboldt 31 Jul No INC 7 8:17 14: $2,889 $0 ($7,550) ($534) $0 $0 ($38) $0 279 RT Transmission Outage PG&E PG&E NCNB 17 Jul No DEC 4 10:18 13: $0 ($6, $0 $2,828 $0 $0 $2,836 ) $0 280 RT Transmission Outage SDG&E SDG&E San Diego 7 Jul 12 0 Yes INC 2 17:04 18: $0 $0 $5, $0 $0 $0 $0 $0 281 RT Transmission Outage SDG&E SDG&E San Diego 8 Jul 12 0 Yes INC 3 15:55 17: $0 $0 ($47) 0.00 $0 $0 $0 $0 $0 282 RT Transmission Outage SDG&E SDG&E San Diego 10 Jul No DEC 2 12:10 13: $0 $0 $ $0 $0 $0 $0 $0 End Time Total MWH Min Load Cost Start Up Cost ED MWH(INC/ DEC) INC DEC CC6482 CC6488 CC66 20 CAISO\MktAnls&Dvpmt Page 17

19 Num ber Mark et Type Reason Location Local Reliability Area Trade Date MW Comm itment INC_ DEC Hou rs Begin Time 283 RT Transmission Outage SDG&E SDG&E San Diego 10 Jul 12 0 No INC 4 12:10 15: $0 $0 $ $0 $0 $0 $0 $0 284 RT Transmission Outage SDG&E SDG&E San Diego 11 Jul Yes DEC 9 12:10 20: $0 ($3, $0 $3,350 $0 $0 $3,350 ) $0 285 RT Transmission Outage SDG&E SDG&E San Diego 11 Jul 12 0 Yes INC 12 12:00 23: $0 $0 $ $0 $0 $0 $0 $0 286 RT Transmission Outage SDG&E SDG&E San Diego 12 Jul No DEC 7 13:00 19: $0 ($3, $0 $3,954 $0 $0 $3,954 ) $0 287 RT Transmission Outage SDG&E SDG&E San Diego 12 Jul 12 0 No INC 20 0:00 19: $0 ($6, $0 $6,125 $0 $0 $6,161 ) $0 288 RT Transmission Outage SDG&E SDG&E San Diego 13 Jul 12 0 Yes INC 1 14:00 14: $0 $0 ($0) 0.00 $0 $0 $0 $0 $0 289 RT Transmission Outage SDG&E SDG&E San Diego 15 Jul Yes INC 4 10:30 13: $5,421 $0 ($4,012) 6.96 ($173) $0 $0 ($3) $0 290 RT Transmission Outage SDG&E SDG&E San Diego 17 Jul 12 0 Yes INC 6 11:50 16: $0 $0 $ $0 $0 $0 $0 $0 291 RT Unit Testing PG&E N/A 9 Jul Yes INC 10 9:30 18: $0 $0 ($8,933) ($4,963) $0 $0 $0 $0 292 RT Unit Testing PG&E N/A 10 Jul Yes INC 10 8:25 17: $0 $0 ($4,632) 3.59 ($155) $0 $0 $0 $0 293 RT Unit Testing PG&E N/A 15 Jul Yes INC 11 8:10 18: $0 ($15, ($9,285) $0 $0 $0 $0 294 RT Unit Testing PG&E N/A 19 Jul Yes INC 8 11:55 18: $0 ($34, ($14,258) $0 $0 $0 $0 295 RT Voltage Support PG&E Fresno 10 Jul Yes INC 7 16:40 22: $14,432 ($16,108 $615 ) ($1,582) $0 $0 ($610) $0 296 RT Voltage Support PG&E Fresno 11 Jul No INC 14 10:30 23: $35,111 ($17,959 $268 ) 1.34 ($30) $0 $0 ($19) $0 297 RT Voltage Support PG&E Fresno 12 Jul No INC 15 9:55 23: $39,345 ($48,089 $268 ) 0.00 $0 $0 $0 $0 $0 298 RT Voltage Support PG&E Fresno 13 Jul No INC 24 0:00 23: $49,623 ($26,395 ($6, ($4,587) $0 $0 $335 ) ) $0 299 RT Voltage Support PG&E Fresno 14 Jul No INC 23 0:00 22: $17,154 $270 ($8,842) 0.00 $0 $0 $0 $0 $0 300 RT Voltage Support PG&E Fresno 15 Jul No INC 10 13:00 22: $20,364 ($15,422 $268 ) 0.04 ($1) $0 $0 ($1) $0 301 RT Voltage Support PG&E Fresno 16 Jul No INC 12 11:40 22: $14,980 $268 ($6,159) 0.00 $0 $0 $0 $0 $0 302 RT Voltage Support PG&E Fresno 17 Jul No INC 8 15:20 22: $9,831 $268 ($7,671) 0.00 $0 $0 $0 $0 $0 303 RT Voltage Support PG&E Fresno 18 Jul No INC 8 15:20 22: $12,704 ($11,393 $71 ) 0.71 ($21) $0 $0 ($0) $0 304 RT Voltage Support PG&E Fresno 19 Jul No INC 12 12:10 23: $25,638 ($86,054 $268 ) 0.33 ($8) $0 $0 ($4) $0 305 RT Voltage Support PG&E Fresno 20 Jul No INC 11 13:01 23: $20,710 ($70,843 $357 ) 0.00 $0 $0 $0 $0 $0 306 RT Voltage Support PG&E Fresno 21 Jul No INC 13 11:15 23: $31,643 ($76,674 $268 ) 0.72 ($16) $0 $0 $0 $0 307 RT Voltage Support PG&E Fresno 22 Jul No INC 13 11:38 23: $16,958 ($19,523 $279 ) 0.00 $0 $0 $0 $0 $0 End Time Total MWH Min Load Cost Start Up Cost ED MWH(INC/ DEC) INC DEC CC6482 CC6488 CC66 20 CAISO\MktAnls&Dvpmt Page 18