Market Performance and Planning Forum July 21, 2016 Market - PowerPoint PPT Presentation

ISO’s CPS1 score for the day was 63.9% and for 11 hours its hourly scores were below 100% on January 31 Wind/Solar vs. CPS1 --- 01/31/2016 3,500 400% 3,000 200% 2,500 0% Wind/Solar (MW) Hourly CPS1 (%) 2,000 -200% 1,500 -400% 1,000 -600% 500 -800% 0 -1000% CPS1 (Pass) CPS1>=100% Wind Solar CPS1<100% CPS1 is evaluated on a rolling 12-month average. Over the past few years, the rolling average has been declining as a result of some poor daily performances. Thus, the CAISO need to take measures to improve daily performance on days with higher variability. Page 49

January 31, 2016 is an example of a stormy day affecting both wind and solar production • The ISO’s daily CPS1 score for the entire day was 63.9% – Hourly average score was less than 100% for 11 different hours – For six of the 11 hours, the CPS1 scores were negative • The ISO depleted regulation up for approximately 35 minutes in HE15 and for approximately 15 minutes in HE16. • The ISO depleted regulation down for approximately 15 minutes during the beginning of HE14. Also, towards the end of HE15 and the beginning of HE16, regulation down was depleted for approximately 25 minutes. • When RTD run does not pick-up load, wind or solar variability at least 7.5 minutes before the dispatch interval, ramp deficiencies are not reflected in the 5-minute energy prices. Page 50

Regulation up was depleted in HE15 for approximately 35 minutes and for approximately 15 minutes in HE16 --- 1/31/2016 CPS1, ACE, Reg_Up --- January 31, 2016 1000 1200 1000 800 800 600 600 400 400 200 200 0 0 -200 -200 ACE & Reg Up (MW) -400 -400 -600 CPS1 (%) -600 -800 -800 -1000 -1000 -1200 -1200 -1400 -1600 -1400 -1800 -1600 -2000 -1800 -2200 -2000 -2400 -2200 -2600 -2400 -2800 1 2 3 4 5 6 7 8 9 10 11 12 1 2 3 4 5 6 7 8 9 10 11 12 1 2 3 4 5 6 7 8 9 10 11 12 14 15 16 Hours Avail Reg_Up ACE CPS1 Page 51

Regulation down was depleted for approximately 15 minutes during the beginning of HE14 and approximately 25 consecutive minutes in HE15 & HE16 --- 1/31/2016 CPS1, ACE, Available Reg_Down --- January , 2016 1000 1200 1000 800 800 600 600 400 400 200 200 0 0 ACE & Reg Down (MW) -200 -200 -400 -400 CPS1 (%) -600 -600 -800 -800 -1000 -1000 -1200 -1200 -1400 -1600 -1400 -1800 -1600 -2000 -1800 -2200 -2000 -2400 -2200 -2600 -2400 -2800 1 2 3 4 5 6 7 8 9 10 11 12 1 2 3 4 5 6 7 8 9 10 11 12 1 2 3 4 5 6 7 8 9 10 11 12 14 15 16 Hours Available Reg Down ACE CPS1 Page 52

Analyzing Forecast Uncertainty 3/24/2016 30,000 15,000 13,000 25,000 11,000 20,000 Wind Forecast 9,000 Solar Forecast MW System TAC Load Forecast 15,000 7,000 Net Load Forecast Renewable Total 5,000 Solar Limit 4200 10,000 Wind Limit 2200 3,000 5,000 1,000 0 (1,000) Page 53

Factors related to forecast uncertainty • Net Load below 22,000 MWs • Forecast for Over Speed Wind Cut Out Events • Variable Solar Production due to: – Cloud Cover Changes throughout daytime hours – High, Medium, Low Cloud Cover – Forecasted Break in Clouds leading to high variability for Utility Scale and Behind the Meter Generation • Variable Wind Production due to: – Significant Ramp Up and Down Forecast – Cold Front Coming through creating uncertainty in the timing of the ramp – High Wind Penetration with a change in wind direction causing variability in turbine generation. Page 54

Regulation Requirements --- February through June 2016 Regulation Up Procurement in February, 2016 Regulation Up Procurement in March, 2016 900 900 800 800 700 700 600 600 500 500 MW MW 400 400 300 300 200 200 100 100 0 0 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 Day Day Regulation Up Procurement in May, 2016 Regulation Up Procurement in April, 2016 700 700 600 600 500 500 400 400 MW MW 300 300 200 200 100 100 0 0 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 Day Day Regulation Up Procurement in June, 2016 700 600 500 400 MW 300 200 100 0 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 Day Page 55

Original estimate of net-load as more renewables are integrated into the grid Typical Spring Day Actual 3-hour ramp 10,892 MW on February 1, 2016 Net Load 11,663 MW on May 15, 2016 Page 56 California ISO Confidential

Generation breakdown and renewable curtailment on May 15, 2016 Generation Breakdown ---05/15/2016 30,000 Renewables Net Load = Load -Wind -Solar Curtailment 28,000 26,000 24,000 22,000 20,000 18,000 MW 16,000 14,000 12,000 10,000 8,000 6,000 4,000 2,000 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Nuclear Thermal Hydro Net Interchange Geothermal/Biomass/Biogas Wind Solar Curtailment Total CAISO Load CAISO Net Load Page 57 California ISO Confidential

Negative energy prices indicating over-supply risk start to appear in the middle of the day Distribution of Negative Prices - March, April & May 2012 through 2016 350 Increasing real-time negative energy price frequency indicates over- 300 generation risk in the # of Occurrences RTD Prices < Zero middle of the day 250 200 150 100 50 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 2012 2013 2014 2015 2016 Page 58 California ISO Confidential

Ongoing regulation projects between the ISO and Pacific Northwest Lab and AWS Truepower • Technology Commercialization Project – DOE funded – Use probabilistic forecasts to help determine the intra-hour ramping needs – Hourly regulation levels needed in the day-ahead timeframe • SunLamp: Solar Centered Grid Project – DOE funded – Identify variability and uncertainty among different BAs – Develop methodology to minimize regulation usage among different BAs – Identify benefits to real-time operations by combining BAAL and CPS1 Page 59

Day-ahead load forecast 3.0% 2.0% MAPE 1.0% 0.0% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 2015 2016 Day-ahead load forecast w/o 6/21 and 6/22 3.0% 2.0% MAPE 1.0% 0.0% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 2015 2016

Day-ahead peak to peak forecast accuracy 4.0% 3.0% 2.0% MAPE 1.0% 0.0% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 2015 2016 Day-ahead peak to peak forecast w/o 6/21 and 6/22 3.0% 2.0% MAPE 1.0% 0.0% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 2015 2016

June DA Forecast Deeper Dive

Temperature Trend 6/20/2016-6/22/2016

Day-ahead wind forecast 10.0% 9.0% 8.0% 7.0% 6.0% 5.0% 4.0% MAE 3.0% 2.0% 1.0% 0.0% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 2015 2016

Day-ahead solar forecast 14.0% 12.0% 10.0% 8.0% 6.0% MAE 4.0% 2.0% 0.0% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 2015 2016

Energy Imbalance Market performance with the addition of NV Energy Gabe Murtaugh Senior Analyst, Department of Market Monitoring Page 66

Energy Imbalance Market performance with the addition of NV Energy • A comparison of the energy imbalance market before and after the introduction of NV Energy reveals that: – PacifiCorp prices in 2015 were driven by local market conditions, constraint relaxations and the lack of transmission with the ISO. – NV Energy significantly increased the available transmission between the ISO and PacifiCorp East. – Prices within NV Energy, PacifiCorp East and the ISO frequently reflected the system marginal price after NV Energy integration. Page 67

Fifteen-Minute Market prices in PacifiCorp East $90 36 Bilateral hub price range Average number of constraint relaxations per day (15- Power balance shortage $80 32 Flexible ramping constraint PacifiCorp East price $70 28 Average monthly price ($/MWh) Price without price discovery or load bias limiter $60 24 minute intervals) $50 20 $40 16 $30 12 $20 8 $10 4 $0 0 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun 2015 2016 Page 68

EIM transfer capacity between EIM balancing areas: January-November 2015 Average total EIM transfer capacity PacifiCorp (15-minute market) West 190 MW 258 MW 205 MW 0 MW* PacifiCorp East CAISO Page 69

EIM transfer capacity between EIM balancing areas: January-May 2016 Average total EIM transfer capacity PacifiCorp (15-minute market) West 300 MW 152 MW 80 MW 0 MW* PacifiCorp 705 MW 891 MW East NV Energy CAISO 453 MW 858 MW Page 70

Congestion in the 15-Minute EIM market: January-May 2016 Percentage of 15-minute intervals congested PacifiCorp (Average transfer limit during congestion) West 9% (29MW) 17% 2% 54% (148 MW) (222 MW) (0 MW) PacifiCorp 0% 0% East NV Energy CAISO 3% 1% ( 816MW) (386 MW) Page 71

Fifteen-minute market prices in NV Energy $60 12 Bilateral hub price range Average number of constraint relaxations per day (15- Power balance shortage $50 10 Flexible ramping constraint NV Energy price Average monthly price ($/MWh) $40 8 Price without price discovery or load bias limiter minute intervals) $30 6 $20 4 $10 2 $0 0 Dec Jan Feb Mar Apr May Jun 2015 2016 Page 72 Last updated: July 20, 2016

Hourly settlement prices in PacifiCorp (Jan-May 2016) $70 Bilateral hub price range PacifiCorp East settlement price $60 PacifiCorp West settlement price Average hourly price ($/MWh) PG&E settlement price $50 $40 $30 $20 $10 $0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Page 73 Last updated: July 20, 2016

Hourly settlement prices in NV Energy (Jan-May 2016) $70 Bilateral hub price range NV Energy settlement price $60 SCE settlement price Average hourly price ($/MWh) $50 $40 $30 $20 $10 $0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Page 74 Last updated: July 20, 2016

Hourly EIM imports into NV Energy (April-June 2016) 500 ISO PacifiCorp East Net 400 300 Imports into NV Energy (MW) 200 100 0 -100 -200 -300 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Page 75 Last updated: July 20, 2016

Policy Update Brad Cooper Manager, Market Design and Regulatory Policy Page 76

Ongoing policy stakeholder initiatives • Contingency modeling enhancements – On hold • Generator contingency and remedial action scheme modeling – Straw proposal targeted for Aug-Sep – 2017 Q1 Board meeting, projected Fall 2018 implementation • Bid cost recovery enhancements – Moving self- schedule’s exemption from IFM cost allocation to separate initiative – Revised straw proposal targeted for August – 2017 Q1 Board meeting – Projected Fall 2018 implementation Page 77

Ongoing policy stakeholder initiatives (continued) • Stepped transmission constraints – Moving lowered bid floor to separate initiative – Conducting analysis, straw proposal targeted for Q3 – 2017 Q2 Board meeting, projected Fall 2018 implementation • Reliability services – phase 2 – Revised draft final proposal posted on July 7 – Stakeholder call held on July 14 – Aug 2016 Board Page 78

Ongoing policy stakeholder initiatives (continued) • Flexible resource adequacy criteria and must-offer obligation – phase 2 – Scope revised to include assessment of existing flexible capacity product – Developing new schedule, Board date TBD • Reactive power and financial compensation – Addendum to draft final proposal to be posted on July 21 – August 2016 Board Page 79

Ongoing policy stakeholder initiatives (continued) • Metering rules enhancements – August/September 2016 Board meeting – Projected Fall 2018 implementation • Energy storage and distributed energy resources (ESDER) Phase 2 – Revised straw proposal to be posted on July 20 – Stakeholder call on revised straw proposal on July 28 – Board meeting to be determined Page 80

Ongoing policy stakeholder initiatives (continued) • Transmission access charge options – Next proposal to be posted in early September – No sooner than October Board • Regional resource adequacy – Next proposal to be posted in early September – No sooner than October Board Page 81

Policy stakeholder initiatives coming soon • Planned to start in Q3 – Gas cost enhancements – ISO tariff load serving entity – Self schedules BCR allocation and bid floor – Regional integration CA greenhouse gas compliance • Planned to start in Q4 – Frequency response – phase 2 Page 82

Release Plan Update Janet Morris Director, Program Office Page 83

Release Plan 2016 Independent 2016 • Aliso Canyon Initiative • Demand Response Registration Enhancements • Capacity Procurement Mechanism Replacement • Reliability Services Initiative • Commitment Cost Enhancements Phase 2 (remainder) • RIMS Functional Enhancements Fall 2016 • Energy Imbalance Market (EIM) 2016 Arizona Public Service (APS) • Energy Imbalance Market (EIM) 2016 Puget Sound Energy (PSE) • OMAR Replacement • BAL-003 Compliance • Flexible Ramping Product • BCR modifications and VER settlement • Acceptable Use Policy - CMRI • PIRP System Decommissioning • Energy Imbalance Market (EIM) Year 1 Enhancements Phase 2 • Energy Storage and Distributed Energy Resources (ESDER) Page 84

Release Plan 2017 Independent 2017 • RTD Local Market Power Mitigation (LMPM) Enhancements • CRR Clawback Modifications Fall 2017 (tentative, to be confirmed) • Reliability Services Initiative Phase 1B • Bidding Rules Enhancements – Part B • Stepped Constraints • Commitment Cost Enhancement Phase 3 • Bid Cost Recovery Enhancements • Contingency Modeling Enhancements • EIM 2017 Portland General Electric (PGE) • ADS User Interface Replacement Spring 2018 • EIM 2018 Idaho Power Company Fall 2018 (tentative, to be confirmed) • Metering Rules Enhancements • Transmission Access Charge Options Subject to further release planning: • Additional Data Transparency Enhancements (OASIS API changes) • Additional OMS Enhancements • Reliability Services Initiative Phase 2 • Flexible Resource Adequacy Criteria and Must-offer Obligation Phase 2 • Regional Resource Adequacy • Reactive Power Requirements and Financial Compensation Page 85

2016 – Aliso Canyon Project Info Details/Date Purpose: explore market mechanisms or other tools to mitigate the risks to gas and electric markets to avoid electric service interruptions to the extent possible. SIBR: • Allow MP to rebid commitment costs for hours without a day-ahead schedule or for RTM commitment periods until the minimum run time expires. SIBR rule change needed. Until implementable, tariff rule was included and monitoring will be needed. • No longer generate RT bids for non-resource adequacy resources or RA resources without a MOO. STUC bidding rule change. Bid Replication (stop creating bids that do not have a MOO for STUC). Current rule: create STUC bids if DAM clean bid exists for resource. New rule: create STUC bids if 1) DA schedule or RUC schedule exists; or 2) Resource is MOO. Settlements: • Leverage existing Good Faith Negotiation (GFN) to recover additional fuel costs • Create and configure a Pass Through Billing (PTB) to accommodate FERC awarded amount Application Software Changes due to “After the Fact Cost Recovery Process” (No system Changes) CMRI: • New report to show the D+2 RUC Schedule. Will use standard CMRI report and IFM web services to do as part of Peak RC requirements, but will monitor as part of Aliso Canyon due to dependency. Integration: • Integration between ECIC, ICE, and market system will be needed depending on payload impacts Nomogram: • Expand number of variables from 25 to 150. This will help apply the constraint to all resources impacted by Aliso Canyon restriction. There are 6 zones and one for all zones. • Potential performance issue with simultaneous constraints • Non-Competitive Overwrite (UI change) MasterFile • Manual process to add, change, fuel regions BPM Changes Market Instruments, Market Operations, Settlements & Billing Page 86

2016 – Aliso Canyon Milestone Type Milestone Name Dates Status  Board Approval Board of Governors Approval May 04, 2016  BPMs Post Draft BPM changes (Addendums) - MO, MI, CRR May 31, 2016  External BRS External Business Requirements May 17, 2016  Post Revised External BRS Jun 02, 2016  Tariff File Tariff May 06, 2016  Receive FERC order Jun 01, 2016 Config Guides Post Draft Configuration Guides N/A Tech Spec Create ISO Interface Spec (Tech spec) N/A Market Sim MARKET SIMULATION N/A Production Activation  Production - Aliso Canyon Phase 1 Jun 02, 2016  Production - Aliso Canyon Phase 2 Jul 06, 2016 Note: SIBR Rules posted 5/12/16 Page 87

2016 – Aliso Canyon No Feature Section Numbers Effective Date Introduce a constraint as needed into the CAISO’s market processes 1 27.11 June 2, 2016 to limit the affected gas area burn to a maximum or minimum 2 Reserve internal transfer capability to respond to real-time load 27.5.6 June 2, 2016 fluctuations or provide contingency reserve in southern California 3 Special tariff to deem selected constraints uncompetitive 39.7.2.2 June 2, 2016 4 Clarification that ISO has authority to suspend virtual bidding in the 7.9.2 (d) June 2, 2016 event that the CAISO identified market inefficiencies 5 Make two-day ahead advisory schedules available with the 6.5.2.2.3 June 2, 2016 clarification that they are not financially binding or operationally binding 6 Adjust the gas price indexes used to calculation commitment and 39.7.1.1.1.3 (d) July 6, 2016 default energy bids for affected resources on the SoCalGas/SDG&E system 7 July 6, 2016 Use current gas price information to increase efficiency of economic 6.5.2.3.4 dispatch 30.4.1.2 31.6.1 39.1.1.1.1.3 (a)(b)(c) and deleting old (b) 8 30.5.1(b) June 2, 2016 Permit market participants to rebid commitment costs in the real-time market 9 Permit participants to file with FERC to recover fuel costs 30.11 June 2, 2016 39.7.1.1.3 40.6.8.1.7 10 Adjust monthly CRR FNM 36.4 June 2, 2016 11 Modifications to STUC so that STUC does not use Day-Ahead bids 34.6 June 2, 2016 of resources not scheduled in day-ahead 40.6.3 Page 88

2016 – Aliso Canyon Market Notice issued 7/1/16 announcing the 7/6/16 activation: Please note the following from the notice: The ISO will activate Phase 2 of the Aliso Canyon Gas-Electric Coordination initiative effective trade date July 6, 2016. Although the functionality is activated, the ISO will delay the use of Intercontinental Exchange (ICE) gas prices to calculate commitment and default energy bids for affected resources in the Southern California Gas Company and San Diego Gas & Electric systems pending confirmation that the gas prices conform to the Federal Energy Regulatory Commission (FERC)'s policy statements on gas prices. The ISO has filed a waiver request with FERC to retain the existing tariff provisions in the interim. All other Phase 2 changes will be implemented as scheduled. Page 89

2016 – Demand Response Registration Enhancements Project Info Details/Date Enhance Demand Response Registration functionality and processes Application Software Changes Develop new registration user interface for DRRS Develop new APIs for support of enhanced registration processes BPM Changes Metering Business Process Changes Automation of internal registration-related processes User Training Thursday, June 2, 2016 Milestone Type Milestone Name Dates Status Board Approval Board Approval N/A BPMs Post Draft BPM changes (Metering) Jul 18, 2016 Publish Final Business Practice Manuals (Metering) Aug 08, 2016 External BRS - Enabling Demand Response Phase 2 -  External BRS Jun 04, 2015 Registration Tariff Tariff N/A Config Guides Config Guide N/A  Tech Spec Tech Specs - DRRS Phase 2 - Registration Sep 17, 2015 Market Sim Market Sim Window Aug 08, 2016 - Sep 02, 2016 Production Activation Post-Mrkt Consol - DRRS Phase 2 - Reg Sep 19, 2016 Page 90

Independent 2016 Market Simulation Market Simulation Dates – RSI, CPM, Commitment Costs Phase 2, and OMS Enhancements 3/15 – 8/19: RSI/CPM Session 2 (Unstructured and Structured E2E) Link to Independent 2016 Release Market Simulation Plan - http://www.caiso.com/Documents/MarketSimulationPlanInd ependent2016Release.pdf Page 91

2016 – Capacity Procurement Mechanism Replacement (CPM) Project Info Details/Date Competitive Solicitation Process (CSP): CSP replaces the existing administrative price process for annual, monthly and intra-monthly CPM events for flexible and generic RA capacity. CSP will cover all events that allow the ISO to procure additional capacity. CIRA: − Bid Submittal system for SCs to submit capacity bids (not an existing bid type) − Capacity bids to implement new validation rules (not an existing bid type) − Capacity Bid submittal to be on a yearly, monthly, and intra-monthly level − LSE/LRA deficiency calculation to be performed for CSP for Generic and Flexible RA data − Existing CPM calculation to be deprecated for trade dates after the effective date of implementation. − Manage import allocation and bilateral trades of import allocation Application Software Changes Settlements: Settlements will need new CPM formulas that will result in charge code impacts. Reporting: If an annual or monthly CPM occurs greater than two times (over a rolling 24 month period) or more than 50% of the LSE’s RA requirement is CPMed, a report must be given to Market Participants. OASIS: − Publish all finalized offers into the competitive solicitation process on a rolling five-quarter delay. (Deferred) − Solicitation for soft offer cap. Timeline for submittal needs to be defined. − Submittal process for annual/monthly CPM bid submittal Business Process Changes − New business process for amount of capacity being relied on (non-RA from partial RA) − New process for Competitive Solicitation Process (annual/month/intra-monthly) Page 92

2016 – Capacity Procurement Mechanism Replacement (cont.) Milestone Details/Date Status Reliability Requirements – PRR issued 11/4/15 BPM Changes Market Instruments – issue PRR 1/8/16 - Billing & Settlements – PRR issued 1/11/16 − Solicitation for soft offer cap. Timeline for submittal needs to be defined. − Submittal process for annual/monthly CPM bid submittal Business Process Changes − New business process for amount of capacity being relied on (non-RA from partial RA) − New process for Competitive Solicitation Process (annual/month/intra-monthly) Board Approval February 5, 2015 External BRS March 31, 2015 Tariff Filed: May 26, 2015 FERC Approved: October 1, 2015 CIRA Session 1  Fall 2016, MPs will use UIs Technical Specifications OASIS Session 2  Fall 2016 Draft Configuration Guides November 23, 2015 Session 2 October 21, 2015: Session 1 – Onsite w/Webinar, Full Day (combined w/ CPG Call) • Training Materials – posted SP & RP page on 10/19 External Training January 6, 2016: Session 2 - Onsite w/ Webinar option, Full Day • Training Materials – post 1/5 Page 93

2016 – Capacity Procurement Mechanism Replacement (cont.) Milestone Details/Date Status April 11 – May 6, 2016: Session 2 • 4/11-4/15: Unstructured • 4/18-4/22: Structured Week 1& 2 • 4/25-4/29: Structured Week 3 - On-Site 4/26-4/29 • 5/2-5/27: Unstructured Market Simulation • 7/18-7/22: Re-run Structured Week 1 & 2 • 7/25-7/29: Re-run Structured Week 3 • Post Structured Scenarios • SIBR Rules, Release Notes, Specs posted – 12/11 • CIRA User Guide – 1/18 11/1/2016: Session 2 Effective Date - FERC Approved Production Activation Page 94

2016 – Reliability Services Initiative (RSI) – 1A Project Info Details/Date CIRA: − Manage new NQC/EFC process request for resource types. This will impact both internal users and Market Participants − Manage Import Allocation (CPM Replacement initiative is covering this scope but is needed for this initiative) − Manage RA obligation (taking into consideration substitution capacity and replacement capacity as RA capacity) will impact RA, Settlements, market, and outage. The output of CSP will be needed − Publish RA Obligations externally − Display Comparative snapshot of DA/RT obligation (outages, energy bids, RA obligation). Display input of RAAIM calculations − Display SCP and CPM availability calculation output for historic trade dates − Creation of substitution rules for flexible resource adequacy resources − Modify existing DA/RT generic substitution rules − DA substitution timeframe shall change from 6 AM to 8 AM − Enable the release of substitute capacity for generic and flexible resources Application Software Changes − Allow imports to substitute for other imports and CAISO system resources. The RA obligation will be at a daily level − Use result of Pre-qualification analysis (the pre-qualification analysis is a manual process) for real time substitution validation − API for substitution and release functionality − Enable Generic CPM substitutions − Enable Flexible CPM substitutions − Build Submit & Retrieve APIs to support Substitutions (4 types) and release of sub capacity − Substitution will now be in CIRA − Addition of RAAIM exempt and planned outage exemption flag − Allow the outage correction process to exempt outage from RAAIM calculations up to 5 business days OMS: − Add 5 nature of work attributes and various validations − Remove SCP Exempt flag from display Page 95

2016 – Reliability Services Initiative (cont.) -1A Project Info Details/Date Status MasterFile: − Will store Use Limit Plan. There will be a new template (ULPDT – Use Limit Plan Data Template) RAAM: − Decommission RAAM Settlements: RAAIM (RA Availability Incentive Mechanism) NEW – replaces SCP for backstop. - Current SCP will retire with implementation of RAAIM. Will assess whether generic and flexible RA resources comply with MOO and better captures use limited resource Application Software Changes availability. - New charge code changes are needed for implementation of the RA Reporting: - Report on the effectiveness of the RAAIM results (1 year after implementation) (Deferred) Other: - Modification of Use Plan with new validation rules - LSE cost allocation methodology needs to automated. - Publish list of all available prequalification combinations Page 96

2016 – Reliability Services Initiative (cont.) – 1A Milestone Details/Date Status Reliability Requirements - issued PRR #888 on 1/12/16 BPM Changes Outage Management - issued PRR #889 on 1/12/16 Billing & Settlements - issued PRR on 1/11/16 − Process to assign NQC values to NGR/PDR/DG resources − Process for PDR/NGR/DG testing Business Process − Process for RA Availability Incentive Mechanism (RAAIM). Must retire SCP business process flows. Changes − Modify DA/Real Time Substitution Process − Process for allocating year end unallocated RA Availability Incentive Mechanism (RAAIM) funds Board Approval March 26, 2015 External BRS March 31, 2015 Tariff Filed: May 28, 2015 FERC Approved: October 1, 2015 CIRA Session 2  Fall 2016, MPs will use UIs MasterFile Session 2 • posted tech spec 9/24 on Release Planning Page • Technical Specifications posted ULDT 9/11 to RP page • posted ULR documentation/ sample templates to RP page on 12/4 OMS Session 2 • posted tech spec 12/2 Draft Configuration November 23, 2015 Session 2 Guides Page 97

2016 – Reliability Services Initiative (cont.) – 1A Details/Date Milestone Status January 6, 2016: Session 2 – Onsite w/ optional Webinar, Full Day External Training • Training Materials – post 1/5 April 11 – May 6, 2016: Session 2 • 4/11-4/15: Unstructured • 4/18-4/22: Structured Week 1& 2 • 4/25-4/29: Structured Week 3 - On-Site 4/26-4/29 • 5/2-5/27: Unstructured • 7/18-7/22: Re-run Structured Week 1 & 2 • 7/25-7/29: Re-run Structured Week 3 • 8/8: MOO Flag API be available in MAP Stage for unstructured testing Market Simulation • Post Structured Scenarios • SIBR Rules, Release Notes, Specs posted – 12/11/15 • CIRA User Guide – 1/18/16 • MF UI User Guide – 1/6/16 • OMS User Guide – embedded in application • CIRA User Guide – 1/18/16 Production Activation 11/1/2016: Session 2 Effective Date - FERC Approved Page 98

2016 – Commitment Costs Phase 2 Project Info Details/Date For the Early Jan 2016 release, the project will • Clarify definition, qualifications, and requirements for use-limited resources • Implementation of the use limited definition (No longer applicable) • Implement revised must-offer rules • Application Software Changes Impacted Systems: • MF • SIBR CCE2 Early 2016 release implementation will be coordinated as part of the Reliability Services Initiative (RSI) project Milestone Type Milestone Name Status Board Approval Yes. March 26-27, 2015 Filed: May 28, 2015 Approved in Part: September 9, 2015 Tariff (FERC rejected the proposed revisions to the definition of “use limited resources”, but approved all other tariff revisions.) Market Operations (Use Plan) – issued PRR #887 on 1/11/16 BPM Changes Business Process Changes No External Business Requirements November 24, 2015 Technical Specifications No January 6, 2016: Session 2 – Onsite w/ optional Webinar, Full Day External Training • Training Materials – post 1/5 Draft Configuration Guides No February 8 th , 2016 – July 29 th , 2016 (Unstructured) Market Simulation Production Activation 11/1/2016: Session 2 Effective Date - FERC Approved Page 99

2016 – RIMS Functional Enhancements Project Info Details/Date Status Functional enhancements resulting from the Customer Partnership Group CPG. Application Software Changes More details to be provided in the future. Generator Interconnection and Deliverability Allocation Procedures Generator Interconnection Procedures Managing Full Network Model BPM Changes Metering Generator Management Transmission Planning Process Customer Partnership Group 10/16/15 Application and Study Webinar 3/31/16 Milestone Type Milestone Name Dates Status Board Approval Board approval not reqiured N/A  BPMs Generator Interconnection and Delivery Allocation Apr 29, 2016 External BRS External BRS not Required N/A Tariff No Tariff Required N/A Config Guides Configuration Guides not required N/A Tech Spec No Tech Specifications Required N/A  Production Activation RIMS5 App & Study Mar 21, 2016 RIMS5 Queue Management, Transmission and Generation Oct 31, 2016 Page 100