MCE Technical Committee
June 5, 2026

MCE Technical Committee Meeting
Friday, June 5, 2026
10:00 a.m.
1125 Tamalpais Avenue
San Rafael, CA 94901
2300 Clayton Road, Suite 1500
Concord, CA, 94520
Public comments may be made in person or remotely via the details below.

Remote Public Meeting Participation
Video Conference: https://t.ly/QzAmo
Phone: Dial (669) 900-9128, Meeting ID: 828 5103 7385, Passcode: 142534 DISABLED ACCOMMODATION: If you are a person with a disability who requires an accommodation or an alternative format, please contact MCE at (888) 632-3672 or [email protected] at least 72 hours before the meeting start time to ensure arrangements are made.

The Technical Committee may discuss and/or take action on any or all of the items listed on the agenda irrespective of how the items are described.

Agenda Page 1 of 2

1. Roll Call/Quorum

2. Board Announcements (Discussion)

3. Public Open Time (Discussion)

4. Report from Chief Executive Officer (Discussion)

5. Consent Calendar (Discussion/Action)
C. 1. Approval of 5.1.26 Meeting Minutes

6. Integrated Resource Plan Proceeding (Discussion/Action)

7. 2026 Open Season (Discussion)
Agenda Page 2 of 2

8. Modification to Committee Process for Agenda Setting (Discussion/Action)

9. Member Requests for Future Agenda Items (Discussion/Action)

10. Committee & Staff Matters (Discussion)

11. Adjourn
DRAFT

MCE TECHNICAL COMMITTEE MEETING MINUTES
May 1, 2026
10:00 A.M.

Present: Stephanie Andre, City of Larkspur
Dion Bailey, City of Hercules, Chair, left at 10:32 a.m.

John McCormick, City of Lafayette
Devin Murphy, City of Pinole, left at 11:47 a.m.

Charles Palmares, City of Vallejo, joined at 10:07 a.m.

Amanda Szakats, City of Pleasant Hill, left at 11:33 a.m.

Staff
& Others: Jesica Brooks, Lead Board Clerk and Executive Assistant John Dalessi, Pacific Energy Advisors
Kirby Dusel, Pacific Energy Advisors
CB Hall, Director of Power Resources
Vicken Kasarjian, Chief Operating Officer
Tanya Lomas, Board Clerk
Linda Lye, Senior Legal Counsel
Stephen Mariani, Manager of Power Resources
Catalina Murphy, General Counsel
Justine Parmelee, VP of Internal Operations
Mike Rodriguez-Vargas, Internal Operations Assistant
Sabrinna Soldavini, Vice President of Policy
Jamie Tuckey, Chief Customer Officer
Dawn Weisz, Chief Executive Officer

1. Roll Call
Chair Bailey called the regular Technical Committee meeting to order at 10:00 a.m. with quorum established by roll call.

2. Board Announcements (Discussion)
There were no comments.

3. Public Open Time (Discussion)
Chair Bailey opened the public comment period and there was a comment from member of the public, Jody Timms.

4. Report from Chief Executive Officer (Discussion)
Dawn Weisz, CEO, introduced this item.

Chair Bailey opened the public comment period and there were no comments.

DRAFT

5. Consent Calendar (Discussion/Action)
C.1 Approval of 4.3.26 Meeting Minutes

6. Committee Process for Agenda Setting
a. Consideration of Agenda Setting Process (Discussion/Action) b. Member Request for Future Agenda Items (Discussion/Action) Chair Bailey and Vice Chair Palmares introduced this item and addressed questions from Committee members.

Chair Bailey opened the public comment period and there was a comment from member of the public, Jody Timms.

Action: It was M/S/C (Murphy/McCormick) to approve the recommendation to a. Add a standing item to each Technical Committee meeting agenda as follows:

Member Request for Future Agenda Items* (Discussion/Action) *Committee Members may request items to be considered for future agendas. An item requested by a Committee Member will only be brought forward with a majority vote and it will appear on a future agenda for discussion only. After discussion and a majority vote, the item will be added to a future agenda for action with staff recommendations for further Committee consideration.

Motion carried by roll call vote. 5-Yays 1-No (No: Szakats).

After the motion was adopted, there was further discussion about the agenda setting process, as adopted. Staff indicated they would follow up with the Chair to ensure the process accomplishes the Committee’s goal of impartiality and streamlining in the agenda setting process.

Director Palmares took over as Acting Chair after agenda item 6.

7. Integrated Resource Plan and Power Procurement (Discussion) Sabrinna Soldavini, VP of Policy, Stephen Mariani, Manager of Power Resources, John Dalessi, President and CEO of Pacific Energy Advisors, and Action: It was M/S/C (Szakats/McCormick) to approve Consent Calendar item C.1. Motion carried by unanimous roll call vote.

DRAFT
Kirby Dusel, Vice President of Pacific Energy Advisors, presented this item and addressed questions from Committee members.

Acting Chair Palmares opened the public comment period and there was a comment from member of the public, Robert Miller.

Action: No action required.

8. Committee & Staff Matters (Discussion)
This item was not discussed due to loss of quorum.

9. Adjournment
Acting Chair Palmares adjourned the meeting at 11:47 a.m. to the next scheduled Technical Committee Meeting on June 5, 2026.
___________________________________________
Charles Palmares, Acting Chair
Attest:
___________________________________________
Justine Parmelee, Secretary
June 5, 2026
TO: MCE Technical Committee
FROM: Sabrinna Soldavini, Vice President of Policy
Johnstone Kipyator, Principal Manager, Power Analytics
Sai Powar, Policy Analyst
RE: Integrated Resource Plan Proceeding (Agenda Item #06) ATTACHMENTS: A. Presentation – Integrated Resource Plan Proceeding B. MCE 2022 Integrated Resource Plan
C. Key Acronyms
Dear Technical Committee Members:

Summary:

Staff requests feedback on the guiding principles used in preparing MCE’s 2026 Integrated Resource Plan (IRP), and draft Preferred Conforming Portfolio (PCP). MCE’s IRP is due to the California Public Utilities Commission (CPUC) on August 10, 2026. In accordance with this Board’s authority granted in Public Utilities Code (Code) Sections 366.2(a)(5) and 454.52(b)(3) and 454.52(b)(3), staff plans to bring the proposed IRP for Board consideration in July and submit it to the CPUC on August 10, 2026.

Background:

Code Section 454.52 requires all CPUC jurisdictional load serving entities (LSE), including Community Choice Aggregators (CCA) like MCE, to file an IRP with the CPUC every two years.1 The IRP encompasses a long-term planning horizon and details the procurement plan each LSE has adopted to meet the state’s goals of reducing greenhouse gas (GHG) emissions and maintaining reliability.

To reinforce the procurement autonomy of CCAs, Section 454.52(b)(3) requires that the IRP of a CCA be submitted to its governing board for approval and requires that the IRP meet the following:
(A) Economic, reliability, environmental, security, and other benefits and performance characteristics that are consistent with the goals of achieving 40% reduction in GHG emissions from 1990 levels by 2030 and procure 50% renewable energy resources by December 31, 2030.
1 While LSEs are generally required to submit IRP’s every two years, the CPUC delayed the 2024 IRP LSE submission cycle to 2026.
(B) A diversified procurement portfolio consisting of both short-term and long-term electricity and electricity-related and demand reduction products. (C) Resource Adequacy requirements.

Introduction
The Integrated Resources Planning (IRP) proceeding is an “umbrella” procurement planning process overseen by the CPUC that considers all of the CPUC’s policies and programs to ensure the state has a safe, reliable, and cost-effective electric supply”.
2 This is an iterative process with two tracks:

1. Planning: CPUC staff model and build a Preferred System Plan (PSP) for the state’s overall resource portfolio on a forward-looking basis. The PSP is based on load forecasts developed by the California Energy Commission (CEC), policy goals for renewable procurement and reliability, and GHG reduction targets. The PSP is a modelling scenario and represents the CPUC’s assumptions for an optimal resource portfolio that achieves the GHG benchmarks at least cost, while maintaining reliability. The CPUC allocates a portion of the PSP to individual LSEs like MCE, proportional to their load. Each LSE then submits a PCP as part of their individual IRPs to meet state targets and align with the PSP. PCPs submitted in an IRP year inform the next iteration of a 2-year process.
o IRP development is one step of a long-term, multi-year, iterative, and interconnected statewide planning process that spans multiple state agencies and LSEs. Most importantly, the PSP informs the California Independent System Operator’s (CAISO) Transmission Planning Process (TPP).

2. Procurement: The CPUC aggregates individual LSEs’ IRPs and measures the state’s progress on reliability and renewable procurement. Based on its evaluation, the CPUC determines the need for additional procurement to fill identified shortfalls which can (and has) led to mandatory procurement orders.
2024-2026 IRP cycle3
Based on portfolio planning information submitted by LSEs in the 2022 IRP process, the CPUC developed a 2023 PSP that informs the 2026 IRP process. For the 2024-2026 IRP cycle, the modeling years included 2026, 2028, 2030, 2035, 2040, and 2045, with GHG emissions limits of 25 million metric ton (MMT) in 2035 and 8 MMT by 2045. A few important aspects of the Commission's PSP analysis and results include:
4 • 70 percent of the selected builds are solar and battery storage; 2 https://www.cpuc.ca.gov/irp/
3 2024-2026 IRP Cycle Events and Materials. https://www.cpuc.ca.gov/industries-and-topics/electrical-energy/electric-power-procurement/long-term-procurement-planning/2024-26-irp-cycle-events-and-materials. 4 2026 CPUC Filing Requirements Modeling. https://www.cpuc.ca.gov/-/media/cpuc-website/divisions/energy-division/documents/integrated-resource-plan-and-long-term-procurement-plan-irp-ltpp/2024-2026-irp-cycle-events-and-materials/2026-cpuc-filing-requirements-modeling.pptx • Nearly the full potential of conventional geothermal, onshore wind, and location-constrained storage is built;
• A small amount of Enhanced Geothermal Systems (EGS) resources is built in 2045; • The GHG emissions target is binding for all model years; and • Use of natural gas declines to meet the GHG target, but natural gas capacity is retained for reliability events through 2045.

MCE’s 2026 IRP
MCE is required to complete and file three templates for the 2026 IRP filing by August 10, 2026:

1. Resource Data Template (RDT) – A CPUC tool used to report MCE’s existing energy and capacity contracts and to build a PCP of planned, new long-term contracts to meet MCE’s load, reliability, and emissions targets. The RDT allows for an assessment of the portfolio’s level of reliability over the planning horizon (2026-2045);

2. Clean System Power (CSP) tool – A CPUC tool used to estimate and demonstrate the GHG and criteria pollutant emissions of MCE’s PCP; and

3. Narrative report – Outline MCE’s analysis, results, and provide a description of MCE’s planning and programmatic efforts for the future.

MCE’s assigned GHG benchmarks for the 2026 IRP are provided in Table 1 below. 2030 2035 2040 2045
Load
(GWh) 6361.61 7600.09 8507.80 8980.29
GHG Benchmark
(MMT) 0.513 0.393 0.332 0.170
Table 1: MCE's assigned GHG benchmarks for the 2026 IRP Guiding Principles for MCE’s 2026 IRP:

As part of its planning and design process for the draft PCP, MCE considers the following Guiding Principles. This list is not in any order of priority, and the principles are not mutually exclusive of each other:
• Mission & Board Policy: Meet Board-approved renewable procurement and emissions targets and comply with all Board-adopted procurement directives; • Regulatory Compliance: Comply with CPUC procurement-related rules and regulations, including procurement orders and resource adequacy (RA); • Affordability: Build a portfolio that ensures stable and affordable rates for MCE customers; • Risk Management: Incorporate contract terms and lengths and procurement timelines to minimize market risk impacts on MCE customers;
• Technology Diversity: Invest in a diverse portfolio of clean technology types; and • Clean Reliability: Progress towards a cleaner RA portfolio.

Draft PCP
MCE developed its draft PCP consistent with the renewable energy and GHG-free goals summarized in Table 2 below.5
Portfolio
Targets
(%)
2026 2027 2028 2029 2030 2031 2032 2033 2034 2035
PCC 1
Renewable
(Light
Green)
60% 65% 70% 75% 80% 85% 85% 85% 85% 85%
Carbon-free 37% 32% 27% 22% 17% 12% 12% 12% 12% 12%
GHG Free 95% 95% 95% 95% 95% 95% 95% 95% 95% 95%
Table 2: MCE's Internally Adopted Renewable and GHG-free Energy Targets MCE’s PCP includes plans for significant capacity additions of new renewable and storage resources by 2045 to support achievement of MCE’s renewable and GHG-free energy goals, while contributing to system reliability in a responsible manner.

MCE’s PCP includes the following planned new capacity:
• In-state and out-of-state wind resources totaling 683.3 Megawatts (MW) • Geothermal resources totaling 176.4 MW;
• Solar resources totaling 1513.6 MW (imported and California solar); • 4-hour battery storage resource totaling 588.9 MW; and • 8-hour battery storage resource totaling 1166.7 MW.

MCE’s PCP provides for the following overall energy resource mix in 2045:
6 • Hydro-electric (large, small, and imported) of 500 Gigawatt Hours (GWh); • Geothermal of 1617 GWh;
• Wind (in-state and out-of-state) of 2322 GWh; and
• Solar (California and imported) of 4700 GWh.
5 These targets were incorporated into MCE’s 2026 budget process and were approved with the Fiscal Year 2026/2027 Budget. The revised targets will be incorporated into future planning efforts such as the IRP and MCE’s Renewables Portfolio Standard (RPS) Procurement Plan until modified by the Board in the future. 6 MCE’s PCP includes battery resources in its portfolio by 2045, but they are not included in this list because battery energy storage does not count towards energy in GWh because of round trip efficiency losses.

New Resource Additions in Draft PCP
MCE’s draft portfolio includes a mix of existing and new resources strategically integrated to adhere to MCE’s policy to achieve at least 85% renewable energy by 2031 to continue to reduce emissions through 2045 to meet state targets.

Through its currently contracted long-term capacity and planned contracts in the draft PCP, MCE plans to:
• Procure approximately 92% of its renewable energy from long-term contracts by 2045; • Contribute to building more than 46 MW of new renewable energy resources directly in MCE’s service area;
• Contribute to building 2928 MW of new renewable energy resources throughout California; • Contract with 2628 MW of storage that will help shift peak demand and support grid reliability; benefiting hourly accounting and energy costs; and • Bring over 860 MW of nameplate capacity from renewable resources online in the next six years to serve reliability needs.

Approximately 4,000 MW of MCE’s PCP is composed of new resources, reflecting MCE’s active role in the State’s development of new storage and renewables.

Figure 1: Cumulative New Resource Additions by Resource Type in Draft PCP The above results are intended for illustrative incremental portfolio analysis only. Actual procurement choices would differ and follow Board approved procurement practices.

Emissions Results of Draft PCP
MCE’s assigned 2035 and 2045 load forecast, GHG emissions benchmarks, and forecast GHG emissions for the draft PCP are reflected in the table below as estimated using the CPUC’s CSP calculator. Inclusion of natural gas for capacity in MCE’s draft PCP does not compromise MCE’s progress towards emissions reductions. Incremental additions of new, clean resources translate to lesser utilization of natural gas plants towards system power.

Year Load
(GWh)
GHG
Benchmark
(MMT)
Draft PCP Annual
Emissions (MMT)
2035 7601 0.393 0.32
2045 8980 0.170 0.169
Table 3: Emissions Results of Draft PCP
Cost Impacts of Draft PCP
Adoption of an IRP does not equate to Board approval to enter into contracts to “build” the resources selected in the IRP. Any future procurement decisions must follow the Board approval process.

As the IRP utilized a 20-year planning horizon and IRPs are updated on a two-year cycle, MCE does not expect to procure exactly what is adopted in its 2026 IRP. Instead, the PCP is intended to represent one reasonable and feasible portfolio that MCE could build out to meet its share of the State’s reliability and GHG-emissions requirements and to help guide MCE and statewide procurement policy between now and the next IRP cycle. Accordingly, a primary goal of the IRP for MCE is to select a portfolio which leads to affordable rates for MCE customers.

While MCE does not expect to procure exactly what is in the 2026 IRP, if MCE were to build and bring online all the resources included in the draft PCP (per the exact planning timeline) and directly pass through the incremental procurement costs to customers, based on current pricing information7 MCE expects the following affordability and ratepayer impacts:

1. MCE’s generation rate8 would increase annually by 5% on average.

2. By 2045, MCE’s rates would cumulatively increase by 18.80 cents/kilowatt-hour (kWh), a 150% increase to the current generation rate.
8 The rate impacts described above and in Figure 2 are intended for illustrative incremental portfolio and ratepayer impact analysis only. Critically, MCE does not currently have a rate mechanism to directly pass through power procurement costs to customers via rate increases. Any future rate changes would require Board approval, and actual net cost and rate impacts would be dependent on all costs and revenues.
7 Pricing information is derived from a combination of cost assumptions from the CPUC’s RESOLVE model and internal knowledge sourced from prior MCE solicitations. 8 Generation rate refers to the Residential E-TOU-C rate plan based on a weighted average rate of customer usage across seasons (summer/winter) and time-of-use (on-peak/off-peak) periods.

Figure 2: Cost Impacts of Draft PCP
Reliability of Draft PCP and Alternative Conforming Portfolio MCE is committed to maintain reliability for our customers and align with the state’s reliability goals and planning scenario. MCE’s short- and long- duration storage, renewable baseload procurement, and its RA capacity-only resources will help maintain MCE’s critical role in supporting the State’s need for reliability and renewable integration.

While MCE does not enter into contracts for natural gas for its energy products, MCE’s portfolio does require natural gas for capacity purposes to reliably, feasibly, and affordably meet RA requirements.9 CPUC modeling in the current IRP cycle demonstrates the State’s need for natural gas resources to ensure a reliable statewide grid10. Accordingly, MCE’s draft PCP aligns with this planning framework and maintains natural gas in its RA portfolio to reliably and affordably serve our customers.11 In order to understand and demonstrate the impacts of replacing natural gas capacity in MCE’s draft PCP with a greater percentage of clean RA resources, MCE built an alternative draft conforming portfolio. In this alternative conforming portfolio, MCE continues to meet all internal targets and CPUC requirements, but a portion of natural gas RA capacity is incrementally replaced with clean RA resources over the planning horizon as shown in Table 4. 9 https://www.cpuc.ca.gov/industries-and-topics/electrical-energy/electric-power-procurement/resource-adequacy-homepage 10 CPUC 2026 IRP Modeling Results. https://www.cpuc.ca.gov/-/media/cpuc-website/divisions/energy-division/documents/integrated-resource-plan-and-long-term-procurement-plan-irp-ltpp/2024-2026-irp-cycle-events-and-materials/2026-cpuc-filing-requirements-modeling.pptx 11 A significant portion of the thermal (natural gas) capacity in MCE’s portfolio comes from the CPUC’s Cost Allocation Mechanism (CAM). CAM allows investor-owned utilities to procure resources for reliability purposes and allocate the costs and capacity value to all LSEs.

Figure 3: Cumulative New Resource Additions by Resource Type in Alternative Conforming Portfolio Year Load
(GWh)
GHG
Benchmark
(MMT)
Draft PCP
Annual
Emissions
(MMT)
Draft
Alternative
Conforming
Portfolio
Annual
Emissions
2035 7601 0.393 0.32 0.14
2045 8980 0.170 0.169 (0.07)12
Table 4: Emissions Results of Draft PCP and Draft Alternative conforming portfolio As MCE adds new clean resources over the planning horizon, the proportion of natural gas within its RA portfolio in the draft PCP is projected to decrease. The draft alternative conforming portfolio demonstrates that MCE would need to contract with a significant amount of new clean resources over the planning horizon.

Based on MCE’s experience and understanding of the market, MCE Staff believe that the alternative conforming portfolio is likely to be very difficult to procure. Additionally, the alternative conforming portfolio is more costly and results in over procurement relative to 2045 needs. As mentioned previously, MCE will not contract with the exact set of resources included in the draft PCP. However, the CPUC uses LSE IRPs to plan statewide procurement and MCE endeavors to submit a portfolio 12 The Draft Alternative Conforming Portfolio results in negative emissions as it leads to over procurement compared to 2045 energy requirements. The negative value reflects the avoided emissions above and beyond MCE’s projected needs.
that can feasibly and reasonably procure to ensure MCE is not providing inaccurate signals.

Accordingly, Staff has not selected this portfolio as its draft PCP at this time.

For example, as shown in Table 4 below, the alternative conforming portfolio would see MCE contracting with approximately 299 MW more of nameplate capacity of geothermal resources between 2026 and 2045 versus 96 MW included in the baseline draft PCP. Currently, geothermal is an extremely scarce and expensive resource, and indicating that MCE could contract at the levels demonstrated in the portfolio would be highly speculative and not representative of what Staff believe is reasonable to build at this time.

Resource Type Draft PCP
(MW)
Clean RA
Alternative
(MW)
Change
Battery Storage 2,115 2,398 +283
Geothermal 96 395 +299
Solar 1,514 1,412 -102
Wind 801 900 +99
Total 4,527 5,106 +579
Table 5: New Resource Additions in Alternative Conforming Portfolio, 2026 – 2045 Additionally, the alternative conforming portfolio would likely result in significant rate increases for MCE customers. If MCE were to build and bring online all the resources included in the draft alternative conforming portfolio (per the exact planning timeline) and directly pass through the incremental procurement costs to customers, based on current pricing information13 MCE expects the following affordability and ratepayer impacts:

1. MCE’s generation rate8 would increase annually by 6% on average.

2. By 2045, MCE’s rates would cumulatively increase by 24.34 cents/kilowatt-hour (kWh), a 194% increase to the current generation rate.
8 Although the 20-year impact appears modest as shown in Figure 4, the 20-year timeframe suppresses the year-over-year cost impact on customers. 13 Pricing information is derived from a combination of cost assumptions from the CPUC’s RESOLVE model and internal knowledge sourced from prior MCE solicitations.

Figure 4: Cost impacts of Draft Alternative Conforming Portfolio MCE Staff plans to continue to invest in clean RA resources and progressively reduce reliance on natural gas for RA, while balancing across all other Guiding Principles. While MCE has not currently selected the alternative conforming portfolio for IRP compliance, MCE Staff welcome feedback from the Technical Committee on this matter and remains open to continuous discussion on its clean RA efforts.

As described above, the results of the alternative conforming portfolio described in this section are intended for illustrative incremental portfolio and rate impact analysis only. Actual procurement choices would differ and follow Board approved procurement practices. Any future rate changes would require Board approval, and actual net cost and rate impacts would be dependent on all costs and revenues.

Fiscal Impacts:

When MCE brings a final 2026 IRP to the Board for consideration in July, it will be aligned with assumptions underlying MCE’s financial pro forma projections. There will be no direct or immediate fiscal impacts of adopting MCE’s 2026 IRP. All future resource commitments made to implement the plan will be subject to separate approval in accordance with MCE’s adopted delegation of authorities.

Recommendation:

Discussion only. Staff invites the Technical Committee to provide feedback on its 2026 IRP guiding principles, and draft PCP. Staff will bring the proposed 2026 IRP to the Board seeking approval in July 2026, before submitting to the CPUC on August 10, 2026.

Integrated Resource Plan
Proceeding
Technical Committee
June 5, 2026
What We Are Asking Today
2 Seeking Feedback on the draft Integrated Resource
Plan (IRP) Preferred Conforming Portfolio (PCP) and
guiding principles.
• Focus: Portfolio direction and tradeoffs
• Today is NOT: Approval of specific projects, contracts, or budgets.

All future procurement decisions will still come to the Board for approval.

What is the IRP and How Does it Work?
3 IRP = Integrated Resource Plan
Key Goal: Identify a diverse
portfolio of resources to meet
grid reliability needs & support
CA’s Greenhouse Gas (GHG)
emissions reductions goals.

California Public Utilities
Commission (CPUC) oversees
the IRP and sets resource
planning targets for Load
Serving Entities (LSEs) within
its jurisdiction.

An iterative process with two tracks that impacts
MCE procurement, budget, and ratepayers:

1. Planning
• The CPUC builds Preferred System Plan
(PSP) portfolio based on load forecasts,
state policy goals, and statewide
emissions targets.
• LSEs prepare individual IRPs that are
aggregated and evaluated against
the PSP.
• Informs transmission planning

2. Procurement
• CPUC evaluates and determines if
there is a need for additional
procurement to fill identified shortfalls.
• This can (and has) lead to mandatory
procurement orders.

How Does MCE Participate in the IRP
4 • MCE regularly engages in advocacy in CPUC-related proceedings to advocate for reasonable forecast and planning assumptions as well as fair procurement obligations.
• Submit an IRP to the CPUC every two years:
• After development of the PSP, the CPUC allocates portion of the PSP to individual LSEs like MCE.
• MCE is required to create and submit a Preferred Conforming Portfolio (PCP or Portfolio) for submission to the CPUC. • Conforming PCP outlines MCE’s model demonstrating that it can meet its share of statewide reliability need and GHG targets. 2026 is an IRP year!
2026 IRP Requirements
5 • MCE’s IRP demonstrates how MCE will meet its share of the 25 Million Metric Tons (MMT) by 2035 and 8 MMT by 2045 GHG target.
• Submission Requirements:
• Resource Data Template (RDT) - Report MCE’s existing energy and capacity contracts and build a PCP of planned contracts to meet MCE’s load, reliability and emissions targets • Clean System Power (CSP) tool – Use to estimate and demonstrate the GHG and criteria pollutant emissions of MCE’s PCP
• Narrative report – Outline MCE’s analysis, results, and provide a description of MCE’s planning efforts for the future
Guiding
Principles
Feedback
May
21 Seek Approval of
Final IRP July Final IRP
Submission
August
10 Impacts: What IRP Does and Does Not Do
6 The IRP does NOT
• Determine specific or exact cost impacts for
MCE.
• Select individual projects or contracts that
MCE must procure.
• MCE’s procurement authority resides
with this Board, and however the Board
delegates such authority.
• All future contracts for new resources
will continue to follow that approval
process.
• Align perfectly with market timing or
contract availability to ensure least cost,
optimal portfolios for individual LSEs.

The IRP does
• Directly impact MCE’s operation strategy
and budget.
• Influence and constrain (but does not
dictate) MCE’s future procurement
efforts.
• Impact on MCE’s procurement costs
through changes in market dynamics
and resource costs and availability.
• Have potential to result in procurement
mandates if the CPUC determines more
capacity is needed.

Guiding Principles for MCE’s PCP
7 Meet Board-approved renewable procurement and emissions targets and comply with all Board-adopted procurement directives Mission & Board Policy Comply with CPUC procurement-related rules and regulations, including procurement orders and resource adequacy (RA) Regulatory Compliance Build a portfolio that ensures stable and affordable rates for MCE customers
Affordability
Diversify contract types and lengths to minimize market risk impacts on MCE customers Risk Management
Build a diverse portfolio of clean technology types Technology Diversity Continue to invest in clean RA resources Clean Reliability Portfolio Design: Constraints & Considerations
8 Regulatory Compliance &
Uncertainty
• CPUC Procurement Mandates
• 2030 – 2032 – 180 MW with 45 MW
from long duration energy storage or
clean firm resources
• Resource Adequacy Compliance
• Uncertainty of Resource Accounting
Methodologies for Planning
• Possibility of Future Procurement
Mandates & Programs (RCPPP)
Market Realities
• Resource Availability and Viability
• Price volatility impacts on MCE procurement
costs
• Infrastructure Constraints impacting Capacity
and Energy Availability, such as:
• Curtailment
• Grid Congestion
• Permitting Backlogs
• Supply Chain Risk
• Federal Policy Risk
Requirement to meet the CPUC’s Preferred System Plan for the state for a 20-year timeframe
MCE’s Assigned GHG Emissions Benchmarks
9 2030 2035 2040 2045
Load
(GWh) 6361.61 7600.09 8507.80 8980.29
GHG
Benchmark
(MMT)

0.513 0.393 0.332 0.170
MCE’s IRP will illustrate how MCE plans to meet its share of the 25 Million Metric Tons (MMT) by 2035 and 8 MMT by 2045 GHG target.

Draft PCP Mission & Board Policy
10 Portfolio
Targets (%) 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 PCC 1
Renewable
(Light Green)
60% 65% 70% 75% 80% 85% 85% 85% 85% 85%
Carbon-free 37% 32% 27% 22% 17% 12% 12% 12% 12% 12%
GHG Free 95% 95% 95% 95% 95% 95% 95% 95% 95% 95%
Draft PCP: Technology diversity
11 Resource type Contracted
Capacity (MW)
in 2026
Planned new
capacity (MW)
Overall resource
mix (GWh) in
2045
Proportion of total
in 2045 [GWh](%)
Wind (in-state, out of
state) 305.2 683.3 2322 25%
Geothermal 137 176.4 1617 18%
Hydro-electric (large,
imported, small) 205.6 500 5%
Solar (California,
imported) 861.4 1513.6 4700 51%
Battery (4hr) 476.6 588.9 - -
Battery (8hr) 35 1166.7 - -
Draft PCP: New Planned Resource Additions
12 *Cumulative MW are nameplate capacity additions
These results are illustrative only. Actual procurement will differ and follow Board approved procurement processes.

Draft PCP: Risk management
13 • The draft PCP aligns with MCE’s current Energy Risk Management policy.
• Over the planning 20+ year horizon, all planned new contracts are long term contracts. The exact procurement timelines will be dependent on MCE’s portfolio needs at the time.
• However, on a short-term timeline (1-3 years), MCE plans to fill its supply with short term contracts with existing resources.

What MCE Has Built Through Long-Term
Contracts + Draft IRP PCP
~92%
of MCE renewable
energy from long-term
contracts (2045)*
46+ MW
of new renewables built
directly in MCE's service
area
2,928 MW
of new
renewables statewide to
serve MCE customers
2,911 MW
of renewable energy
including draft IRP
portfolio since 2021
Energy Storage: 2,268 MW of storage including draft IRP portfolio — shifting renewable energy to hours of peak demand and adding grid reliability. A benefit for hourly accounting & energy cost.

MCE also offers a Feed-in Tariff program providing direct incentives for new clean energy projects within our service area — supporting hyperlocal renewable development. *2045 results will depend on load and portfolio optimization. 14 Four Reasons We Need Short-Term Contracts
01 Load Forecast Uncertainty
MCE cannot perfectly predict future demand.

Large customers come and go; customers opt
in/out of Deep Green; electrification reshapes
demand. Short-term contracts let us adjust
without being locked into wrong-sized long-term commitments, better for hourly accounting. 02 Multi-Year Project Development
Timelines and Delays
Many new renewable projects are delayed due
to transmission constraints. Short-term contracts
with operating resources ensure reliable
delivery while new-build projects come online.
03 Technology Diversity
MCE's long-term portfolio is solar-heavy, so
short-term contracts for wind, geothermal, and
hydro can generate power when solar isn't
producing. This reduces hourly emissions and
better matches MCE's actual customer demand.
04 Price Risk Management
Executing contracts at different times and
lengths diversifies portfolio risk. Observing
temporal diversity when buying energy avoids
over-exposure to discrete market conditions. A
mix of short- and long-term contracts minimizes
“planning cliffs” that could occur if several long-term commitments expired at the same time. 15 Draft PCP: Affordability & Cost Impacts
16 If MCE built this exact portfolio, all else equal, based on current cost assumptions MCE’s generation rate would increase 150% by 2045.
**All future rate changes would require board approval and actual net cost and rate impacts would be dependent on all costs and revenues.
4%
11%
5%
6% 6% 6%
13%
5%
4% 4%
7%
7%
3% 3%
5%
2%
4%
-0.50

0.00 0.50

1.00 1.50

2.00 2.50

3.00 -5
0 5
10 15
20 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 ¢/KWh¢/KWh
Preferred Conforming Portfolio Rate Impacts (Nominal ¢/KWh) Annual Rate Impact Cummulative rate impact
RA and IRP: Key Differences
17 RA
• Resource accounting: Slice of Day
(SOD)
• Compliance timeline
• Short-term (2 years) planning
• Month-ahead and year-ahead filings
• Meet capacity requirements with a
Planning Reserve Margin (PRM) for
MCE’s load
IRP
• Resource accounting: Marginal Effective
Load Carrying Capability (ELCC)
• Compliance timeline
• Long term (10-20 years) planning
• 2-year filing cycle (iterative)
• Meet state GHG reduction goals and
demonstrate alignment with state’s
planning portfolio
Main takeaway: MCE needs to address the challenge of building a portfolio and procuring resources for meeting two compliance programs on separate timelines with separate evaluation metrics, efficiently and affordably.

Clean Reliability in the IRP
18 • The fossil fuel question: MCE does not directly procure natural gas as part of its energy supply for customers. However, MCE sources Resource Adequacy (capacity) from existing natural gas facilities.
• Progress: Over 860 MW of nameplate capacity from renewable resources expected to come online in the next six years.
• Natural Gas in MCE’s PCP: MCE will have natural gas in its RA portfolio all the way through 2045.
• CPUC’s PSP includes reliance on natural gas to maintain reliability and MCE’s PCP aligns with that planning direction.
• As MCE’s load is projected to increase, the proportion of natural gas relative to entire RA portfolio decreases.
• Although the capacity is present in MCE’s RA portfolio, this does not directly translate to the natural gas plants coming online to provide energy to the State’s energy grid.

Draft Alternative Conforming Portfolio
19 These results are illustrative only. Actual procurement will differ and follow Board approved procurement processes.

Draft Alternative Conforming Portfolio: Affordability & Cost Impacts 20 If MCE built this exact portfolio, all else equal, based on current cost assumptions MCE’s generation rate would increase 194% by 2045.
*All future rate changes would require board approval and actual net cost and rate impacts would be dependent on all costs and revenues.
4%
12%
8%
15%
8%
6%
15%
5%
3% 4%
5%
12%
2% 2%
6%
2%
5%
-0.50

0.00 0.50

1.00 1.50

2.00 2.50

3.00 3.50

4.00 -5
0 5
10 15
20 25
30 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 ¢/KWh¢/KWh
Alternative Conforming Portfolio - Rate Impacts (Nominal ¢/KWh) Annual Rate Impact Alternate Cummulative Rate Impact Alternate Affordability & Cost Impacts Comparison
21 *All future rate changes would require board approval and be dependent on many factors. 0 5
10 15
20 25
30 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 ¢/KWh
Portfolio Rate Impacts Comparison (% Change)
Cummulative rate impact Alternate Cummulative rate impact PCP Alternative PCP
Draft PCP
Draft Alternative Conforming Portfolio
22 • Given the scarcity of resources like
geothermal and wind, the price and
cost impact of the resources will
make them difficult to procure and
costly for MCE’s customers.
• Accordingly, Staff has not selected
this portfolio as its Draft PCP.

New Resource Additions (Nameplate capacity)
Resource Type Draft
PCP
(MW)
Alternative
Draft PCP
(MW)
Change
Battery Storage 2,115 2,398 +283
Geothermal 96 395 +299
Solar 1,514 1,412 -102
Wind 801 900 +99
Total 4,527 5,106 +579
Looking Ahead: MCE will continue to invest in clean RA resources, while balancing across all other Guiding Principles. MCE is committed to continuous discussion on its clean RA efforts.

Next Steps
23 Recommendation
• Staff invites feedback on its 2026 IRP guiding principles and Draft PCP.

Proposed Next Steps
• June/July - Refine PCP and complete 2026 IRP based on feedback received today
• July - Proposed 2026 IRP for Board consideration and approval • August 10 – Final IRP Submission to CPUC
Thank you!
mceCleanEnergy.org
[email protected]

BEFORE THE PUBLIC UTILITIES COMMISSION

OF THE STATE OF CALIFORNIA
Order Instituting Rulemaking to Continue
Electric Integrated Resource Planning and
Related Procurement Processes. Rulemaking 20-05-003

MARIN CLEAN ENERGY
2022 INTEGRATED RESOURCE PLAN
(PUBLIC VERSION)
Ann C. Springgate
Keyes & Fox LLP
580 California Street, 12th Floor
San Francisco, CA 94104
415.987-8367
[email protected]
Counsel to
Marin Clean Energy
November 1, 2022
FILED
11/01/22
01:50 PM
R2005003

BEFORE THE PUBLIC UTILITIES COMMISSION

OF THE STATE OF CALIFORNIA
Order Instituting Rulemaking to Continue
Electric Integrated Resource Planning and
Related Procurement Processes. Rulemaking 20-05-003

MARIN CLEAN ENERGY
2022 INTEGRATED RESOURCE PLAN
(PUBLIC VERSION)
In accordance with the requirements of California Public Utilities Code Sections 454.51 and 454.52, Ordering Paragraph 14 of the California Public Utilities Commission’s (“Commission”) Decision Adopting 2021 Preferred System Plan (“D.22-02-004”), and the June 15, 2022 Administrative Law Judge’s Ruling Finalizing Load Forecasts and Greenhouse Gas Emissions Benchmarks for 2022 Integrated Resource Plan Filings, Marin Clean Energy (“MCE”) hereby submits its 2022 Integrated Resource Plan (“IRP”) and related documents to the Commission for certification.

Attached to this filing are the following documents associated with MCE’s 2022 IRP:
• Attachment A - Standard Load-Serving Entity Plan (Public); • Attachment B – 25 MMT Resource Data Template (Public); • Attachment C – 30 MMT Resource Data Template (Public); • Attachment D – 25 MMT Clean System Power Calculator;
• Attachment E – 30 MMT Clean System Power Calculator; and • Attachment F - MCE October 20, 2022 Board Meeting Agenda.

MCE has developed both public (redacted) and confidential (unredacted) versions of its Load-Serving Entity Plan (i.e., narrative), 25 MMT Resource Data Template, and 30 MMT Resource Data Template. Concurrent with this filing, MCE is filing a motion to file the confidential materials under seal and will submit the confidential versions of these documents to the Commission through secure FTP.

MCE thanks the Commission for its time and effort in the 2022 IRP cycle and respectfully requests the Commission certify its 2022 IRP as consistent with the requirements of Sections 454.52(b)(3) and 454.51(d) and (e) of the California Public Utilities Code and Commission direction.

November 1, 2022
Respectfully submitted,
/s/ Ann C. Springgate
Ann C. Springgate
Keyes & Fox LLP
580 California Street, 12th Floor
San Francisco, CA 94104
415.987-8367
[email protected]
Counsel to
Marin Clean Energy

ATTACHMENT A
Standard LSE Plan

MARIN CLEAN ENERGY
2022 INTEGRATED RESOURCE PLAN
NOVEMBER 1, 2022
1 Table of Contents
I. Executive Summary ................................................................................................................ 4 a. Introduction .................................................................................................................. 4 Description of MCE................................................................................................................................................ 4 MCE’s Mission ....................................................................................................................................................... 5 Introduction to MCE’s Compliance IRP.................................................................................................................. 6 MCE’s Preferred Conforming Portfolio.................................................................................................................. 7 Request for Certification ....................................................................................................................................... 8 b. Summary of Findings .................................................................................................... 9 II. Study Design ........................................................................................................................11 a. Objectives ...................................................................................................................11 b. Methodology ..............................................................................................................12 i. Modeling Tool(s) .................................................................................................................... 12 ii. Modeling Approach................................................................................................................ 13 Load Forecast ......................................................................................................................................................13 Table 1: MCE’s 2023-2035 Load Forecast............................................................................................................13 Load Shape ..........................................................................................................................................................13 Compiling Existing Resources..............................................................................................................................14 Selecting New Resources.....................................................................................................................................14 Confirming Reliability ..........................................................................................................................................14 Calculating GHG Emissions..................................................................................................................................15 III. Study Results ........................................................................................................................15 a. Conforming and Alternative Portfolios .......................................................................15 Table 2: MCE’s 2035 PCP Resources....................................................................................................................15 MCE’s PCP Is Consistent with the 2021 PSP ........................................................................................................17 Table 3: MCE’s PCP New Resource Procurement by Type Compared to 2021 PSP.............................................18 b. Preferred Conforming Portfolio ..................................................................................19 Meeting GHG Reduction Goals............................................................................................................................20 Procuring Eligible Renewable Energy ..................................................................................................................21 Minimizing Bill Impact.........................................................................................................................................21 Ensuring System and Local Reliability..................................................................................................................22 Strengthening the Bulk Transmission and Distribution Systems.........................................................................23 Enhancing Demand-Side Energy Management...................................................................................................23 Minimizing Localized Air Pollutants with Emphasis on Disadvantaged Communities.........................................24 c. GHG Emissions Results ...............................................................................................25 Table 4: MCE’s PCP GHG Emissions.....................................................................................................................25 d. Local Air Pollutant Minimization and Disadvantaged Communities ...........................25 i. Local Air Pollutants................................................................................................................. 25 Table 5: MCE’s PCP Local Pollutant Emissions (30 MMT Scenario).....................................................................25 Table 6: MCE’s PCP Local Pollutant Emissions (25 MMT Scenario).....................................................................26 ii. Focus on Disadvantaged Communities.................................................................................. 26 2 Table 7: DACs Served by MCE..............................................................................................................................26 Green Access and Community Solar Connection Programs................................................................................29 Sustainable Workforce and Diversity Policy........................................................................................................30 Ad Hoc Workforce Development ........................................................................................................................31 Creating Energy Efficiency Jobs...........................................................................................................................33 Equity in Power Purchasing ................................................................................................................................. 34 Strategic Recruiting and Hiring Practices ............................................................................................................34 Community Power Coalition................................................................................................................................34 Building Community Resiliency ...........................................................................................................................35 COVID-19 Customer Support...............................................................................................................................36 e. Cost and Rate Analysis ................................................................................................36 f. System Reliability Analysis. .........................................................................................38 g. High Electrification Planning .......................................................................................40 Table 8: MCE’s 2024-2035 Load Forecast - High Electrification Scenario............................................................41 Table 9: MCE’s 2024-2035 Peak Demand Forecast - High Electrification Scenario.............................................41 Table 10: MCE’s Planned Out-of-State and Off-Shore Wind Resources..............................................................42 h. Existing Resource Planning .........................................................................................42 i. Hydro Generation Risk Management .........................................................................43 j. Long-Duration Storage Planning .................................................................................44 k. Clean Firm Power Planning .........................................................................................45 l. Out-of-State Wind Planning ........................................................................................45 m. Offshore Wind Planning ..............................................................................................46 n. Transmission Planning ................................................................................................46 i. New Projects.......................................................................................................................... 46 ii. Projects Under Development................................................................................................. 46 iii. Projects Under Review........................................................................................................... 48 iv. Planned New (Generic) Projects ............................................................................................ 49 IV. Action Plan ...........................................................................................................................50 a. Proposed Procurement Activities and Potential Barriers ...........................................50 Joint Solicitations.................................................................................................................................................50 Optimizing Existing Procurement........................................................................................................................51 Annual Energy Solicitations................................................................................................................................. 51 i. Resources to meet D.19-11-016 procurement requirements................................................ 54 D.19-11-016 Procurement Progress Report ........................................................................................................54 Sutter Energy Center...........................................................................................................................................55 Strauss Wind, LCC................................................................................................................................................55 MCE Solar One.....................................................................................................................................................56 Waste Management Redwood Landfill (“Redwood Landfill Project”) ................................................................56 i. Resources to meet D.21-06-035 procurement requirements, including: .............................. 57 MTR Procurement Progress Report.....................................................................................................................57 i. All other procurement requirements..................................................................................... 59 3 Open Season RFO................................................................................................................................................59 ii. Offshore wind ........................................................................................................................ 60 iii. Out-of-state wind................................................................................................................... 60 iv. Other renewable energy not described above ...................................................................... 60 v. Other energy storage not described above ........................................................................... 60 vi. Other demand response not described above....................................................................... 61 vii. Other energy efficiency not described above ........................................................................ 61 viii. Other distributed generation not described above ............................................................... 62 Net Energy Metering and Rooftop Solar Rebates ...............................................................................................62 ix. Transportation electrification, including any investments above and beyond what is included in Integrated Energy Policy Report (IEPR) ........................................................................................ 63 x. Building electrification, including any investments above and beyond what is included in Integrated Energy Policy Report (IEPR)............................................................................................ 64 Multifamily Energy Saving Program ....................................................................................................................64 LIFT Pilot Program ...............................................................................................................................................65 Home Energy Savings (“HES”) Program...............................................................................................................66 Heat Pump Water Heater (“HPWH”) Contractor Incentive Program..................................................................67 xi. Other...................................................................................................................................... 67 b. Disadvantaged Communities ......................................................................................67 Green Access and Community Solar Connection Programs................................................................................67 Sustainable Workforce and Diversity Policy........................................................................................................68 c. Commission Direction of Actions ................................................................................68 V. Lessons Learned ...................................................................................................................69 Glossary of Terms.........................................................................................................................70 4 I. Executive Summary
a. Introduction
Description of MCE
Marin Clean Energy (“MCE”) is California’s first Community Choice Aggregation (“CCA”) Program, a not-for-profit Joint Powers Authority (“JPA”) that began service in 2010. MCE’s mission is to confront the climate crisis by eliminating fossil fuel greenhouse gas (“GHG”) emissions, producing renewable energy, and creating equitable community benefits. MCE’s vision is to lead California to an equitable, clean, affordable, and reliable energy economy by serving as a model for community-based renewable energy, energy efficiency, and cutting-edge clean-tech products and programs.

As a load-serving entity (“LSE”), MCE provides electricity generation service to approximately 580,000 customer accounts. These accounts represent more than one million residents and businesses across four Bay Area counties.1 MCE procures for annual retail sales of approximately 5,729 GWh and a peak load of more than 1,240 MW.

MCE provides service to approximately 87% of eligible customers within its service area, which is depicted in Figure 1, below. MCE is also the default generation provider for any new or relocated customers therein.2
1 MCE serves communities across Contra Costa, Marin, Napa, and Solano counties. Those communities currently receiving service include: Unincorporated Contra Costa, Marin, Napa, and Solano counties and the Cities and Towns of Concord, Danville, El Cerrito, Lafayette, Martinez, Moraga, Oakley, Pinole, Pittsburg, Pleasant Hill, Richmond, San Pablo, San Ramon, Walnut Creek, Belvedere, Corte Madera, Fairfax, Larkspur, Mill Valley, Novato, Ross, San Anselmo, San Rafael, Sausalito, Tiburon, American Canyon, Calistoga, Napa, St. Helena, Yountville, Benicia, Vallejo, and Fairfield.
2 MCE expanded service to the city of Fairfield in April 2022. This expansion is reflected in MCE’s Commission-assigned load forecast. Expansion to additional communities may occur during the planning period.
5 Figure 1: Service Area Map
As a JPA and local government agency, MCE is governed by a 31-member Board of Directors (“Board” or “Governing Board”) composed of elected representatives from MCE’s member communities. MCE’s Board sets policy for the agency and oversees MCE’s operations, including MCE’s procurement planning. Through these representatives, MCE is controlled by and accountable to the communities MCE serves.

MCE’s Mission
MCE was formed to empower its member communities to choose the generation resources that reflect their specific values and needs. As a mission-driven local government agency, MCE works toward the following:
● Reducing GHG emissions and accelerating the supply of clean energy being delivered to and used on the grid;
● Developing community programs and local energy projects to expand access to competitively priced renewable energy and energy efficiency programs for all customers;
● Creating economic and workforce benefits associated with renewable energy and energy conservations programs; and
● Leveraging energy and conservation spending to promote more equity throughout MCE’s communities and California.
6 Member community values and needs are reflected in a number of procurement principles, goals, targets, and directives reviewed and adopted by MCE’s Board via MCE’s annual Operational Integrated Resource Plan (“Operational IRP”).3 Since 2014, MCE has prepared an annual Operational IRP as an internal planning and policy document to address MCE’s GHG reduction targets and various other agency matters related to resource planning and procurement, including complementary energy programs administered and funded by MCE.

The Operational IRP is well-aligned with the biennial Compliance IRP submitted to the California Public Utilities Commission (“Commission” or “CPUC”) for certification pursuant to Cal. Pub.

Util. Code Section 454.52(b)(3).4 These two IRPs are developed concurrently in even years and describe consistent long-term procurement planning strategies and goals.

Consistent with Sections 366.2(a)(5) and 454.52 (b)(3), MCE’s procurement is governed by MCE’s Board and must be consistent with the Board-adopted mandates in MCE’s Operational IRP.

Introduction to MCE’s Compliance IRP
In accordance with the requirements of Sections 454.51 and 454.52, Commission Decisions (“D.”) 22-02-004, D.21-06-035, D.19-11-016, D.18-02-018, and formal guidance provided by the Commission’s Energy Division,5 MCE is filing its Compliance IRP for certification review and use in the Commission’s statewide planning process. In addition to this narrative, MCE’s Compliance IRP includes the following documents:
● MCE’s 30 MMT Resource Data Template;
● MCE’s 25 MMT Resource Data Template;
● MCE’s 30 MMT Clean System Power Calculator; and
● MCE’s 25 MMT Clean System Power Calculator.
3 The current MCE 2022 Operational Integrated Resource Plan was approved by MCE’s Technical Committee in November 2021 and is available on MCE’s website: https://www.mcecleanenergy.org/energy-procurement/. MCE is developing its 2023 Operational Integrated Resource Plan concurrently with this Compliance IRP. The 2023 OIRP is scheduled to be reviewed and approved by MCE’s Technical Committee in November 2022. 4 All further citations to statute are to the California Public Utilities Code unless otherwise noted. 5 Over the course of the IRP planning cycle, Energy Division has issued a number of guidance documents to be used as LSEs develop their IRPs. These documents include LSE Filing Requirements RESOLVE Results (issued June 15, 2022); Filing Requirements Overview (updated July 15, 2022); Filing Requirements Questions and Answers (updated September 23, 2022); Clean System Power Calculator Documentation (updated July 15, 2022); Resource Data Template v3 User Guide (updated September 23, 2022); and Aggregated CAM Resources for LSEs Plan Development (issued September 29. 2022).
7 As provided for in D.22-02-004 and described in Commission Guidance documents, MCE is submitting a single conforming portfolio (“Preferred Conforming Portfolio”) as part of its Compliance IRP, which meets the following GHG emissions limits:

1. A portfolio that achieves emissions that are equal to or less than MCE’s proportional share of the 38 MMT by 2030 and 30 MMT by 2035 GHG targets (“30 MMT Conforming Portfolio); and

2. A portfolio that achieves emissions that are equal to or less than MCE’s proportional share of the 30 MMT by 2030 and 25 MMT by 2035 GHG targets (“25 MMT Conforming Portfolio”).

Projecting resource needs over the planning horizon covered by the IRP is an inexact exercise and is inevitably and appropriately subject to change in terms of both amounts procured and types of resources needed. MCE’s portfolio of resources generally includes (a) existing and operating resources that are under contract with MCE; (b) resources that MCE has contracted for, but that have not achieved commercial operation; and (c) future resources that MCE will need to procure to meet its agency targets and goals over both the mid- and long-term. The future resources identified in MCE’s Compliance IRP represent MCE’s best, good-faith projection of the resource mix it will procure over the IRP planning horizon based on currently available information. The resources identified in future iterations of MCE’s Compliance IRP may change due to new information and changed circumstances. As such, the ultimate resource mix MCE procures may differ from what is reflected in this Compliance IRP due to a number of variables including regulatory changes, availability of supply, price of supply, and/or other market or regulatory considerations. What MCE expects to remain constant, however, is its aggressive trajectory towards procuring a diverse resource mix that meets MCE’s reliability and customer needs and minimizes reliance on GHG-emitting resources for both energy and capacity.

MCE’s Preferred Conforming Portfolio
MCE’s Preferred Conforming Portfolio (“PCP”) is described in detail below and is represented in MCE’s Resource Data Template, version 3 (“RDT”) for both the 30 MMT Conforming Portfolio and the 25 MMT Conforming Portfolio, respectively. The PCP has been approved by MCE’s Chief Executive Officer and Governing Board as: (a) reflective of MCE’s actual planned procurement as of the filing of this Compliance IRP; (b) consistent with MCE’s statutory obligations; (c) consistent with the Commission’s IRP framework and guidelines, including the Preferred System Plan (“PSP”); (d) consistent with the Commission’s reliability requirements; and (c) consistent with MCE’s internal short-, mid-, and long-term procurement plans and internal procurement policies. MCE’s PCP comes in under its assigned portion of the 25 MMT 8 and 30MMT system emissions targets. MCE’s PCP was approved by MCE’s governing Board on October 20, 2022 and is being provided to the Commission for certification consistent with Section 454.52(b)(3).

Request for Certification
MCE respectfully requests that the Commission certify this Compliance IRP.

As both the Legislature and the Commission have recognized, the Legislature has granted CCAs broad authority to procure resources on their customers’ behalf, an authority limited only where “other generation procurement arrangements have been expressly authorized by statute.”6 The Commission has likewise recognized that the Legislature has granted CCAs autonomy in setting their own rates and managing interactions with their customers.7 As such, the Commission has three primary interests in the CCA IRP process:
● Ensuring that CCA IRPs provide the CCA procurement information that the Commission needs to develop its statewide plan;8
● Ensuring that CCAs’ current and planned procurement is consistent with the resource adequacy (“RA”) requirements established pursuant to Section 380;9 and ● Ensuring that each CCA contributes to grid reliability and GHG emissions reductions through the procurement of long-term renewable integration resources. 10 MCE has prepared its Compliance IRP with these interests in mind, and MCE thanks the Commission in advance for its recognition of CCA procurement autonomy and the benefits of a collaborative approach with CCAs in its certification review of MCE’s Compliance IRP. 6 Section 366.2(a)(5).
7 D.05-12-041 at 5 (“Nothing in the statute directs the CPUC to regulate the CCA’s program except to the extent that its programs may affect utility operations and the rates and services to other customers. For example, the statute does not require the CPUC to set CCA rates or regulate the quality of its services.”); D.19-04-040 at 18 (“[T]he Commission does not approve CCA or ESP rates.”). 8 D.19-04-040 at 17-18 (“The Commission’s portfolio aggregation and evaluation process, which relies of fulfillment of IRP filing requirements by LSEs, is the only process capable of assessing the overall needs of the CAISO grid and meeting the statewide GHG, reliability, and least-cost goals collectively. While LSEs may use their IRP process to meet local planning needs as well, the statewide planning function is the statutorily required process.
9 Section 454.52(b)(3)(C).
10 Section 454.51.
9 b. Summary of Findings
This narrative provides a detailed description of: (a) the development and content of MCE’s PCP; (b) the PCP’s compliance with applicable requirements; and (c) an Action Plan detailing MCE’s planned next steps to implement its plan.

MCE developed its Compliance IRP through the following steps:
● MCE compiled data for its existing energy-only contracts, bundled energy and capacity contracts, RA capacity contracts, and its share of capacity for allocated Cost Allocation Mechanism (“CAM”) and Demand Response resources;
● For each IRP planning year, MCE identified its short positions relative to MCE's planning targets in relation to its assigned load forecast; ● MCE populated the RDTs with all current contracts;
● MCE compiled information on projects for which it is currently negotiating power purchase agreements (“PPA”), including information regarding project status and timing;11
● MCE identified future contracts it expects for new geothermal, storage, and wind generation. MCE prioritized the selection of future resources that best fit MCE’s portfolio and that meet or exceed MCE’s proportional share of planned new procurement;
● MCE added generic future contracts with existing resources to help fill its remaining open positions;
● MCE used the Commission’s Clean System Power (“CSP”) calculator to check the GHG emissions associated with the resulting portfolio to ensure that these emissions are lower than MCE’s assigned share of the 30 MMT and 25 MMT benchmarks; ● MCE identified the resulting portfolio as its Preferred Conforming Portfolio or PCP; and ● MCE checked its PCP for reliability by comparing the total portfolio Net Qualifying Capacity (“NQC”) against MCE’s forecast RA requirements for the month of September in each year of the planning period.

MCE reached the following findings regarding its PCP:
● MCE’s PCP includes the procurement of the following new resources and nameplate capacities over the course of the planning horizon:
11 In the interest of providing the Commission as much current information as possible, MCE’s RDTs include information on projects under negotiation to the extent commercially reasonable and feasible. MCE asserts, though, the information provided for such projects is subject to change pending final execution of agreements. 10 o New wind resources totaling 265 MW;12
o New geothermal resources totaling 109 MW;
o New hybrid resources totaling 212 MW of solar generation and 153 MW of storage;
o New grid connected battery storage of 400 MW;
o New Demand Response resources of 15 MW; and
o New long-duration storage13 of 90 MW;
● MCE’s PCP provides for the following overall resource mix in 2035:
o Large hydro-electric of 525 GWh;
o Imported hydro-electric of 120 GWh;
o Small hydro-electric of 69 GWh;
o Biogas/biomass of 46 GWh;
o Geothermal of 1,785 GWh;
o California wind of 1,014 GWh;
o Out-of-state wind of 250 GWh;
o Offshore wind of 400 GWh;
o California solar of 1,155 GWh;
o Distributed solar of 13 GWh;
o Hybrid solar and storage of 596 GWh; and
o Standalone battery storage of 2,117 MWh (capacity x duration). ● Using the 30 MMT scenario CSP calculator, MCE’s PCP would have 2030 emissions of

0.500 MMT and 0.514 MMT in 2035.14 This is lower than MCE’s assigned share of 2030 and 2035 emissions (0.848 MMT and 0.630 MMT, respectively). ● Using the 25 MMT scenario CSP calculator, MCE’s PCP would have 2030 emissions of

0.493 MMT and 0.492 MMT in 2035. This is lower than MCE’s assigned share of 2030 and 2035 emissions (0.640 MMT and 0.504 MMT, respectively). ● MCE’s PCP meets all Commission-provided reliability metrics. ● MCE’s PCP provides more than MCE’s load-proportional share of renewable integration resources.

MCE has selected its PCP because it appropriately balances Board directives, MCE’s program 12 This 265 MW of new wind resources consists of in-state, out-of-state, and off-shore wind in the following amounts: 100 MW of in-state wind; 70 MW of out-of-state wind; and 95 MW of off-shore wind. 13 MCE is currently interested in long-duration storage resources with at least 8 hours of duration at full capacity. 14 MCE notes that the increase in emissions from 2030 to 2035 results from an increase in use of system power attributable to a decrease in allocated generation from Combined Heat and Power resources, as well as increases in the volume of curtailments and exports modeled.
11 goals, cost constraints, reliability, and customer rate impacts. Specifically, the PCP adheres to MCE Board Policy to achieve an 85% renewable energy content by 203515 and minimize GHG emissions through use of a combination of renewable energy and other low carbon energy sources.16
To implement its PCP, MCE is adopting the Action Plan described in Section IV, below. This Action Plan includes the following steps:
● MCE will conduct an annual “open season” Request for Offers (“RFO”) process to solicit offers for new renewable generation and storage projects. These resources are typically secured through long-term PPAs. MCE expects to secure PPAs for new projects in each open season conducted over the next several years; ● Periodically throughout the year, MCE will solicit offers for (i) short-term renewable energy, (ii) large hydro-electric and Asset Controlling Supply (“ACS”), (iii) RA, and (iv) load-hedging products needed to balance the portfolio and adhere to position limits established through MCE’s risk management policy and practices. These solicitations can take the form of formal RFO processes, bilateral discussions, and transactions arranged through broker markets; and
● Continuing to develop and offer customer programs that shed load, including aggregated load shift from business and residential customers.

II. Study Design
a. Objectives
MCE had the following objectives in performing the analytical work to develop its PCP and larger Compliance IRP:

1. Identify a portfolio that meets MCE’s goals for renewable energy utilization and GHG emission minimization and that has GHG emissions no greater than MCE’s proportional share of the 38 MMT 2030 GHG Emissions Benchmark and 25 MMT 2035 GHG Emissions Benchmark, as determined using the CSP calculator;

2. Identify a portfolio that achieves economic, reliability, environmental, security, and 15 This assumes a certain amount of curtailment as dictated by the CSP. Without the curtailments assigned by the CSP calculator, MCE’s renewable generation would be approximately 87%. To account for curtailment, MCE uses short-term contracts to balance its portfolio and meet its goals and obligations. This ensures that unrealized or curtailed generation is accounted for.
16 See MCE’s 2022 Operational Integrated Resource Plan available here: https://www.mcecleanenergy.org/energy-procurement/. 12 other benefits and performance characteristics that are consistent with the goals set forth in Section 454.52(a)(1) (A-I);

3. Identify a diverse and balanced portfolio that includes both short-term and long-term electricity, electricity-related, and demand reduction and management products;

4. Identify a portfolio that achieves the RA requirements established pursuant to Section 380 and fully provides MCE’s share of system reliability and renewable integration resources;

5. Identify a portfolio that fully complies with all MCE Board-adopted procurement directives;

6. Identify portfolios that are fully compliant with MCE’s obligations under the Renewable Portfolio Standard (“RPS”) program; and

7. Identify portfolios that are cost-effective and minimize rate impacts on MCE’s customers.
b. Methodology
i. Modeling Tool(s)
In developing its PCP, MCE used modeling tools that quantify portfolio targets for renewable energy content, capacity, and portfolio GHG emissions, as well as physical and financial positions to ensure adherence to MCE’s risk management policies and business practices. MCE uses proprietary models to assess annual, monthly, and hourly open positions taking into account forecasted hourly electric loads and expected deliveries from MCE’s resource portfolio.

MCE uses a proprietary financial model to project power supply costs and incorporate existing and planned procurement into an overall financial assessment of revenues, costs, and cash flows. MCE also utilizes a commercially available energy trading and risk management system to monitor positions, market exposure, credit exposure, value-at-risk, and other risk management metrics.17
Portfolio reliability was evaluated using forward-looking Effective Load Carrying Capacity (“ELCC”) values for each resource type to assess total NQC of the portfolio relative to MCE’s reliability requirements. This approach ensures MCE contributes to grid reliability commensurate with its share of system reliability needs.

For new resource selection where specific projects have not yet been identified in MCE’s procurement process, MCE relied upon the modeling and assumptions in RESOLVE as well as MCE’s recent procurement experience. Both provide insight into resource availability and cost. 17 Hitachi Energy TRMTracker.

14 Compiling Existing Resources
To populate its baseline resource templates, MCE added existing resources from the following sources:
● Existing and planned energy contracts, including MCE’s election of renewable resources through the Voluntary Allocation and Market Offer (“VAMO”) process; ● Existing and planned capacity RA contracts;
● MCE’s assigned share of capacity for CAM and Demand Response resources, taken from the most recent year-ahead CAM resource allocations provided to MCE on September 29, 2022;18 and
● Expected allocations of GHG-free energy from the Pacific Gas & Electric Company (“PG&E”) portfolio.

Selecting New Resources
To identify its new resource procurement, MCE first determined the new resource capacity it intends to add each year. To make this determination, MCE considered (i) resource need (i.e., open positions), (ii) long-term renewable contracting requirements, (iii) RPS requirements, (iv) RA requirements, (v) the need for incremental RA capacity to contribute to system reliability and renewable integration needs, (vi) the potential for technological improvements, (vii) financial considerations, and (viii) a desire to transition its portfolio toward greater use of renewable energy and storage capacity in lieu of reliance on fossil resources. MCE selected resource types based on its experience with competitive solicitations for new renewable and storage resources as well as by making reference to the studies and modeling underlying the adopted PSP portfolio.

Confirming Reliability
MCE’s portfolios were evaluated to ensure that sufficient dependable NQC is available to meet peak load requirements plus the required planning reserve margin. MCE used forward looking technology specific ELCC factors provided by the Commission to assess the contribution of each resource to system reliability. As such, MCE’s portfolio addresses the expected changes to ELCC factors and NQC of its planned resources. MCE’s PCP was designed to ensure that current incremental RA capacity obligations are met, and that MCE contributes to new resource 18 MCE’s CAM and Demand Response allocations reflect the information provided in the Aggregated CAM Resources for LSEs Plan Development (“Aggregated CAM Guidance”), issued September 29, 2022, available at https://www.cpuc.ca.gov/industries-and-topics/electrical-energy/electric-power-procurement/long-term-procurement-planning/2022-irp-cycle-events-and-materials.

16 Biomass (GWh) - - 16 - - 16
Geothermal
(GWh) - - 149 580 1,056 1,785
Hybrid or Paired
Solar and Battery
(GWh)
596 - - - - 596
Imported Hydro
(GWh) - - 120 - - 120
Large Hydro
(GWh) - 25 500 - - 525
Small Hydro
(GWh) - 37 32 - - 69
Solar Distributed
(GWh) 13 - - - - 13
Solar Existing
California (GWh) 18 1,058 79 - - 1,155
Wind Existing
California (GWh) - - 374 - 87 461
Wind New
Mexico (GWh) - - - 250 - 250
Wind New PG&E
(GWh) 290 - - - - 290
Wind Offshore
Morro Bay (GWh) - - - 400 - 400
Wind New SCE
SDG&E (GWh) - - - - 263 263
17 Additionally, MCE’s 2035 PCP includes capacity-only resources composed primarily of the following:
● CAM, and Demand Response allocations – 48 MW23
● Existing natural gas and other (planned procurement) – 549 MW MCE’s portfolio includes a mix of existing and new resources. MCE’s 2035 portfolio is composed of approximately 1,383 MW of new nameplate capacity, reflecting MCE’s role as an active participant in the State’s development of new renewable and storage resources. Additionally, MCE’s short- and long-duration storage, along with its capacity-only resources will help maintain MCE’s commitment to supporting the State’s need for reliability and renewable integration.

MCE’s PCP Is Consistent with the 2021 PSP
The new resources included in MCE’s PCP are generally consistent with the 2021 PSP’s 2035 new resource mix as adopted in D.22-02-004, as updated,24 for both the 38 MMT and 30 MMT scenarios. There are, however, certain notable differences that reflect portfolio needs and resource selection that are unique to MCE.

As demonstrated in Table 3, below, MCE’s PCP includes proportionately more new resources than would be indicated by MCE’s proportional share of new procurement for each of the resource types identified in the adopted 2021 PSP.25 Under this scenario, MCE’s portfolio includes considerably more wind, geothermal and storage resources, and less utility-scale solar resources than does the 38 MMT PSP scenario.

Importantly, Table 3 also demonstrates the PCP’s general consistency with procurement types and amounts in the 30 MMT PSP scenario. Notably, however, MCE’s PCP consists of fewer MW of procurement and different resource proportions relative to the 30 MMT PSP 23 MCE’s CAM and Demand Response allocations reflect the information provided in the Aggregated CAM Guidance issued September 29, 2022.
24 LSE Plan Filing Requirements RESOLVE Modeling Results at 16, issued June 15, 2022, available at https://www.cpuc.ca.gov/-/media/cpuc-website/divisions/energy-division/documents/integrated-resource-plan-and-long-term-procurement-plan-irp-ltpp/2022-irp-cycle-events-and-materials/lse-filing-requirement-resolve-results.pdf. 25 D.22-02-004 adopts the 38 MMT GHG target as the 2021 PSP. However, the Decision also requires LSEs to submit plans for how they would reach the 30 MMT GHG target or lower. Further, as clarified in the Administrative Law Judge’s Ruling Finalizing Load Forecasts and Greenhouse Gas Emissions Benchmarks for 2022 Integrated Resource Plan Filings, issued June 15, 2022, LSEs whose portfolios go below the 30 MMT GHG target are only required to submit one PCP.

19 Utility-Scale
Solar 17,418 465 21,794 582 22228
Battery
Storage 17,350 463 17,742 474 559
Pumped
(Long-Duration)
Storage
1,000 27 1,000 27 90
Shed Demand
Response 977 26 767 20 15
Total 50,919 1,360 56,377 1,505 1,351
The differences between MCE’s share of the 2021 PSP New Build Resources and the resources in MCE’s PCP, under either the 38 MMT or 30 MMT scenarios, reflect MCE’s planned contributions to new resource development during the planning period. MCE plans to add significant new renewable generation and storage capacity to help reduce reliance on fossil fueled generation, while minimizing GHG emissions and maintaining reliability using the most cost-effective and efficient portfolio of resources.
b. Preferred Conforming Portfolio
MCE’s PCP consists of a combination of:
● Utility-scale solar;
● In-state wind;
● Out-of-state wind;
● Off-shore wind;
● Short-duration storage;
● Long-duration storage;
● Small and large hydro-electric;
● Geothermal;
● Biomass/biogas;
● Shed Demand Response; and
● Natural gas/other (capacity only).
28 This represents 212 MW of solar hybrid procurement and 10 MW of new utility-scale solar procurement. 20 MCE’s PCP consists of the following specifical compilation of resources:
● MCE’s PCP includes the procurement of the following new resources and nameplate capacities over the course of the planning horizon:
o New wind resources totaling 265 MW (consisting of in-state, out-of-state, and off-shore wind);
o New geothermal resources totaling 109 MW;
o New hybrid resources totaling 212 MW of solar generation and 153 MW of storage;
o New grid connected battery storage of 400 MW;
o New Demand Response resources of 15 MW; and
o New long-duration storage29 of 90 MW;
● MCE’s PCP provides for the following overall resource mix in 2035:
o Large hydro-electric of 525 GWh;
o Imported hydro-electric of 120 GWh;
o Small hydro-electric of 69 GWh;
o Biogas/biomass of 46 GWh;
o Geothermal of 1,785 GWh;
o California wind of 1,014 GWh;
o Out-of-state wind of 250 GWh;
o Offshore wind of 400 GWh;
o California solar of 1,155 GWh;
o Distributed solar of 13 GWh;
o Hybrid solar and storage of 596 GWh; and
o Standalone battery storage of 2,117 MWh (capacity x duration).

As stated above, in accordance with Section 454.51(b)(3), the resource mix in MCE’s PCP achieves “economic, reliability, environmental, security, and other benefits and performance characteristics that are consistent with the goals set forth in [Section] 454.51(a)(1)].” These benefits and characteristics are discussed below.

Meeting GHG Reduction Goals
MCE’s PCP achieves results and performance characteristics consistent with the Section 454.52(a)(1)(A) goal of meeting the Commission’s 30 MMT or 25 MMT GHG reduction benchmark. MCE’s proportional share of the 30 MMT benchmark is 0.848 MMT in 2030 and

0.630 MMT in 2035. According to the Commission’s emissions calculator for the 30 MMT 29 MCE is currently interested in long-duration storage resources with at least 8 hours of duration at full capacity. 21 scenario, MCE’s PCP would account for 0.500 MMT of emissions in 2030 and 0.514 MMT of emissions in 2035.30 MCE’s proportional share of the 25MMT benchmark is 0.640 MMT in 2030 and 0.504 MMT in 2035. According to the Commission’s CSP calculator for the 25 MMT scenario, MCE’s PCP would account for 0.493 MMT of emissions in 2030 and 0.492 MMT of emissions in 2035.

Procuring Eligible Renewable Energy
MCE’s PCP achieves results and performance characteristics consistent with the goals of Sections 454.52(a)(1)(B) & (F) of ensuring that portfolios are composed of at least 50% eligible renewable resources and displacing fossil fuels within the state. In 2035 MCE’s PCP portfolio would consist of 87% eligible renewable generation. To this end, MCE has executed a number of long-term PPAs with new, California-based generating facilities that will produce Portfolio Content Category (“PCC”) 1-eligible renewable energy in excess of the 2030 requirement. Of the targeted 87% eligible renewable generation in 2035, 44.5% is under long-term contracts in 2030, and 33.6% in 2035. The remaining 42.5% and 53.4%, respectively, will be filled with long-term contracts that are currently under negotiations and/or planned as shown in both the CSPs and RDTs.31
To supplement its core procurement of PCC 1 resources under long-term contracts for its PCP, MCE engages, and will continue to engage, in short-term contracts for renewable energy supplies to balance and optimize its PCP. As of this filing, MCE has secured contracts for renewable energy volumes in excess of applicable California RPS procurement requirements through 2025, and long-term contracting requirements through 2030.

Minimizing Bill Impact
MCE’s PCP achieves results and performance characteristics consistent with the Section 454.52(a)(1)(D) goal of minimizing the impact of planned procurement on ratepayers’ bills. MCE prioritizes use of renewable energy and low carbon emitting resources, reliability, and cost competitiveness.
30 MCE notes that the increase in emissions from 2030 to 2035 results from an increase in use of system power attributable to a decrease in allocated generation from Combined Heat and Power resources, as well as increases in the volume of curtailments and exports modeled.
31 Historically, MCE has contracted with PCC 1 resources located in California. However, some resources located outside California are eligible for PCC 1, typically through direct interconnection or firm transmission rights to the CAISO. Although MCE has an established preference for in-state resources, contracting with out-of-state PCC 1- qualified resources is likely to the extent that they offer increased value or other desirable portfolio attributes during the planning period.
22 Energy and RA costs have risen sharply in recent years, and rising wholesale energy costs have placed upward pressure on customer rates. New build renewable development and storage costs have also seen substantial increases since the last IRP cycle due to a confluence of unprecedented amounts of mandated procurement on strict timelines, limited transmission capacity to support new projects, supply chain constraints, and inflationary pressures. At the same time, prices in the short-term markets for renewable energy and RA have also increased significantly resulting from increasing incidents of resource scarcity during peak hours and more numerous and extensive extreme weather events. MCE will take steps to minimize bill impacts, but near-term rate increases may be necessary to accommodate increased procurement costs.

Despite recent cost increases for new generation and storage associated with its resource plan, bill impacts can be at least partially mitigated by the fact that new renewable generation projects can have lower net costs than the prices paid in the short-term renewable energy and resource adequacy markets. In evaluating new resource commitments, MCE seeks generation and/or storage projects that meet portfolio fit considerations and that have positive net present value in consideration of expected contract costs and the value of the energy, reliability, and environmental attributes provided by the project. Such projects help reduce costumer costs relative to alternative sources of energy and capacity. Further, MCE’s PCP minimizes exposure to volatile natural gas prices and the bill impacts that can result from periodic spikes in fossil fuel prices.

Specific estimates of MCE’s average portfolio costs through 2035 are provided in Section III.e., below.

Ensuring System and Local Reliability
MCE’s PCP achieves results and performance characteristics consistent with the Section 454.52(a)(1)(E) goal of ensuring system and local reliability on both a near- and long-term basis.

The PCP meets system RA requirements as detailed in Section III.f. MCE’s PCP is reliable from both an MCE-specific and systemwide perspective under the 30 MMT and 25 MMT Scenarios.

The PCP would provide adequate energy storage and RA capacity to meet MCE’s generation needs during non-solar generating hours.

As a practical matter, the ability of MCE’s portfolio to meet MCE’s own load requirements will not be materially impacted by whether other parties procure consistent with the 30 MMT or 25 MMT target. As discussed in Section III.f., MCE’s PCP includes sufficient NQC to meet peak loads and reserve margins regardless of whether other load serving entities procure to the 25 MMT or 30 MMT benchmark targets. If other LSEs procure in accordance with a 25 MMT GHG target, the NQC and contribution to reliability of MCE’s PCP would increase by an average of 10 MW. 23 Based on results from the CSP calculator, MCE should expect more hours of curtailment for its renewable resources, greater use of system power, and higher emissions of GHG and local pollutants in the 30 MMT scenario as compared to the 25 MMT scenario; however, these differences are small relative to the size of MCE’s planned portfolios and would have no meaningful impact on reliability.

For the periods during which MCE’s load exceeds the sum of its contracted energy resources and planned storage capacity and Demand Response resources, MCE intends to ensure sufficient system capacity is available through use of firm short- and long-term RA contracts.

MCE is planning that approximately half of its RA capacity (ELCC adjusted) will be provided by new renewable and storage resources, while the other half will be provided by existing resources, most of which are likely to be dispatchable natural gas fueled generators.

MCE is proud of its role supporting reliability and renewable integration needs to date and is eager to continue supporting these important state objectives going forward. While MCE has built-in plans for traditional reliability resources (i.e., from natural gas), MCE aspires to gradually layer in reliability supply that better aligns with the State’s ultimate GHG reduction goals.

Strengthening the Bulk Transmission and Distribution Systems MCE’s PCP achieves results and performance characteristics consistent with the Section 454.52(a)(1)(G) goal of strengthening the diversity, sustainability, and resilience of the bulk transmission and distribution systems. MCE does not own, operate, or maintain the bulk transmission or distribution systems. However, MCE’s procurement of strategically located renewable generation, prioritization of local renewable generation, demand-side management efforts, and investment in distribution-side resources all serve to enhance the sustainability and resiliency of the bulk transmission and distribution systems.

Enhancing Demand-Side Energy Management
MCE’s PCP achieves results and performance characteristics consistent with the Section 454.52(a)(1)(H) goal of enhancing demand-side energy management. MCE’s PCP includes MCE’s allocation of capacity through the demand-side management programs operated by PG&E.

MCE operates a variety of energy efficiency and demand response programs, including MCE’s PeakFlex Market.32
Additionally, MCE is working to develop a pilot Virtual Power Plant (“VPP”) within the City of 32 See https://www.mcecleanenergy.org/market/ .
24 Richmond. This effort will install a suite of privately-owned distributed energy resources (“DERs”) to be dispatched into the VPP, such as rooftop solar, heat pump water heaters, smart thermostats, smart plugs, electric vehicles, and energy storage. These will send data directly to MCE and can be remotely controlled and operated together to pull power to and from the grid at strategic times, creating pockets of power to support and decarbonize the grid.

The goal of Richmond Advanced Energy Community is to connect 120 sites to the VPP including 10 rehabilitated homes, 90 homes occupied by low-to-middle income residents (which have already received solar systems from GRID Alternatives), 18 commercial sites, and 2 industrial sites. Combined, the 120 sites are expected to contribute 1 MW of solar, 2 MWh of energy storage, and 1.5 MW of flexible load by December 2024.

The VPP will allow MCE to aggregate and dispatch DERs to manage critical peak loads, minimize procurement costs, and - as market opportunities evolve - generate value in wholesale markets.

Participants may not be enrolled in other DER aggregation or demand response programs.

Participants will receive modern appliances, bill savings, and bill credits.

MCE plans to expand this program to monitor and control other customer owned DERs.

Minimizing Localized Air Pollutants with Emphasis on Disadvantaged Communities MCE’s PCP achieves results and performance characteristics consistent with the Section 454.52(a)(1)(I) goal of minimizing localized air pollutants and other GHG emissions with early priority on disadvantaged communities (“DACs”). MCE’s PCP relies primarily on renewable generation and would have low GHG and localized air pollution emissions. Further, MCE’s PCP minimizes MCE’s reliance on unspecified system power, instead opting for renewable generation, hydro generation, local energy storage, and local demand side reduction programs.

Results from the 30 MMT CSP calculator indicate the following localized air pollutants associated with MCE’s PCP in 2035:
● NOx: 68 tonnes/yr
● PM 2.5: 31 tonnes/yr
● SO2: 7 tonnes/yr
Results from the 25 MMT CSP tool indicate the following localized air pollutants associated with MCE’s PCP in 2035:
● NOx: 64 tonnes/yr
● PM 2.5: 28 tonnes/yr

27 6013314103 Bay Point Contra Costa 94565 5629 1,552 61 1,613 6013314104 Bay Point Contra Costa 94565 9278 2,217 121 2,338 6013336201 Concord Contra Costa 94520 4056 1,161 21 1,182 6013320001 Martinez Contra Costa 94553 3671 1,092 262 1,354 6013365002 North Richmond Contra Costa 94801 5590 1,213 126 1,339 6013302005 Oakley Contra Costa 94561 7290 2,051 184 2,235 6013309000 Pittsburg Contra Costa 94565 3546 1,275 175 1,450 6013310000 Pittsburg Contra Costa 94565 6257 1,646 135 1,781 6013311000 Pittsburg Contra Costa 94565 5329 1,473 67 1,540 6013312000 Pittsburg Contra Costa 94565 2243 626 82 708 6013313101 Pittsburg Contra Costa 94565 7178 2,580 491 3,071 6013313102 Pittsburg Contra Costa 94565 4595 1,341 123 1,464 6013314102 Pittsburg Contra Costa 94565 6561 1,184 33 1,217 6013373000 Richmond Contra Costa 94801 4468 897 90 987
6013375000 Richmond Contra Costa 94801 4897 1,050 96 1,146 6013376000 Richmond Contra Costa 94801 6245 1,557 78 1,635 6013377000 Richmond Contra Costa 94801 7323 2,123 168 2,291 6013379000 Richmond Contra Costa 94804 7003 1,508 203 1,711 6013380000 Richmond Contra Costa 94804 5931 2,860 380 3,240 6013381000 Richmond Contra Costa 94804 6521 1,708 191 1,899 6013382000 Richmond Contra Costa 94804 8159 1,540 114 1,654 6013392200 Richmond Contra Costa 94806 11304 2,829 172 3,001 6013358000 Rodeo Contra Costa 94572 6285 1,609 151 1,760 6013364002 San Pablo Contra Costa 94806 5531 1,693 36 1,729 28 6013366001 San Pablo Contra Costa 94806 4514 1,117 34 1,151 6013366002 San Pablo Contra Costa 94806 6627 1,584 71 1,655 6013368001 San Pablo Contra Costa 94806 4817 1,236 85 1,321 6013368002 San Pablo Contra Costa 94806 3782 956 125 1,081 6013369001 San Pablo Contra Costa 94806 7254 2,026 240 2,266 6013314200 Unincorporated
Contra Costa
County Area
Contra Costa 94565 7748 1,473 50 1,523
6013315000 Unincorporated
Contra Costa
County Area
Contra Costa 94520 3862 1,077 811 1,888

6013327000 Unincorporated
Contra Costa
County Area
Contra Costa 94520 7430 1,627 1,001 2,628
6095252502 Fairfield Solano 94533 2106 596 281 877
6095250801 Unincorporated
Solano County
Area
Solano 94592 4135 1,079 45 1,124
6095252402 Unincorporated
Solano County
Area
Solano 94534 5549 1,470 361 1,831
6095253500 Unincorporated
Solano County
Area
Solano 94571 10676 308 323 631
6095250701 Vallejo Solano 94590 3529 767 196 963
6095250900 Vallejo Solano 94590 2654 1,133 344 1,477
6095251000 Vallejo Solano 94590 2654 1,122 69 1,191
6095251200 Vallejo Solano 94590 3663 1,068 222 1,290
6095251500 Vallejo Solano 94590 4326 1,362 348 1,710
6095251600 Vallejo Solano 94590 2580 1,086 123 1,209
6095251802 Vallejo Solano 94589 2770 927 406 1,333
29 6095251901 Vallejo Solano 94589 5119 1,626 73 1,699
6095251902 Vallejo Solano 94589 6173 1,508 59 1,567
In total, MCE serves 54,897 customer accounts located within DACs. This represents approximately 9.5% of MCE’s total customer accounts (approximately 580,000).

MCE is dedicated to reducing pollution impacts and encouraging the development, health, and prosperity of DAC within and outside our service area. Our commitment is reflected in the practices, programs, and policies described below.

Green Access and Community Solar Connection Programs
MCE is collaborating with the Commission, Investor-owned Utilities (“IOU”), and other CCAs to develop community solar programs for customers in DACs. These programs will be supported by the development of an additional 5.92 MW of new, local, clean energy capacity.

The Green Access program will supply 100% renewable power to customers located in a DAC with an accompanying 20% bill discount. The program currently serves 3,000 customers, and MCE prioritizes customers who live in the highest scoring DACs and are currently participating in either the California Alternate Rates for Energy (“CARE”) or Family Electric Rate Assistance (“FERA”) discount program and need additional support to get caught up on their energy bills.

Eligible customers will be served by this 4.64 MW solar resource once it comes online, currently expected by December 2023.

The Community Solar Connection program will offer 100% solar energy and provide a 20% discount on the electricity portion of participating customers’ energy bills. This program also involves developing a solar project within 5 miles of a DAC to serve participating customers. At least 50% of the program’s participation capacity will be reserved for customers who are enrolled in CARE or FERA discount programs. Efforts to procure the 1.28 MW solar resource for this program are currently ongoing.

MCE estimates that it will be able to provide approximately 3,500 customers in DACs with bill discounts after both programs are up and running.
30 Sustainable Workforce and Diversity Policy
In 2017, MCE’s Board approved a Sustainable Workforce and Diversity Policy34 to facilitate and encourage diversity and a sustainable workforce through its support for the following:

1. Fair compensation in direct hiring, renewable development projects, customer programs, and procurement services;

2. Development of locally generated renewable energy within the MCE service area;

3. Direct use of union members from multiple trades;

4. Quality training, apprenticeship, and pre-apprenticeship programs;

5. Direct use of local businesses in MCE’s service area;

6. Development of California-based job opportunities;

7. Business and workforce initiatives located in low-income and disadvantaged communities;

8. Direct use of Disabled Veteran-owned Business Enterprises (“DVBE”) and LGBT-owned Business Enterprises (“LGBTBE”);

9. Direct use of green and sustainable businesses; and

10. Direct hiring practices that promote diversity in the workplace.

More recently, in 2022 MCE adopted Sustainable Workforce Guidelines35 to create a more detailed plan for implementing its Sustainable Workforce and Diversity Policy, further demonstrating our commitment to procuring resources that benefit our customers, our planet, and our future. These guidelines outline how MCE integrates these priorities into PPAs with third parties, MCE-owned or MCE-led power generation projects, and MCE customer programs, services, supplies, and direct hiring. For example:
● When possible, MCE shall give preference to projects within MCE’s service area and to CBOs and local associations serving disadvantaged and low-income communities. ● MCE has three tiers of requirements for union labor depending on the location of proposed projects. Projects located in Contra Costa County and over 1 MW in size must adhere to the terms of the Project Labor Agreement (“PLA”) between MCE and International Brotherhood of Electrical Workers (“IBEW”) Local 302 (“MCE/IBEW PLA”).

Projects within Napa, Marin, or Solano County must participate in a PLA of similar 34 See MCE November 16, 2017, Board of Directors Meeting Packet, Agenda Item No. 7 Attachment A https://www.mcecleanenergy.org/wp-content/uploads/2020/05/MCE-Board-Meeting-Packet-November 2017.pdf. 35 See https://www.mcecleanenergy.org/wp-content/uploads/2022/05/MCE-Sustainable-Workforce-Guidelines 05122022.pdf. 31 scope and requirements with participating unions for workforce hired as described in the MCE/IBEW PLA. Projects outside of MCE’s service area are encouraged to enter into project labor agreements of similar scope and requirements with participating unions for workforce as described in the MCE/IBEW PLA.
● For projects located in MCE’s service area, 50% of work hours are required to come from permanent residents who reside within the same county as the project. ● MCE will not accept any proposals for projects that rely on equipment or resources built with forced labor. MCE adopted this prohibition two years ahead of federal law, signed by President Biden in June 2022.
● Any renewable development project that is developed or owned by MCE qualifies as a public works project and requires prevailing wages to be paid.

These efforts have resulted in significant local developments. To date, MCE has helped build almost 48 MW of new renewable projects in our service area. All local projects over 1 MW were built with union labor. Additionally, in 2021 MCE launched two new community solar programs, Community Solar Connection and Green Access, both described above.

These programs offer qualifying customers living in a CalEnviroScreen-designated DAC access to 100% renewable energy and a 20% discount on their electricity bills for up to 20 years. Both programs will be supported by the development of additional new clean energy resources.

In developing its Compliance IRP, MCE carefully considered the impact of its resource procurement on DACs. MCE’s PCP minimizes the use of fossil-based resources and unspecified system power, reducing reliance on natural gas generators that have an impact on DACs.

Ad Hoc Workforce Development
Growing the green economy, supporting local contractors, and providing access to workforce development opportunities are core to MCE’s mission. One avenue for job creation is through energy efficiency, which lowers energy consumption and can save customers money while reducing greenhouse gas pollution and producing more equitable communities. Importantly, improving the built environment through energy efficiency also creates strong job opportunities, including among populations facing additional barriers to workforce entry.

Encouraging the creation of local green job opportunities is rooted in the history of MCE’s efforts to create more equitable communities, while also reducing GHG emissions through renewable energy projects and electrification of the built environment and the transportation sector. For example, MCE has:
● Partnered with the Marin City Community Development Corporation from 2012–2016 32 to train 59 community members and connect them to solar installation and energy efficiency jobs.
● Partnered with RichmondBUILD in 2013, 2015, and later in 2021 to help 44 job seekers develop construction, numeracy, and literacy skills, and later connect them with related jobs for MCE Solar One and an LED retrofit project for city streetlights. ● Partnered with Rising Sun Center for Opportunity in 2012 and 2016 to train youth to provide no-cost energy and water-saving assessments in the cities of Richmond, El Cerrito, and San Pablo. More recently in 2021–22, helped customize a Rising Sun training construction curriculum to train five cohorts on green construction basics and give them an intro to electrification and energy storage systems. ● Coordinated the installation of a new call center in the City of Pittsburg through its contract with Calpine in 2017, and then partnered with Future Build in Pittsburg (a county workforce development program) to train students on call center basics, call handling, energy data, and more. Graduates of the training were offered positions at the new call center.
● Partnered with GRID Alternatives in 2021 to train six job seekers from Marin City and the Canal District on solar installation skills and provided them a paid stipend for their participation, to increase access and minimize barriers. ● Sponsored a collaboration with Puertas Abiertas Community Resource Center to develop a direct connection between local hard-to-reach communities and the opportunity to inform and engage with these communities on MCE programs and services, especially those programs developed specifically for underserved populations.

This program sponsorship was a workforce development opportunity for organization staff to learn more about renewable energy, energy efficiency, and environmental sustainability.

To deepen MCE’s commitment to creating equitable green jobs, MCE has been an active participant in the regional High Road Training Partnership (“HRTP”) led by the Rising Sun Center for Opportunity since 2021. The joint project aims to understand regional decarbonization labor market demands, workforce issues, and training needs; establish industry labor standards; and develop clear, accessible training pathways to building decarbonization jobs in the Bay Area, especially for entry-level and disadvantaged workers.

Together with other key partners — including the Association for Energy Affordability, Electrify My Home, Inclusive Economics, Eco Performance Builders, Building Electrification Institute, Bay Area Metro, GENTEC Services, Emerald Cities Collaborative, StopWaste, the Greenlining Institute, Construction Trades Workforce Initiative, the Cities of Berkeley and Oakland and the Association of Bay Area Governments — MCE staff collaborate and hear from leaders in the 33 industry to address important equity and access aspects of a renewable economy. As a member of the Equity and Public Agencies Working Groups, MCE staff work to lay the groundwork for this industry while improving agency programming.

Creating Energy Efficiency Jobs
In 2018, the CPUC awarded MCE $2.24 million through 2025 to offer a broad spectrum of opportunities to prepare the local workforce for careers in energy efficiency. This funding allows MCE to streamline workforce investments into a sustainable pipeline of long-term green job opportunities for community members, while strengthening the local economy and contributing to a just transition to a clean energy economy. This path is especially important in communities where the fossil fuel industry has long been a primary employer for generations of families. To ensure that a decarbonized energy future provides economic opportunities for all, workforce programs like these are a necessary link to train for the skills needed to enter the green economy.

As a result, in 2020 MCE launched the Workforce, Education, and Training (“WE&T”) Program to create a geographically diverse pool of training partners able to provide job seekers with the skills necessary to be competitive in the energy efficiency and electrification sector. This program funds on-the-job training and up to 12 months of wrap-around services to support their transition to a new career in energy efficiency and electrification. While providing an onramp for job seekers, the WE&T Program concurrently allows vetted contractors working in MCE’s service area to be matched with these prequalified job seekers for 160 hours of no-cost project assistance and labor. By influencing both the supply side and demand side of this industry, MCE hopes to increase the number of skilled workers and strengthen the local labor market.

With engagement from local partners, community colleges, and the existing contractor workforce, MCE has developed an internship program to achieve the following goals:
● Upgrade the existing contractor workforce’s technical expertise on energy efficiency and electrification technology;
● Fund the training of job seekers;
● Match qualified job-seeker trainees with trained contractors and pay for a local internship in a “learn and earn” model; and
● Provide project site opportunities where the intern can install efficiency and electrification measures while helping MCE customers increase the efficiency, health, and safety of their homes and businesses.
34 Long term, MCE hopes to solidify this trainee-to-employee pipeline so that it can continue investing in technical training, creating onramps to career pathways, providing job security, and building the economic health of member communities.

Equity in Power Purchasing
As of 2021, MCE’s Open Season solicitation encourages suppliers to consider community benefits and equity metrics when submitting offers. Some of the optional elements that MCE solicits in offers include:
● Support for educational programs, environmental justice initiatives, and workforce development and training initiatives;
● Participation of contractors, subcontractors, or businesses owned by disabled veterans;
● Projects located in a designated DAC or employing workers living in a designated DAC; and
● Use of components and materials manufactured or assembled in the United States.

In late 2020, when issues related to the use of forced labor for solar equipment production in Xinjiang, China, were reported, MCE incorporated new language into its PPA term sheets and contracts that prohibit MCE from contracting with facilities that rely on equipment or resources built with forced labor. This language was incorporated into MCE’s 2021 and 2022 Open Season, Green Access, and Community Solar Connection PPAs, and will continue to be an MCE procurement requirement.

Strategic Recruiting and Hiring Practices
Practices include targeted job postings, partnerships with community-based organizations (“CBOs”), education and employment organizations, physical attendance at job recruitment fairs, blind resume reviews, and the creation of diverse hiring panels. Some MCE jobs may substitute experience for education requirements. MCE has also tailored employee benefit packages to be more inclusive and to apply to a broad range of people.

Community Power Coalition
To facilitate direct community collaboration in the development, progress, and evolution of its mission MCE engages its Community Power Coalition (“CPC”). Formed in 2014, the CPC seeks to represent the interests of underrepresented and historically marginalized communities through collaboration and open dialogue with MCE. The CPC currently has over 40 members and meets every two months. MCE’s recruitment for the CPC prioritizes organizations that:
35 ● Expand awareness and access to affordable renewable services; ● Accelerate the transition to a clean energy future through workforce development training opportunities;
● Develop inclusive programs and policies at MCE; and
● Identify just and equitable community collaboration opportunities aligned with MCE’s environmental justice values.

Adding these voices and their questions to the CPC working group deepens MCE’s understanding about the groups’ challenges and the measures or types of support that are needed. MCE’s CPC strengthens its connection to the community and offers expert advice on the needs of their constituents and how MCE can best support underserved customers and environmental equity through its programs, policies, and procurement.

Building Community Resiliency
To mitigate the impact of grid outages and Public Safety Power Shutoff (“PSPS”) events, and improve overall grid reliability, MCE’s Board of Directors approved a Resiliency Fund in 2019.

In 2020, MCE launched its Energy Storage Program to deploy up to 15 MWh of customer-sited battery storage systems that can provide backup power during grid outages and reduce GHG emissions and costs. This program prioritizes vulnerable customers and populations that are disproportionately affected by grid outages. The program leverages incentives from the CPUC’s Self-Generation Incentive Program (“SGIP”), coupled with gap funding and performance-based payments provided through MCE’s Resiliency Fund.

To extend the impact of this program, MCE is working with the Marin Community Foundation.

Through a three-year grant of $750,000 from the Buck Family Fund, this partnership is stretching MCE’s contributions to secure local resilience in Marin. These funds will be used to cover the costs for select critical facilities operated by nonprofits throughout Marin County to provide backup power to vulnerable communities during planned or unplanned outages.

As described above, on May 26th, 2022, MCE was approved to join the implementation of a $5 EPIC grant from the CEC to develop an Advanced Energy Community (“AEC”). The grant will be used to develop a pilot VPP within the City of Richmond. The goal of Richmond Advanced Energy Community is to connect 120 sites to the VPP including 10 rehabilitated homes, 90 homes occupied by low-to-middle income residents (which have already received solar systems from GRID Alternatives), 18 commercial sites, and 2 industrial sites. Combined, the 120 sites are expected to contribute 1 MW of solar, 2 MWh of energy storage, and 1.5 MW of flexible load by December 2024.
36 The VPP will allow MCE to aggregate and dispatch DERs to manage critical peak loads, minimize procurement costs, and - as market opportunities evolve - generate value in wholesale markets.

Participants may not be enrolled in other DER aggregation or demand response programs.

Participants will receive modern appliances, bill savings, and bill credits. During later phases, this program may help MCE expand its role as a California Independent System Operator (“CAISO”) market participant by aggregating resources that can be dispatched into the CAISO market.

COVID-19 Customer Support
In response to the COVID-19 pandemic, MCE launched additional programs and services to support its customers. The $10 million MCE Cares Credit Program offers qualifying customers bill relief in the form of a $10 monthly bill credit for residential customers and a 20% monthly bill credit for small businesses. This program pairs with state discount programs and the Arrearage Management Program (“AMP”), in which MCE was an early participant.

MCE’s ongoing COVID relief efforts include suspension of collections; direct outreach to customers to encourage enrollment in existing discount and utility bill assistance programs; an education and awareness program to spread the word about community resources and programs for financial assistance; and free EV charging at MCE’s San Rafael office. The relief efforts were promoted online, via social media, with signage, and through local business and residents groups from early 2020 through the summer of 2022. MCE also launched two webpages providing a comprehensive list of COVID support resources for residential and small business customers, by county. In 2021, MCE partnered with local CBOs to distribute bill-savings program flyers in English and Spanish. e. Cost and Rate Analysis
MCE strives to minimize carbon emissions associated with the electricity it supplies to customers while maintaining competitive rates and minimizing customer bill impacts. MCE also prioritizes reliability and seeks a supply portfolio that minimizes risks related to transmission congestion, curtailments, project development risks, and other uncertainties that impose the potential for unanticipated costs. MCE’s PCP was developed with these goals in mind.

Resources were selected for least cost and best portfolio fit based on associated emissions, delivery profile, risk, commercial viability, and reliability. MCE considers both the direct resource costs (e.g., contract price) as well as the value of each resource in its portfolio, taking into account the different resource characteristics of the various portfolio options. 37 MCE modeled the expected portfolio costs of its PCP to evaluate cost and rate impacts on customers. The results of this cost analysis are illustrated in the figure below. System average portfolio costs are projected to increase through 2024, decline from 2025 through 2028, and slowly increase from 2029 through 2035. The compounded annual rate of growth (nominal dollars) between 2022 and 2035 is 0.5%, which is below the expected rate of inflation. The near-term cost increases are primarily driven by high prevailing CAISO energy costs, which are influenced by the significant increase in natural gas prices since the beginning of 2022.

Exceptionally high resource adequacy costs are also driving increases in MCE’s average portfolio costs. These cost pressures are expected to moderate as new resources are developed and displace more expensive purchases from the short-term markets. It must be noted that the projected portfolio costs are dependent on assumed costs for new resources, and these are subject to considerable uncertainty. MCE engages in competitive solicitations for resource selection and makes resource decisions based on prices offered to it during these solicitations.

MCE has observed very little stability in offered resource prices over time as market conditions and external events such as procurement orders, trade tariffs, tax policy and supply chain conditions impact resource costs that are available at any point in time. If these events persist, or additional external events (e.g., new procurement orders) occur, the average portfolio costs may instead continue to increase in excess of MCE’s current projections. While MCE’s PCP provides a helpful framework for procurement decisions going forward, MCE must remain flexible to respond to market conditions or technological changes as circumstances change.

MCE will take steps to minimize bill impacts, but near-term rate increases may be necessary to accommodate increased procurement costs.

In evaluating new resource commitments, MCE seeks generation and/or storage projects that meet portfolio fit considerations and that have positive net present value in consideration of expected contract costs and the value of the energy, reliability, and environmental attributes provided by the project. Such projects help reduce consumer costs relative to alternative sources of energy and capacity.

New resources were selected for the PCP with the goal of minimizing ratepayer impacts, while meeting reliability and environmental policy goals. MCE’s plan diversifies across different renewable and low-carbon generation technologies with the goal of reducing use of system energy, thereby reducing market risk and emissions. MCE selected new resources that provide reliability and low emissions (e.g., geothermal) and other carbon-free technologies that have low expected costs (e.g., wind), which in conjunction with resources already under contract provide a least-cost, best-fit portfolio solution. In modeling expected ratepayer costs, MCE generally used cost assumptions consistent with RESOLVE modeling and the PSP. While not the lowest cost resource option, geothermal resources were included in the PCP to provide 38 reliability benefits from additional clean, firm resources. These resources have relatively low GHG emissions, and their ability to reliably produce energy on a near 24X7 basis warrants a role despite somewhat higher costs. Technological diversification in use of resources capable of providing firm energy reduces ratepayer risk that could arise from overdependence on new technologies such as long duration storage. The PCP includes lower cost wind resources to help minimize ratepayer impacts while meeting environmental and reliability objectives. MCE’s PCP also minimizes exposure to volatile natural gas and system power prices and the bill impacts that can result from periodic spikes in fossil fuel prices. f. System Reliability Analysis
39 40
g. High Electrification Planning
Under a high electrification scenario, MCE’s energy and peak demand requirements would increase, with most of the increase occurring toward the latter end of the planning period.

MCE projected the load impacts of a high electrification scenario based on the 2022-2023 TPP High Electrification Load Sensitivity RESOLVE Modeling Results available on the 2019-2020 IRP Page.36
Assuming similar impacts within the MCE service territory, MCE’s adjusted load forecast is shown below:
36 https://www.cpuc.ca.gov/-/media/cpuc-website/divisions/energy-division/documents/integrated-resource-plan-and-long-term-procurement-plan-irp-ltpp/2019-2020-irp-events-and-materials/2022-2023-tpp-high-electrification-sensitivity-resolve-results.pdf.

43 renewable generation MCE has added to the grid and the additional approximately 500 MW37 of new build that MCE currently has under contract and that will be coming online by mid-decade. Further, as demonstrated in MCE’s PCP, which covers the full planning horizon, MCE will continue to drive significant new resource development, which will have a corresponding decrease in MCE’s planned use of existing resources.

As compared to MCE’s 2020 IRP, planned reliance on existing resources in 2030 has declined from 754 MW to 503 MW. Under MCE’s PCP, existing resources are planned to make up less than half of MCE’s total portfolio NQC in 2035. These existing resources include renewable resources that are already online and under contract, expected allocations of CAM resources from the PG&E portfolio, and expected resource adequacy contracts with existing generators.

Particularly during this energy transition and the need for renewables integration, it is reasonable and necessary to assume continued use of existing resources in light of studies indicating the importance of retaining existing resources to ensure grid reliability. The 2021 PSP, for example, shows retention of much of the existing natural gas fleet. MCE’s planned reduction in use of existing resources from 100% today to less than 50% in 2035, however, accommodates planned generator retirements and provides a reasonable transition away from fossil fueled capacity toward storage and other non-GHG-emitting technologies. MCE utilizes various procurement strategies to ensure access to resources in the market, including multi-year forward contracting with new and existing resources. i. Hydro Generation Risk Management
In developing its PCP, MCE took the following three key steps to manage the risk of reduced hydro-electric availability due to in-state drought:
● First, MCE reduced its overall reliance on large hydro-electric generation by adopting ambitious 2035 targets for renewable energy (which excludes large hydro-electric).

More specifically, MCE’s PCP in 2035 consists of 87% eligible renewable generation, which will limit its large hydro-electric procurement to 13% or less. This compares to MCE’s current use of large hydro for up to 40% of its electricity supply. MCE’s 87% renewable energy target significantly exceeds its current 60% level, and it also exceeds the 85% target that MCE submitted to the Commission in its 2021 Compliance IRP. ● Second, to the extent hydro-electric fits into the portfolio, MCE has an established network of Pacific Northwest hydro suppliers, including entities that have substantial 37 This number does not include incremental Shed Demand Response that MCE recently secured under contract (i.e., 15 MW of September NQC that is eligible incremental capacity under D.19-11-016). 44 ACS energy volumes. As a result of these substantial ACS volumes, suppliers are able to sell MCE reliable, firm volumes.
● Third, MCE has the ability to take deliveries of hydropower outside of the CAISO and schedule/import such volumes into the CAISO on its own, as a purchasing-selling entity registered with the North American Electric Reliability Corporation (“NERC”)-affiliated North American Energy Standards Board (“NAESB”). This substantially increases MCE’s flexibility as a counterparty and therefore provides MCE increased access to greater volumes of non-California hydro-electric resources from suppliers that may not be willing, themselves, to be the importer of record.

To the extent that hydro supply is unavailable, MCE would plan to use other sources of low carbon or carbon-free energy, which may include additional qualifying renewable energy.

Considering the relatively small volume of planned large hydro, the cost impacts of supply unavailability is limited. At the extreme, if MCE needed to replace its entire planned large hydro-electric energy with a renewable energy source such as wind, the cost impact to the portfolio is estimated to be less than 10%. A more realistic drought scenario would have cost impacts in the range of 0% to 5%. Moreover, the PSP’s hydro-electric energy resources are planned as energy-only. As such, there would be no direct reliability impacts to MCE’s PSP in the event of drought, although there may be system-wide reliability impacts to the extent that other LSEs utilize large hydro-electric resources for capacity purposes.

One technique MCE uses to manage variable hydro conditions is to include planned margins of over procurement in its hydro-electric purchasing strategy. These reserve margins apply to forward procurement and are gradually released as better information about hydro-electric availability becomes known.
j. Long-Duration Storage Planning
MCE is planning significant new battery storage capacity to help balance load and supply as it integrates a greater percentage of renewable energy into its supply mix and continues to reduce reliance on natural gas generation capacity. MCE sees a greater need and role for long-duration storage as the grid continues to evolve. To address this need, MCE is procuring to meet its long-duration storage requirement under D.21-06-035 (i.e., 29 MW of NQC) and anticipates procuring an additional 50 MW NQC of long-duration storage resources in the 2030 to 2035 timeframe.

In MCE’s view, battery storage technology is currently the most commercially viable technology to qualify for this long-duration attribute. However, MCE is also evaluating other technologies that have long-duration storage capability as well. Technology performance risk is the biggest 45 unknown at present because, with the exception of pumped hydro storage, there is no track record for utility scale, long-duration storage. MCE expects rapid technological improvement in battery storage as the industry continues to scale-up and anticipates declining costs in the longer-term. In the short-term, however, costs are increasing, and project opportunities are limited, particularly when the procurement is on accelerated procurement timelines. These factors may impact the pace at which MCE adds storage to its resource portfolio. k. Clean Firm Power Planning
MCE has prioritized acquisition of clean firm resources beyond what is required under existing Commission procurement orders. Despite higher costs, clean firm resources provide reliable capacity and a higher-value energy delivery profile as compared to solar and other intermittent resources. MCE is planning for greater use of geothermal resources over time due to its low carbon emissions and high resource value. Unfortunately, supply of geothermal, and clean firm resources generally, is very limited in California, and the cost of new-build resources is significantly higher. Clean firm energy imported from other balancing areas is complicated by transmission availability and the need to obtain equivalent Maximum Import Capability (“MIC”) through the CAISO in order to utilize the capacity under the resource adequacy program.

Despite these challenges to their expanded use, clean firm resources are important contributors to reliability and offer operational attributes that cannot be replicated by current-technology storage or other resource types. To develop these resources cost-effectively and efficiently, California LSEs will need the commitment of regulatory agencies and CAISO to facilitate this resource development by ensuring regulatory procedures and requirements align with market realities and that the transmission infrastructure necessary for this development is available and accessible to California LSEs.
l. Out-of-State Wind Planning
MCE’s PCP includes 70 MW of new, out-of-state wind, assumed to be located in New Mexico, with deliveries commencing in 2030. The choice of New Mexico wind is not intended to reflect a definitive plan for procurement from this area, and other locations for future wind projects are possible. New Mexico was selected as a likely source based on MCE’s review of wind projects that have been offered in recent solicitations. These opportunities utilize existing firm transmission routes into the CAISO. However, MCE observes the significant potential in the PSP for wind located in Wyoming and Idaho, as well as transmission projects being planned that would allow for delivery of this resource to California, which would indicate opportunities to contract for new wind from these areas should be prevalent in the 2030 timeframe provided the planning and construction of the Southwest Intertie Project-North (“SWIP-North”) transmission line proceeds expeditiously. Absent certainty that the SWIP-North transmission 46 line will be available with the appropriate level of import allocations and deliverability assurances for California LSEs, it will be difficult, or impossible to invest in this region’s renewable generation potential.
m. Offshore Wind Planning
MCE’s PCP includes 95 MW of offshore wind, assumed to be located at Morro Bay, with deliveries commencing in 2033. MCE has not yet seen any proposed opportunities to contract for offshore wind and is basing its planning assumption on the significant potential indicated in the PSP. Offshore wind appears to be a high potential resource with relatively high-capacity factors and resource adequacy values. At this time, costs of offshore wind development and maintenance infrastructure are largely unknown. As such, cost and development timelines pose the greatest risk to utilization of this resource. Despite these near-and possible near-term barriers to progress on this front, MCE is monitoring the issue as it evolves, and procurement of offshore wind becomes feasible.
n. Transmission Planning
i. New Projects
This section describes new generation projects that are under development and planned projects that have been specifically identified through MCE’s procurement processes where there is sufficient locational specificity that could be useful to the transmission planning process.
ii. Projects Under Development
Strauss Wind, LLC
This is a new-build wind project. The expected commercial operation date (“COD”) is in 2023, and MCE intends to apply this resource towards its procurement requirements under D.19-11-016. The project is located in Santa Barbara County.

The interconnection queue position is WDT-1320. All transmission upgrades needed for this project have been completed. The Strauss Wind project is represented in both the 30MMT and 25MMT RDTs, respectively, as incremental capacity. Please refer to row 41 of the unique_contracts tab in MCE’s RDTs.

Golden Fields Solar IV, LLC
47 This is a new-build hybrid project located in Kern County that pairs 100 MW of solar with 92 MW four-hour battery storage. The project has an expected COD of March 2025 and is intended to apply towards MCE’s mid-term reliability (“MTR”) requirements under D.21-06-035. The interconnection queue position for this resource is Q-1211, and the project will connect at the Southern California Edison (“SCE”) Whirlwind 230 kV substation. Transmission upgrades needed for this project are expected to be completed in October 2024. These transmission upgrades are described in Appendix A to the Large Generator Interconnection Agreement (“LGIA”) and include participating transmission owner (i.e., SCE) reliability network upgrades.

The Golden Fields Solar project is represented in both the 30MMT and 25MMT RDTs, respectively, as incremental capacity. Please refer to row 51 of the unique_ contracts tab in MCE’s RDTs.

Daggett Solar Power 3, LLC
This is a new-build hybrid project located in San Bernardino County that pairs 110 MW of solar with 60 MW of four-hour battery. The project has an expected COD of August 2023, and MCE intends to apply this capacity towards its MTR requirements under D.21-06-035. The interconnection queue position is Q-1314, and the project will connect at Kramer Substation 220kV switchrack. Transmission upgrades needed for this project are expected to be completed in December 2022. These transmission upgrades are described in Appendix A to the LGIA and include participating transmission owner (i.e., SCE) reliability network upgrades. The Daggett Solar Power project is represented in both the 30MMT and 25MMT RDTs, respectively, as incremental capacity. Please refer to row 55 of the unique_ contracts tab in MCE’s RDTs.

Hecate Grid Humidor Storage 185, LLC
This new 185 MW four-hour battery storage project has an expected COD of April 2024 and will be located in Los Angeles County. MCE intends to apply this capacity towards its MTR requirements under D.21-06-035. The interconnection queue position is Q-1629, and the project will connect at SCE Vincent Substation, 220kV Bus. Transmission upgrades needed for this project are expected to be completed in Q4 2023. These transmission upgrades include extending the existing 230kV bay within the substation and installing an intermediate structure to connect to the Point of Interconnection (“POI”) riser outside of the substation. The Hecate Grid Humidor Storage project is represented in both the 30MMT and 25MMT RDTs, 48 respectively, as incremental capacity. Please refer to row 64 of the unique_ contracts tab in MCE’s RDTs.

RPCA Solar 3 - Byron Highway Solar
This is a new-build 5 MW solar project located in Contra Costa County. The project has an expected COD of November 2022. The interconnection queue position is 2296-WD, and the project will connect at Brentwood distribution substation. All transmission upgrades needed for this project have been completed. The RPCA Solar 3-Byron Highway Solar project is represented in both the 30MMT and 25MMT RDTs, respectively. Please refer to row 40 of the unique_contracts tab in MCE’s RDTs.

Ranch Sereno Clean Power, LLC
This is a new build 2MW solar project with 0.8 MW of four-hour battery storage. The project is located in Contra Costa County and has an expected COD of February 2024. The interconnection queue position is 2597-WD, and the project will connect at PG&E’s Brentwood distribution substation. No transmission upgrades are required for this project. The Ranch Sereno Clean Power project is represented in both the 30MMT and 25MMT RDTs, respectively. Please refer to row 52 of the unique_contracts tab in MCE’s RDTs.

CES Electron One Farm, LLC
This new-build project consists of two solar projects sized at 4.4 MW and 0.24 MW.

The projects are located within specified Disadvantaged Community areas in Fresno County and have an expected COD of December 2023. The interconnection queue position is 2226-WD, and the project will connect at PG&E’s Panoche distribution substation. No transmission upgrades are required for this project. The CES Electron One Farm project is represented in both the 30MMT and 25MMT RDTs, respectively.

Please refer to rows 53 and 54 of the unique_contracts tab in MCE’s RDTs. iii. Projects Under Review
49 iv. Planned New (Generic) Projects
The following projects included in the PCP are generic in nature. Locations and technology resource types are subject to change as MCE advances in its procurement.

OS22 New Wind 2026
This generic 100 MW wind project with initial deliveries commencing in 2026 is assumed to be located in the Tehachapi area.

Generic LT Wind NM 2030
This generic 70 MW wind project with initial deliveries commencing in 2030 is assumed to be located in New Mexico. Please see subsections iv. and v., below, for additional details on planning assumptions for this project.

Generic LT Wind 2033
This generic 95 MW wind project with initial deliveries commencing in 2033 is assumed to be located offshore of Morro Bay. Please see subsections iv and v, below, for additional details on planning assumptions for this project.

Generic LT Geothermal 2030
This generic 75 MW geothermal project with initial deliveries commencing in 2030 is assumed to be located in the Imperial Valley.

MTR LDS 2026
This generic eight-hour battery storage project with initial operation commencing in 2026 is assumed to be located in Contra Costa.
50 Generic LDS 2030
This generic eight-hour battery storage project with initial operation commencing in 2030 is assumed to be located in Contra Costa County.

Generic 4 Hour Storage 2028
This generic four-hour battery storage project with initial operation commencing in 2028 is assumed to be located in Solano County.

Generic 4 Hour Storage 2034
This generic four-hour battery storage project with initial operation commencing in 2034 is assumed to be located in Napa County.

IV. Action Plan
a. Proposed Procurement Activities and Potential Barriers To achieve its PCP over the planning horizon, MCE plans to steadily procure volumes at regular intervals to allow MCE to keep within its established position limits and avoid concentrated procurement during any particular market environment. This is consistent with MCE’s risk management approach to spread out the potential cost risks that may be at play in the market at any given year, while maximizing the potential for MCE to optimally procure. At a high level, MCE plans to procure renewables and storage, large hydro-electric and ACS, RA (including incremental capacity required by the Commission) and load-hedging products.

MCE’s goal is to procure such products in a manner that is cost effective, achieves emissions and reliability objectives, and supports a well-balanced and optimal resource portfolio.

To support this goal, MCE also considers the following strategies:

Joint Solicitations
Joint solicitations can expand the procurement opportunities available to a CCA, as well as provide procedural efficiencies, economies of scale, and overall cost savings for participating organizations. MCE is closely networked with other CCAs through its membership in the California Community Choice Association (“CalCCA”), the trade organization representing California’s CCA sector, and regularly coordinates with other CCAs regarding prospective 51 procurement opportunities and portfolio balancing activities.

Optimizing Existing Procurement
As MCE considers its long-term resource needs, it will evaluate options in its future PPAs to increase output through either facility upgrades or adding new capacity to the generating facility. Expanding existing facilities may provide additional generation at reduced costs with a lower risk of project failure because the need for distribution system upgrades and permitting may be reduced. However, MCE has experienced some challenges as it pertains to transmission upgrades and deliverability of new capacity on to the grid. MCE continues to engage with relevant stakeholders and developers to evaluate the feasibility of such expansions for implementation.

Annual Energy Solicitations
In addition to periodic joint solicitations, MCE will also run targeted solicitations in the upcoming years to further optimize its current portfolio needs. Such solicitations may provide MCE with flexibility and potential to meet specific portfolio needs and obligations unique to MCE.

MCE also considers the deliverability characteristics of its resources (including the expected delivery profile, available capacity and dispatchability attributes, if any, associated with each of its generating resource and/or supply agreements) and reviews the respective risks associated with short- and long-term purchases as part of its forecasting and procurement processes.

These risk evaluations include, but are not limited to, transmission availability, MIC allocation, and exposure to global supply and market forces.

These efforts lead to a more diverse resource mix, help to address grid integration issues, improve the probability of project delivery, and provide value to MCE’s member communities through reduced costs and support in achieving planned procurement objectives.

MCE has a well-established procurement process that it will use to steadily achieve its PCP over the next twelve years (i.e., by 2035). This process is used by MCE in executing all its planned new resources. MCE’s procurement process includes the following ten key activities:

1. Load forecasting based on the number and types of customers, potential service territory expansions, opt-out rates, electrification trends, demand-side resources and weather;

2. Integrated resource planning based on load forecasts, renewables and emissions targets, agency-wide budgetary considerations and customer rate implications, 52 long- term contracting requirements and goals for new steel in the ground, grid reliability needs and capacity requirements, market price hedging needs and goals for local resources, local resiliency and local workforce development;

3. Calculating open positions and interim volumetric needs based on MCE’s risk management policies;

4. Soliciting volumetric needs through RFOs, bilateral discussions or brokers;

5. Evaluating offers using a combination of proprietary and public models;

6. Negotiating (and ultimately executing) power purchase agreements, enabling agreements and confirms – including credit provisions and collateral requirements;

7. Managing pre-COD executed contracts and monitoring progress towards key development milestones (such as interconnection status, deliverability studies, siting, zoning, permitting, financing, construction, commercial operation, etc.)

8. Managing post-COD executed contracts: obtaining generation forecasts, bidding/scheduling resources into the CAISO markets, validating and paying invoices, etc.;

9. Bidding/scheduling MCE’s load into the CAISO markets; and

10. Regulatory compliance reporting.

With respect to activity number four listed directly above, MCE plans to conduct an annual “open season” RFO in the first half of each year for new renewable generation and storage projects. MCE anticipates that the majority of its open seasons over the next several years will result in executed long-term PPAs for new renewables and/or storage, and MCE anticipates that such projects will achieve commercial operation within 3 years of contract execution. In these solicitations for long-term renewable energy and storage, MCE imposes numerous bid requirements on interested respondents. These requirements address a variety of considerations and are intended to identify the best qualified suppliers of MCE’s long-term renewable energy needs. Such requirements include:

1. Overall quality of response, inclusive of completeness, timeliness, and conformity;

2. Price and relative value within MCE’s supply portfolio;

3. Project location and local benefits, including local hiring and prevailing wage considerations;

4. Project development status, including but not limited to progress toward interconnection, deliverability, siting, zoning, permitting, and financing requirements;

5. Qualifications, experience, financial stability, and structure of the prospective project team (including its ownership);

6. Environmental impacts and related mitigation requirements, including impacts to air pollution within communities that have been disproportionately impacted by the 53 existing generating fleet;

7. Potential impacts to grid reliability;

8. Acceptance of MCE’s standard contract terms; and

9. Development milestone schedule, if applicable.

In addition, MCE is planning to solicit offers periodically throughout each year for short term renewable energy, large hydro-electric and ACS, resource adequacy and load-hedging products needed to balance the portfolio and adhere to position limits established through MCE’s risk management policy and practices.

MCE uses a portfolio risk management approach in its power purchasing program, seeking low-cost supply, based on then-current market conditions, as well as diversity among technologies, production profiles, project sizes and locations, counterparties, lengths of contract, and timing of market purchases.

A key component of this process relates to the analysis and consideration of MCE’s forward load obligations and existing supply commitments with the objectives of closely balancing supply and demand, cost/rate stability and overall budgetary impacts, while leaving some flexibility to take advantage of market opportunities and technological improvements that may arise over time. MCE monitors its open positions separately for each renewable generating technology, GHG-free resources, conventional resources, and its aggregate supply portfolio.

MCE maintains portfolio coverage targets of up to 100% of expected customer energy requirements in the near-term (0 to 2 years). Typically, MCE has gradually larger open positions in the mid- to long-term, consistent with generally accepted industry practices.

In addition to the planned and proposed procurement activities, MCE also takes into consideration the various barriers that may impact the success of its planned renewable projects. Some of the potential barriers for each of the new resources identified in MCE’s PCP include:

1. New Wind: The current market conditions have made new in-state wind resources scarce, which has led to a price premium and escalated cost risks on any available in-state wind resources. In addition, the transmission constraints and limited MIC allocation for out of state wind has made it difficult to negotiate and plan for new resources due to the uncertainty of deliverability.

2. New Geothermal: Due to the scarcity of new geothermal projects in-state and the uncertainty of deliverability and transmission of out of state geothermal projects, there has been an unprecedented competition on available geothermal, causing an ever-increasing upwards pressure in price. If this trend continues it may impact MCE’s ability 54 to procure new geothermal resources in the near-term.

3. Hybrid Resources: Currently, most hybrid resources primarily consist of intermittent resources like solar. As solar is highly affected by global supply chain issues, most planned projects are facing upward pressures in cost and are consequently facing further delays.

4. Storage: Similarly, to hybrid resources, global supply chain issues and the scarcity of the raw materials required for battery production, there is risk and uncertainty in prices and expected delivery dates that may negatively impact MCE’s planned portfolio and budgeted costs.

MCE continuously monitors the developments in the market and engages with various market stakeholders including the Commission, CAISO, and other CCAs, to strategize and find solutions to the various barriers and the risks associated with new clean energy procurement.

Throughout the planning period MCE will continue to proactively evaluate its planned procurement and make necessary adjustments to meet its portfolio needs as determined by MCE’s Board and its operational and compliance needs.
i. Resources to meet D.19-11-016 procurement requirements In D.19-11-016, the Commission ordered LSEs to collectively procure a total of 3,300 MW of incremental system capacity by 2023, with specific procurement obligations allocated to each LSE. As part of MCE’s contribution to system reliability and renewable integration needs, MCE is committed to self-providing its share of the identified system capacity need.38 MCE’s assigned share is 87.5 MW,39 50% of which was online by August 1, 2021, 75% of which was online by August 1, 2022, and 100% of which is expected to be online by August 1, 2023.

D.19-11-016 Procurement Progress Report
MCE has executed agreements that will satisfy MCE’s 2021, 2022 and 2023 incremental capacity requirements under D.19-11-016. As of the date of this filing, MCE has 108.77 MW40 of 38 Marin Clean Energy’s February 15, 2020, Integrated Procurement Planning Progress Report Pursuant to Decision 19-11-016 Adopted in Rulemaking 16-02-007 filed February 18, 2020. 39D.19-11-016 at Ordering Paragraph 3.
40 For consistency purposes, MCE is calculating September NQC based on the most recent ELCC factors adopted in D.22-08-039 and the September NQC assigned to MCE’s resources in the RDTs. However, using the more conservative NQC values, MCE has 101.9 MW of NQC either online or under contract to meet its D.19-11-016 requirement. This capacity includes a recently executed agreement for incremental capacity. However, due to the Commission’s August 1, 2022, cutoff for contracts, MCE includes this contact in its RDTs as a resource under review (see unique_contracts tab of the RDT Row 115) but includes this capacity in this progress report to provide the Commission the most up-to-date information on its D.19-11-016 procurement. MCE will reflect this resource as in 55 September NQC under contract; this is NQC not included on the baseline resource list adopted in Rulemaking 16-02-00741 and exceeds MCE’s 87.5 MW incremental capacity requirement. The projects reflected in these contracts are either already online or expected to be online in advance of August 1, 2023.

MCE also provides a narrative description of specific incremental procurement efforts below, which is consistent with the information MCE provides the CPUC in its bi-annual D.19-11-016 compliance filings.

Sutter Energy Center
The Sutter Energy Center project has been online since January 1, 2021 under a 3-year Purchase & Sale Agreement between MCE and Calpine Energy Services, L.P.. The period for this agreement began on January 1, 2021 and will continue through December 31, 2023, which is consistent with D.19-11-016’s requirement that commitments based on existing resources must “stay in place at least through the end of the resource adequacy summer months of 2023.”42 Additionally, D.19-11-016 defines the Sutter Energy Center as an incremental capacity resource.43 Although physically located outside of the CAISO balancing authority, D.19-11-016 also indicates that Sutter Energy Center is not an import for purposes of the capacity procurement ordered by the decision and thus not subject to the D.19-11-016’s 20% limitation on import resources.44
Sutter Energy Center adds 69.55 MW of incremental capacity to the system from January 2021 through 2023. As such, this project satisfied both MCE’s 2021 and 2022 requirements.

The Sutter Energy Center is represented in both the 30MMT and 25MMT RDTs, respectively, as incremental capacity. For this resource, please refer to row 59 of the unique_contracts tab in MCE’s RDTs.

Strauss Wind, LCC
In 2018 MCE executed an Amended and Restated Renewable Power Purchase Agreement with Development in its next D.19-11-016 RDT compliance filing. Under either NQC methodology, MCE has more than its share of incremental capacity under contract for purposes of D.19-11-016. 41 See Administrative Law Judge’s Ruling Finalizing Baseline for Purposes of Procurement Required by Decision 19-11-016 filed January 3, 2020, Rulemaking 16-02-007. 42D.19-11-016 at 47.
43D.19-11-016 at Ordering Paragraph 6.
44 Id.

58 Long-Duration Storage (MCE Requirement = 29 MW of NQC)

Zero Emissions Generation (MCE Requirement = 274 MW of NQC) ● Golden Fields Solar IV
MCE executed a contract with Clearway Energy Group on February 4, 2022, for a new-build hybrid project located in Kern County that pairs 100 MW of solar PV with 92 MW four-hour battery storage. This project has an expected COD of March 2025, and MCE expects to apply this resource to count for at least 75 MW of NQC towards its general MTR requirements under D.21-06-035, including towards MCE’s 72 MW of zero-emitting resources pursuant to Table 6 in D.21-06-035.48 The Golden Fields Solar project is represented in both the 30 MMT and 25 MMT RDTs, respectively, as incremental capacity. Please refer to row 51 of the unique_contracts tab in MCE’s RDTs. ● Daggett Solar Power 3, LLC
MCE executed a contract with Clearway Energy Group on September 25, 2020, for a new-build hybrid project in San Bernardino County that pairs 110 MW of solar PV with 60 MW four-hour battery storage. This project has an expected COD of August 2023, and MCE expects to apply this resource to count for at least 65.9 MW of NQC towards its MTR requirements under D.21-06-035, which also contributes towards MCE’s 72 MW 48 MCE expects this resource to provide at least 61.3 MW of DCPP replacement capacity. To apply towards both the general MTR requirements and MCE’s requirement to procure 72 MW of zero-emitting resources with certain availability requirements, MCE’s PPA for this project ensures that this hybrid resource will be designed to be capable of delivering 5 MWh of energy per every MW of claimed incremental capacity during the 5PM to 10PM period, daily.
59 of zero-emitting resources pursuant to Table 6 in D.21-06-035.49 The Daggett Solar Power project is represented in both the 30MMT and 25MMT RDTs, respectively, as incremental capacity. Please refer to row 55 of the unique_contracts tab in MCE’s RDTs. ● Hecate Grid Humidor Storage
MCE executed a contract with Hecate Grid in August 2022 for a new 185 MW four-hour battery storage project in Los Angeles County. This project has an expected COD of April 2023, and MCE expects to apply this resource to count for at least 167.8 MW of NQC towards its MTR requirements under D.21-06-035. The Hecate Grid Humidor Storage project is represented in both the 30 MMT and 25 MMT RDTs, respectively, as incremental capacity. Please refer to row 64 of the unique_contracts tab in MCE’s RDTs. i. All other procurement requirements
Open Season RFO
After counting the above-mentioned resources
To fill any current and future open positions, MCE issues annual open season RFOs, which seek to fill approximately 350 GWh of annual energy needs, including any incremental procurement that might be needed to meet D.21-06-035. These RFOs request offers for Portfolio Content Category 1 Renewable Energy and stand-alone, front-of-the-meter energy storage. MCE is in the final stages of completing power purchase agreements with selected respondents from 2021 RFO and expects to procure significant volumes of hybrid resources, all of which will be agreements of at least 10 years in duration. In addition, MCE expects to count these 2021 and future RFOs projects towards any future Commission-directed incremental capacity obligations. While MCE does not anticipate that the new projects will be needed for MCE’s share of capacity requirements identified in D.21-06-035, they may provide back up to the projects identified above.

Because these resources are expected/planned, and not currently contracted for, these resources are reflected as “review,” “PlannedExisting,” and “PlannedNew”resources in both the 30 MMT and 25 MMT Resource Data Templates.
49 MCE expects this resource to provide at least 48 MW of DCPP replacement capacity. To apply towards both the general MTR requirements and MCE’s requirement to procure 72 MW of zero-emitting resources with certain availability requirements, this hybrid resource is capable of delivering 5 MWh of energy per every MW of claimed incremental capacity during the 5PM to 10PM period, daily. 60 ii. Offshore wind
MCEs PCP includes 95 MW of offshore wind, assumed to be located at Morro Bay, with deliveries commencing in 2033. MCE has not yet seen any proposed opportunities to contract for offshore wind and is basing its planning assumption on the significant potential indicated in the PSP. Offshore wind appears to be a high potential resource with relatively high-capacity factors and resource adequacy values. At this time, costs of offshore wind development are largely uncertain. As such, costs of offshore wind development and maintenance infrastructure pose the greatest risk to utilization of this resource. However, the completion of environmental impact review and filing a proposed sale notice for the Humboldt Wind Energy Area by the federal Bureau of Ocean Energy Management (“BOEM”) is an important initial step. MCE will continue to monitor the developments and will engage the various stakeholders involved, should an opportunity to purchase offshore wind arise.
iii. Out-of-state wind
MCE’s PCP includes 70 MW of planned new, out-of-state wind (“OOS”), with deliveries commencing in 2030. MCE has reviewed wind projects that have been offered in recent solicitations and understands that the transmission projects needed to connect OOS Wind to the CAISO grid require significant lead-times. OOS wind opportunities rely on existing firm transmission routes into the CAISO or construction of new transmission with the appropriate level of import allocations and deliverability assurances for California LSEs. Absence of such assurances make it difficult for MCE to realize the significant potential for wind located in Idaho, Wyoming, and New Mexico. Given the fact that OOS Wind is not needed until 2030, MCE believes that a careful and considered approach to potential OOS Wind projects is best. MCE will continue to monitor for opportunities to purchase such resources and will evaluate offers it receives during its annual open season process.
iv. Other renewable energy not described above

v. Other energy storage not described above
MCE is not actively planning for any additional energy storage investments beyond what is described above.
61 vi. Other demand response not described above
In April 2021, MCE launched the Peak FLEXmarket, a first-of-its-kind program platform aimed at shifting energy use in its service area away from times of extreme demand. Following its initial pilot year, the program received $11 million in ratepayer funding from the CPUC for the summers of 2022 and 2023. Created in partnership with Recurve, the Peak FLEXmarket provides tools to measure hourly reductions in energy use that allows MCE to compensate businesses working locally with customers for energy savings during peak demand hours. The program is technology agnostic and incentivizes load reductions from a diverse group of technologies including batteries, managed EV charging, controls systems and behavioral/operational change. The Peak FLEXmarket incentivizes regular load shifting and also calls demand response events during periods of extreme grid stress. The Peak FLEXmarket has been included in MCE’s Energy Efficiency Business Plan Application for continued funding for the 2024-2027 timeframe.

MCE plans to expand this program to monitor and control other customer owned DERs.

In addition to the City of Richmond VPP described above, MCE continues to explore opportunities for demand response in its service area while facilitating third-party demand response programs. MCE customers are eligible for many of the demand response programs administered by PG&E, and MCE receives allocations from PG&E-administered programs.

Depending on the results of this analysis, MCE may launch new programs and possibly seek funding from other sources for more robust programs in this sector. vii. Other energy efficiency not described above
MCE is an administrator of California’s ratepayer-funded, energy efficiency programs alongside IOUs and Regional Energy Networks. Ratepayer funding is derived through collection of the Public Purpose Program charge from all electric service customers and is administered by the Commission. MCE has received Commission funding approval for energy efficiency programs to be administered through 2025 and currently administers programs in multifamily, single family, commercial, agriculture, and industrial sectors. Furthermore, MCE administers the Low-Income Families and Tenants (“LIFT”) Program, which serves income-qualified, multifamily properties and includes a fuel-switching component to incentivize property owners to replace gas-fired space and water heaters. The forecasted cumulative savings of MCE-administered energy efficiency programs are based on average life cycle savings. 62 MCE also invests in multiple workforce development initiatives to encourage the growth of green jobs through the approval of its Energy Efficiency Business Plan. MCE also coordinates closely with PG&E to maximize community benefits.

MCE cumulative energy efficiency impacts (GWh)
viii.Other distributed generation not described above
Net Energy Metering and Rooftop Solar Rebates
Through its Net Energy Metering (“NEM”) program, MCE supports customer-sited distributed generation within its service area by offering above-market incentives including automatic cash-outs for surplus generation each year at twice the wholesale rate (up to $5,000). MCE’s NEM Program currently includes more than 63,528 customers (10.9% of all MCE accounts) with an aggregate-installed renewable generating capacity of approximately 642 MW.

Through 2021, MCE incentivized local rooftop solar development for low-income customers.

MCE has a long-standing partnership with California’s Single Family Affordable Solar Housing (“SASH”) program administrator, GRID Alternatives. By leveraging multiple sources of funding, GRID Alternatives installs these systems in disadvantaged communities at little to no cost for the customer. MCE contributed $900 per solar installation to qualifying low-income, single-family homeowners. MCE also offered a $0.41 per watt (AC) rebate to low-income, multifamily properties that install solar to benefit their tenants.

From 2012–2021, MCE allocated $725,000 toward these two rebate programs, and supported the installation of 688 residential solar PV systems on low-income multifamily homes. These 63 installations represent more than 1,400 kW of new, local, renewable capacity that helps reduce monthly energy bills for low-income families.
ix. Transportation electrification, including any investments above and beyond what is included in Integrated Energy Policy Report (IEPR) As part of its broader strategy to reduce GHG emissions through buildings and transportation electrification, MCE has been working on several EV-related initiatives since 2017. These include demand response-enabled charging devices, equity-centered incentives for EVs, and funding for charging stations. These efforts started with a strategic plan and infrastructure analysis in partnership with the U.S. Environmental Protection Agency to analyze local EV market trends and their impact on MCE’s customer demand.

MCE has identified workplace EV charging as an opportunity to shift the demand of the 60,200 (and growing) EV drivers in its service area to hours of the day when energy is frequently cheaper and cleaner. MCE Solar Charge, a public EV charging station that opened in 2019 at MCE’s San Rafael office, demonstrates that vision to MCE’s staff and customers. In 2021, MCE launched MCE Sync, a residential smart charging pilot with the goal of reducing the peak load impacts of home charging while saving customers money and reducing GHG impacts.

MCE Sync uses an app to manage home vehicle charging. During a 6-month pilot with 232 enrolled participants, the pilot shifted 93% of EV electricity usage away from the 4–9 p.m. peak, reduced carbon intensity by 55% on average, and saved customers on an EV rate around $12/month before event-based incentives. The expanded program has a goal of 2,500 enrolled customers by May 2023.

Since 2018, MCE has supported or funded 1,570 Level 2 EV charging ports for workplaces or multifamily properties. More than 930 ports have been installed — equivalent to 36% of all public Level 2 charging ports in the four counties that MCE serves — and more than 645 ports under planning and in construction. MCE is coordinating with PG&E on its EV Charge Network program and providing a supplemental rebate to customers who participate in that program.

More than 71% of the MCE stations already deployed are enrolled in MCE’s Deep Green service.

In addition to incentives for EV charging stations, MCE provides free technical assistance and helps coordinate with other funding sources for commercial and multifamily customers interested in EV charging infrastructure. A CEC grant won by Contra Costa Transportation Authority and MCE will increase EV engagement, access to electric transportation, and deployment of charging infrastructure, especially at multifamily properties, across marginalized communities in the county from summer 2021 to spring 2024. 64 MCE also partnered with Bay Area Air Quality Management District and GRID Alternatives to win grants from the CEC and Marin Community Foundation. These grants are anticipated to start in the second half of 2022. Implementation will focus on deepening relationships with local housing authorities, affordable housing administrators, owners, and property managers to increase awareness and adoption of tenant-based EV charging stations. The implementation consists of installing EV charging and providing concierge education on how to qualify for income-based EV incentives, including MCE’s own EV rebate.

Lastly, MCE built upon its rebate program for income-qualified customers interested in purchasing a new EV with the goal of increasing understanding of and access to EVs beyond the typical early adopters. This program has helped over 261 customers purchase or lease a new EV and will expand in fiscal year 2023/2024 to include used EVs as well. x. Building electrification, including any investments above and beyond what is included in Integrated Energy Policy Report (IEPR)
MCE is committed to electrifying its service area and is currently offering several programs that it expects will impact building electrification efforts including its: LIFT Pilot Program, Multifamily Energy Savings (“MFES”) Program, Home energy Savings (“HES”) Program, and Heat Pump Water Heater (“HPWH”) Contractor Incentive Program. An overview of MCE’s planned investment in these programs is provided below.

Multifamily Energy Saving Program
MCE’s MFES provides residential energy efficiency50 and electrification51 improvements to affordable multifamily properties in the MCE service area. The intent of the program is to support vulnerable communities, particularly those who have been traditionally underserved.

MFES seeks to substantially fund energy efficiency and electrification measures for deed-restricted properties. It will also continue to co-leverage as many funding opportunities to provide comprehensive, whole building upgrades.

MFES was designed to co-leverage with MCE’s LIFT pilot program, authorized in D.16-11-022, by providing funding to affordable properties where not all units qualify for LIFT incentives. LIFT provides comprehensive services and supports fuel switching from natural gas to electric heat pumps for cleaner and safer energy use. Income-qualified multifamily properties can layer 50 Refrigerators, package terminal heat pumps, LED light fixtures, smart thermostats, low flows showerhead and aerators, and LED bulbs, T24 compliant windows, crawlspace, wall, and roof insulation. 51 Domestic hot water heat pump, space heating and cooling and electrical upgrades. 65 incentives from LIFT on MFES program rebates. With this model, MFES supports property-wide upgrades for all tenants who live in affordable housing.

MFES services include no-cost property assessments, project scope development, and program assistance throughout the project lifetime. The program also offers owner rebates for energy efficiency and electrification measures as well as no-cost direct installation of certain energy efficiency measures.

The program addresses market barriers by providing: (1) customized technical assistance to; overcome challenges associated with the diversity of building types, ownership types, and billing configurations, and to provide assistance with analyzing potential upgrade measures; (2) guidance through the initial assessment of multiple measure upgrade opportunities throughout the property; (3) a range of participation options to best meet the current needs and abilities of properties; and (4) a bridge for the funding gap between multifamily units that qualify for LIFT or ESA incentives and the rest of the property to promote a comprehensive and equitable whole-building upgrade.

The current budget for the MFES program is $1,017,476 for 2022 and $971,459 for 2023. The current timeline for the program is 2022-2024, with project renewal expected every two years.

LIFT Pilot Program
MCE launched the LIFT pilot in 2017, providing additional incentives for property owners and tenants in multifamily buildings (5+ units) beyond what is available through the MFES program.

LIFT provides $1,200 per unit for energy efficiency upgrades52 and additional incentives for fuel substitution and fuel switching away from natural gas and propane combustion appliances to high efficiency electric heat pumps53 (HVAC and water heating). This transition will support cleaner and more efficient energy use while resolving health and safety concerns.

MCE’s LIFT program aims to support income-eligible multifamily renters with improving their household efficiency, reducing their energy costs, and increasing home safety and comfort, while simultaneously maximizing benefits to owners. The program is part of a larger goal of California’s climate initiatives to support disadvantaged customers and increase statewide electrification and efficiency efforts. The literature review outlines the current regulatory 52 Refrigerators, package terminal heat pumps, LED light fixtures, smart thermostats, low flows showerhead and aerators, and LED bulbs, T24 compliant windows, crawlspace, wall, and roof insulation. 53 Domestic hot water heat pump, space heating and cooling and electrical upgrades. 66 context within California, discusses DAC definitions and metrics, electrification, health and safety, costs, and barriers to emerging technology adoption.

The LIFT pilot was originally approved by the CPUC to run under the Energy Savings Assistance (“ESA”) program, followed by a series of extensions granted to keep this running as a pilot through 2023. The LIFT Program distributed over $1 million in incentives to 680 qualifying households between 2018 and 2021 and successfully reached underserved customers with 95% of participants residing outside of a DAC. Participants collectively saved over 7,800 kilowatt-hours annually and, individually, an average of $192 per year on their electricity bill.

MCE expects to serve more than 450 additional households in the LIFT program through 2023.

MCE’s MFES and LIFT programs have different funding sources (CPUC – Energy Efficiency and CPUC – Energy Savings Assistance, respectively), which makes it possible for MF properties to leverage incentives from both programs. The two programs share the same implementor, providing a single point of contact (“SPOC”) and stack incentives for low-income multifamily customers. The rebates, when combined with MCE’s Multifamily Energy Savings program, cover up to 80% of total project costs. The program currently has a timeline of October 2017 – December 2023 with a budget of $6.75 million.

Home Energy Savings (“HES”) Program
MCE’s Single-Family Direct Install program, or Home Energy Savings Program (“HES”), provides no-cost energy efficiency measures to eligible homeowners and tenants in single-family homes (up to 4 attached units) and dwellings in MCE’s service area. This program targets moderate-income customers whose household income falls between 200% and 400% of the Federal Poverty Guidelines (“FPG”). The target group’s income exceeds the limit to receive services through programs like PG&E’s Energy Savings Assistance (“ESA”) program and MCE’s LIFT Program, yet who are still too income constrained (lower middle-income) to participate in market rate programs. MCE will refer customers who fall outside of the moderate-income threshold to available low-income and market rate programs. MCE’s goal is to fill the service gap and introduce this market sector to the concepts of energy efficiency, while providing energy upgrades and emerging technologies that reduce household energy consumption.

Energy efficiency measures offered under this program include: energy and water savings kits, energy advisor provided home assessments and envelope, heating, ventilation and cooling (HVAC) and electrification home upgrade measures.

The current budget for the HES program is $2,366,392 for 2022 and $2,384,874 for 2023. The current timeline for the program is 2022-2024, with project renewal every two years. 67 Heat Pump Water Heater (“HPWH”) Contractor Incentive Program BayREN has partnered with MCE, East Bay Community Energy, Silicon Valley Power, City of Santa Clara, and CleanPower SF to offer a standardized midstream electrification program serving multiple Bay Area counties. The program seeks to develop the electrification market by providing Bay Area residential contractors incentives for the installation of HPWHs.

The program offers a $1,000 incentive — paid directly to licensed contractors who replace homeowners’ natural gas or propane residential water heaters with high efficiency heat pump water heaters. Contractors enrolled in the BayREN Home+ program may participate in both programs and rebates are stackable. This program is self-funded by MCE and has a budget of $300,000 to install 250 HPWHs in MCE’s service area.

The HPWH Contractor Incentive Program has also created a resource of all electrification programs serving the Bay Area and has developed HPWH resources54 to help contractors and homeowners understand the benefits of this technology. MCE has contributed to a memo sharing learnings from the first year of the program, including contractor barriers to participation.55
xi. Other
MCE has no additional information in response to this sub-section xi. b. Disadvantaged Communities
In total, MCE serves 54,897 customer accounts located within DACs. This represents approximately 9.5% of MCE’s total customer accounts (approximately 580,000).

MCE is dedicated to reducing pollution impacts and encouraging the development, health, and prosperity of DAC within and outside our service area. In addition to the measures and programs described above, MCE’s commitment is reflected in the practices, programs, and policies described below.

Green Access and Community Solar Connection Programs
As described in Section d.ii., above, MCE is collaborating with the CPUC, IOUs, and other CCAs to develop community solar programs for customers in DACs. These programs will be supported 54 https://www.bayren.org/contractors/heat-pump-water-heater-hpwh-incentive-participating-contractors. 55 https://www.bayren.org/sites/default/files/2022-02/hpwh learnings may 2021 bayren 1.pdf 68 by the development of an additional 5.92 MW of new, local, clean energy capacity.

Sustainable Workforce and Diversity Policy
As described in Section d.ii., above, in 2017, MCE’s Board approved a Sustainable Workforce and Diversity Policy56 to facilitate and encourage diversity and a sustainable workforce.

More recently, in 2022 MCE adopted Sustainable Workforce Guidelines57 to create a more detailed plan for implementing its Sustainable Workforce and Diversity Policy.

These efforts have resulted in significant local developments. To date, MCE has helped build almost 48 MW of new renewable projects in our service area. All local projects over 1 MW were built with union labor. Additionally, in 2021 MCE launched two new community solar programs, Community Solar Connection and Green Access. These programs offer qualifying customers living in a CalEnviroScreen-designated DAC access to 100% renewable energy and a 20% discount on their electricity bills for up to 20 years. Both programs will be supported by the development of additional new clean energy resources.

In developing its Compliance IRP, MCE carefully considered the impact of its resource procurement on DACs. MCE’s PCP minimizes the use of fossil-based resources and unspecified system power, reducing reliance on natural gas generators that have an impact on DACs. c. Commission Direction of Actions
MCE is not seeking any specific direction of actions from the Commission at this time. However, MCE notes that it is aware of the Commission’s recent Administrative Law Judge’s Ruling Seeking Comments on Staff Paper on Procurement Program and Potential Near-Term Actions to Encourage Additional Procurement (“ALJ Ruling”).58 MCE looks forward to exploring the options for a programmatic approach to procurement to meet the goals of the IRP process as outlined in the Staff Paper on Programmatic Approaches to Electricity Procurement included with the ALJ Ruling. Whichever programmatic approach the Commission ultimately adopts, it is critical for the Commission to ensure that any new program equitably reflects an LSE’s full contribution to 56 See MCE November 16, 2017, Board of Directors Meeting Packet, Agenda Item No. 7 Attachment A https://www.mcecleanenergy.org/wp-content/uploads/2020/05/MCE-Board-Meeting-Packet-November 2017.pdf 57 See https://www.mcecleanenergy.org/wp-content/uploads/2022/05/MCE-Sustainable-Workforce-Guidelines 05122022.pdf 58 Administrative Law Judge’s Ruling Seeking Comments on Staff Paper on Procurement Program and Potential Near-Term Actions to Encourage Additional Procurement, issued September 8, 2022. 69 system reliability and achievement of California’s environmental goals and allows for flexibility to accommodate continuously evolving grid needs.

V. Lessons Learned
MCE shares the Commission’s commitment to robust and comprehensive integrated resource planning. MCE also understands the procedural and substantive complexity that defines IRP development at the state agency level and that continues through to individual LSEs as they respond to and integrate statutory and regulatory requirements into their resource planning efforts. However, in addition to the statutory requirements articulated in 454.52(a)(1)(A) -(I), MCE’s resource planning process must also give deference to its Board of Directors, which is granted statutory authority to govern MCE’s procurement and approve MCE’s IRP under 454.52(b)(3) and 366.2(a)(5). To meet all of the aforementioned statutory objectives and requirements, it is critical for MCE and other similarly situated LSEs to expect and receive timely and clear guidance from the Commission and adequate time to incorporate this guidance into its planning process. Administrative Law Judge Fitch alluded to this in the July 15, 2022 Ruling in which Energy Division Staff was directed to provide “final versions of the CSP Calculators and RDT . . .” within a reasonable period of time following July 1, 2022.59 Despite this clear guidance, updated RDTs were provided to LSEs on Friday, September 30, 2022.60 MCE appreciates these updates and the diligent work being done by Energy Division Staff, but revised templates and revised guidance this late in the process, no matter how insignificant or helpful, are disruptive to and dismissive of LSEs’ internal processes and timelines, particularly in the case of CCAs where other law governs procedure and timelines that must be followed when requesting their Boards take action. MCE urges the Commission to take steps in the next IRP cycle to adhere firmly to its timelines and the direction in its own rulings. Diligence on this front will aid all stakeholders in meeting statutory requirements and comprehensively and thoroughly addressing the state’s resource planning efforts. 59 Load Forecast Ruling issued June 15, 2022, at 14.
60 Email from Ali Eshraghi to Commission-jurisdictional LSEs, Aggregated CAM Resources for LSEs [sic] Plan Development, sent September 30, 2022; LSEs were initially advised of this update on Friday, September 23, 2022, via an email from James McGarry to Commission-jurisdictional LSEs, Notice of IRP Template Update and Q&A document [sic], sent September 23, 2022.
70 Glossary of Terms
Alternative Portfolio: LSEs are permitted to submit “Alternative Portfolios” developed from scenarios using different assumptions from those used in the Preferred System Plan with updates. Any deviations from the “Conforming Portfolio” must be explained and justified.

Approve (Plan): the CPUC’s obligation to approve an LSE’s integrated resource plan derives from Public Utilities Code Section 454.52(b)(2) and the procurement planning process described in Public Utilities Code Section 454.5, in addition to the CPUC obligation to ensure safe and reliable service at just and reasonable rates under Public Utilities Code Section 451.

Balancing Authority Area (CAISO): the collection of generation, transmission, and loads within the metered boundaries of the Balancing Authority. The Balancing Authority maintains load-resource balance within this area.

Baseline resources: Those resources assumed to be fixed as a capacity expansion model input, as opposed to Candidate resources, which are selected by the model and are incremental to the Baseline.

Baseline resources are existing (already online) or owned or contracted to come online within the planning horizon. Existing resources with announced retirements are excluded from the Baseline for the applicable years. Being “contracted” refers to a resource holding signed contract/s with an LSE/s for much of its energy and capacity, as applicable, for a significant portion of its useful life. The contracts refer to those approved by the CPUC and/or the LSE’s governing board, as applicable. These criteria indicate the resource is relatively certain to come online. Baseline resources that are not online at the time of modeling may have a failure rate applied to their nameplate capacity to allow for the risk of them failing to come online.

Candidate resource: those resources, such as renewables, energy storage, natural gas generation, and demand response, available for selection in IRP capacity expansion modeling, incremental to the Baseline resources.

Capacity Expansion Model: a capacity expansion model is a computer model that simulates generation and transmission investment to meet forecast electric load over many years, usually with the objective of minimizing the total cost of owning and operating the electrical system. Capacity expansion models can also be configured to only allow solutions that meet specific requirements, such as providing a minimum amount of capacity to ensure the reliability of the system or maintaining greenhouse gas emissions below an established level.

Certify (a Community Choice Aggregator Plan): Public Utilities Code 454.52(b)(3) requires the CPUC to certify the integrated resource plans of CCAs. “Certify” requires a formal act of the Commission to determine that the CCA’s Plan complies with the requirements of the statute and the process established via Public Utilities Code 454.51(a). In addition, the Commission must review the CCA Plans to determine 71 any potential impacts on public utility bundled customers under Public Utilities Code Sections 451 and 454, among others.

Clean System Power (CSP) methodology: the methodology used to estimate GHG, and criteria pollutant emissions associated with an LSE’s Portfolio based on how the LSE will expect to rely on system power on an hourly basis.

Community Choice Aggregator: a governmental entity formed by a city or county to procure electricity for its residents, businesses, and municipal facilities.

Conforming Portfolio: the LSE portfolio that conforms to IRP Planning Standards, the 2030 LSE-specific GHG Emissions Benchmark, use of the LSE’s assigned load forecast, use of inputs and assumptions matching those used in developing the Reference System Portfolio, as well as other IRP requirements including the filing of a complete Narrative Template, a Resource Data Template and Clean System Power Calculator.

Effective Load Carrying Capacity: a percentage that expresses how well a resource is able avoid loss-of-load events (considering availability and use limitations). The percentage is relative to a reference resource, for example a resource that is always available with no use limitations. It is calculated via probabilistic reliability modeling and yields a single percentage value for a given resource or grouping of resources.

Effective Megawatts (MW): perfect capacity equivalent MW, such as the MW calculated by applying an ELCC % multiplier to nameplate MW.

Electric Service Provider: an entity that offers electric service to a retail or end-use customer, but which does not fall within the definition of an electrical corporation under Public Utilities Code Section 218.

Filing Entity: an entity required by statute to file an integrated resource plan with CPUC.

Future: a set of assumptions about future conditions, such as load or gas prices.

GHG Benchmark (or LSE-specific 2030 GHG Benchmark): the mass-based GHG emission planning targets calculated by staff for each LSE based on the methodology established by the California Air Resources Board and required for use in LSE Portfolio development in IRP.

GHG Planning Price: the systemwide marginal GHG abatement cost associated with achieving a specific electric sector 2030 GHG planning target.

Integrated Resources Planning Standards (Planning Standards): the set of CPUC IRP rules, guidelines, formulas, and metrics that LSEs must include in their LSE Plans.

Integrated Resource Planning (IRP) process: integrated resource planning process; the repeating cycle through which integrated resource plans are prepared, submitted, and reviewed by the CPUC 72 Long term: more than 5 years unless otherwise specified.

Load Serving Entity: an electrical corporation, electric service provider, community choice aggregator, or electric cooperative.

Load Serving Entity (LSE) Plan: an LSE’s integrated resource plan; the full set of documents and information submitted by an LSE to the CPUC as part of the IRP process.

Load Serving Entity (LSE) Portfolio: a set of supply- and/or demand-side resources with certain attributes that together serve the LSE’s assigned load over the IRP planning horizon.

Loss of Load Expectation (LOLE): a metric that quantifies the expected frequency of loss-of-load events per year. Loss-of-load is any instance where available generating capacity is insufficient to serve electric demand. If one or more instances of loss-of-load occurring within the same day regardless of duration are counted as one loss-of-load event, then the LOLE metric can be compared to a reference point such as the industry probabilistic reliability standard of “one expected day in 10 years,” i.e., a LOLE of 0.1.

Maximum Import Capability: a California ISO metric that represents a quantity in MWs of imports determined by the CAISO to be simultaneously deliverable to the aggregate of load in the ISO’s Balancing Authority (BAA) Area and thus eligible for use in the Resource Adequacy process. The California ISO assess a MIC MW value for each intertie into the ISO’s BAA and allocated yearly to the LSEs. A LSE’s RA import showings are limited to its share of the MIC at each intertie.

Net Qualifying Capacity (NQC): Qualifying Capacity reduced, as applicable, based on: (1) testing and verification; (2) application of performance criteria; and (3) deliverability restrictions. The Net Qualifying Capacity determination shall be made by the California ISO pursuant to the provisions of this California ISO Tariff and the applicable Business Practice Manual.

Non-modeled costs: embedded fixed costs in today’s energy system (e.g., existing distribution revenue requirement, existing transmission revenue requirement, and energy efficiency program cost).

Nonstandard LSE Plan: type of integrated resource plan that an LSE may be eligible to file if it serves load outside the CAISO balancing authority area.

Optimization: an exercise undertaken in the CPUC’s Integrated Resource Planning (IRP) process using a capacity expansion model to identify a least-cost portfolio of electricity resources for meeting specific policy constraints, such as GHG reduction or RPS targets, while maintaining reliability given a set of assumptions about the future. Optimization in IRP considers resources assumed to be online over the planning horizon (baseline resources), some of which the model may choose not to retain, and additional resources (candidate resources) that the model is able to select to meet future grid needs.

Planned resource: any resource included in an LSE portfolio, whether already online or not, that is yet to be procured. Relating this to capacity expansion modeling terms, planned resources can be baseline 73 resources (needing contract renewal, or currently owned/contracted by another LSE), candidate resources, or possibly resources that were not considered by the modeling, e.g., due to the passage of time between the modeling taking place and LSEs developing their plans. Planned resources can be specific (e.g., with a CAISO ID) or generic, with only the type, size and some geographic information identified.

Qualifying capacity: the maximum amount of Resource Adequacy Benefits a generating facility could provide before an assessment of its net qualifying capacity.

Preferred Conforming Portfolio: the conforming portfolio preferred by an LSE as the most suitable to its own needs; submitted to CPUC for review as one element of the LSE’s overall IRP plan.

Preferred System Plan: The Commission’s integrated resource plan composed of both the aggregation of LSE portfolios (i.e., Preferred System Portfolio) and the set of actions necessary to implement that portfolio (i.e., Preferred System Action Plan).

Preferred System Portfolio: the combined portfolios of individual LSEs within the CAISO, aggregated, reviewed, and possibly modified by Commission staff as a proposal to the Commission, and adopted by the Commission as most responsive to statutory requirements per Pub. Util. Code 454.51; part of the Preferred System Plan.

Short term: 1 to 3 years (unless otherwise specified).

Staff: CPUC Energy Division staff (unless otherwise specified).

Standard LSE Plan: type of integrated resource plan that an LSE is required to file if it serves load within the CAISO balancing authority area (unless the LSE demonstrates exemption from the IRP process).

Transmission Planning Process (TPP): annual process conducted by the California Independent System Operator (CAISO) to identify potential transmission system limitations and areas that need reinforcements over a 10-year horizon.

ATTACHMENT B
un que_cont acts
lse_unique_contract_id resource alternative_resource_name contract_status project_interconnection_position interconnection_substat on marginal_addition marginal_add tion_to total_nameplate_capacity contracted_nameplate_capacity sep_contracted_mw_nqc contract_gwh_annual s_hybrid_paired can_charge_from_grid Ost om_MCE WHEATL_6_LNDFIL Onl ne NA NA NA 2 2 12 NotHyb d Hay MCE PEABDY 2 LNDF L Onl ne NA NA NA 2 2 11 NotHyb d Geyse s MCE GEYS13 7 UNIT13 Onl ne NA NA NA 10 10 88 NotHyb d L ncoln MCE PLSNTG 7 LNCLND Onl ne NA NA NA 5 4 27 NotHyb d Voyage II MCE VOYAGR 2 VOYWD3 Onl ne NA NA NA 5 138 NotHyb d WM_MCE NOVATO_6_LNDFL Onl ne NA NA NA 4 3 30 NotHyb d
Antelope 2 MCE BGSKYN 2 AS2SR1 Onl ne NA NA NA 105 12 289 NotHyb d Cooley I MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d Cost Plus_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 1 NotHyb d Dese t Ha vest MCE DSRTHV 2 DH1SR1 Onl ne NA NA NA 80 9 252 NotHyb d F eethy 1 MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d F eethy 2_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d G eat Valley MCE TRNQL8 2 ROJSR1 Onl ne NA NA NA 100 11 285 NotHyb d L ttle Bea 1 MCE LTBERA 1 LB1SR1 Onl ne NA NA NA 40 4 105 NotHyb d L ttle Bea 3 MCE LTBEAR 1 LB3SR3 Onl ne NA NA NA 20 2 52 NotHyb d L ttle Bea 4 MCE LTBEAR 1 LB4SR4 Onl ne NA NA NA 50 6 132 NotHyb d L ttle Bea 5_MCE LTBEAR_1_LB4SR5 Onl ne NA NA NA 50 6 132 NotHyb d SR A po t MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d Mustang MCE MSTANG 2 SOLAR4 Onl ne NA NA NA 30 3 82 NotHyb d Soscal Fe y Sola C_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d Soscal Fe y Sola D MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d Ame can Canyon Sola A MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d Ame can Canyon Sola B_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d Ame can Canyon Sola C MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d S lve a Ranch A MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d S lve a Ranch B_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d SR A po t 2 MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d EO P oducts MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 1 NotHyb d Oakley RV & Boat Sto age MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d DRES Qua y 2.4 MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 0 0 0 1 NotHyb d Co co an_MCE CORCAN_1_SOLAR2 Onl ne NA NA NA 11 1 27 NotHyb d Goose Lake MCE GOOSLK 1 SOLAR1 Onl ne NA NA NA 12 1 30 NotHyb d Buck MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d MCE Sola 1_8.5_MCE R CHMN_1_CHVSR2 Onl ne NA NA NA 9 1 17 NotHyb d MCE Sola 1 2.0 MCE R CHMN 1 SOLAR Onl ne NA NA NA 2 0 4 NotHyb d Ke n Tule PCC1 1 LT MCE KRNCNY 6 UNIT Onl ne NA NA NA 11 5 37 NotHyb d S lve a Ranch C_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d Lake He man PCC1 1 LT MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 5 5 0 13 NotHyb d By on Sola PCC1 1 LT MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 3 3 0 8 NotHyb d St auss PCC1 1 LT MCE STRAUSSWIND Development WDT-1320 NA NA NA NotHyb d By on Sola PCC1 2 LT MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d Haywo th_PCC1_1_LT_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d Fallon PCC1 1 LT MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d RPCA PCC1 1 LT MCE NEW GENERIC SOLAR FIXED Development B entwood 2105 NA NA 5 5 0 13 NotHyb d Napa_PCC1_1_LT_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 1 NotHyb d CMSA PCC1 2 LT MCE EX STING GENER C BIOMASS/WOOD Onl ne NA NA NA 1 1 0 3 NotHyb d EBCE PCC1 Sale 1 MCE GOOSLK 1 SOLAR1 Onl ne NA NA NA 0 8 NotHyb d SJCE_PCC1_Sale_1_MCE CORCAN_1_SOLAR2 Onl ne NA NA NA 0 4 NotHyb d PCEA PCC1 Sale 1 MCE GOOSLK 1 SOLAR1 Onl ne NA NA NA 0 10 NotHyb d Golden F elds PCC1 LT MCE NEW GENERIC SOLAR 1AXIS Development Q-1212 NA NA NA 100 100 103 272 NewSola NewSto age NO Ranch Se eno_PCC1_LT_MCE _NEW_GENERIC_SOLAR_1AXIS Development WDT-2597 NA NA NA 2 2 1 5 NewSola NewSto age NO CES Elect on Fa m PCC1 DAC 1 LT MCE NEW GENERIC SOLAR 1AXIS Development NA NA 0 0 0 1 NotHyb d CES Elect on Fa m PCC1 DAC 2 LT MCE NEW GENERIC SOLAR 1AXIS Development NA NA 4 4 0 12 NotHyb d Daggett PCC1 1 LT MCE NEW GENERIC SOLAR 1AXIS Development Q-1314 NA NA NA 110 110 66 317 NewSola NewSto age NO Ma sh Land ng LLC RA 1 BAF MCE COCOPP 2 CTG4 Onl ne NA NA NA 81 77 0 NotHyb d WELLHEAD_RA_3_POF_MCE AGRICO_7_UNIT Onl ne NA NA NA 50 48 0 NotHyb d CALPINE RA 35 S F MCE BOGUE 1 UNITA1 Onl ne NA NA NA 32 32 0 NotHyb d CALPINE RA 34 NS MCE SUTTER 2 CISO Onl ne NA NA NA 70 70 0 NotHyb d CALPINE_RA_44_NS_MCE _EXISTING_GENERIC_COMBINED_CYCLE Onl ne NA NA NA 25 25 0 NotHyb d CALPINE RA 67 NS MCE EXISTING GENERIC COMBINED CYCLE Onl ne NA NA NA 15 15 0 NotHyb d CALPINE RA 68 NSF MCE EXISTING GENERIC COMBINED CYCLE Onl ne NA NA NA 15 15 0 NotHyb d ENERSPONSE_RA_2_SS_MCE _EXISTING_GENER C_DR Onl ne NA NA NA 20 20 20 0 NotHyb d Hecate Sto age RA 2024 NEW GENERIC BATTERY STORAGE Development 185 185 185 0 NotHyb d EBMUD B1 MCE CAMCHE 1 PL1X3 Onl ne NA NA NA 10 0 46 NotHyb d EBMUD B1 MCE PARDEB 6 UNITS Onl ne NA NA NA 30 0 140 NotHyb d SENA CF 13 MCE EX STING GENERIC INSTATE LARGE HYDRO Onl ne NA NA NA 0 200 NotHyb d MSCG_CF_5_MCE _EX STING_GENERIC_NW_HYDRO Onl ne NA NA NA 0 400 NotHyb d B ookf eld CF 4 MCE EX STING GENERIC NW HYDRO Onl ne NA NA NA 0 200 NotHyb d TENASKA CF 2 MCE EXCHEC 7 UNIT 1 Onl ne NA NA NA 95 0 120 NotHyb d POWEREX_CF_3_MCE _EX STING_GENERIC_NW_HYDRO Onl ne NA NA NA 0 250 NotHyb d Powe ex CF 4 MCE EX STING GENERIC NW HYDRO Onl ne NA NA NA 0 206 NotHyb d Powe ex CF 5 MCE EX STING GENERIC NW HYDRO Onl ne NA NA NA 0 100 NotHyb d WAPA_BR_MCE EX STING_GENERIC_INSTATE_LARGE_HYDRO Onl ne NA NA NA 0 25 NotHyb d WAPA BR 2 MCE EX STING GENERIC INSTATE LARGE HYDRO Onl ne NA NA NA 0 25 NotHyb d GHG F ee A locat on EX STING GENERIC INSTATE LARGE HYDRO PlannedEx st ng 0 500 NotHyb d DR A locat on EXISTING GENER C DR Onl ne 19 0 NotHyb d
OS22 New W nd 2026 NEW GENER C WIND PlannedNew w nd ca so planned 100 100 22 263 NotHyb d Gene c LT W nd NM 2030 CREZ GENER C NEW MEX CO WIND PlannedNew w nd mpo t planned 70 70 20 250 NotHyb d Gene c LT W nd_2033 EZ_GENER C_MORRO_BAY_OFFSHORE_WIND PlannedNew w nd_ca so_planned 95 95 41 400 NotHyb d Gene c LT Geothe mal 2030 NEW GENERIC GEOTHERMAL PlannedNew geothe mal mpo t planned 75 75 70 580 NotHyb d MTR LDS 2026 NEW GENERIC BATTERY STORAGE PlannedNew batte y ca so planned 40 40 40 0 NotHyb d VAMO_ST_B omass _EX STING_GENER C_BIOMASS/WOOD Onl ne 0 33 NotHyb d VAMO ST Sola PV EXISTING GENER C SOLAR FIXED Onl ne 0 206 NotHyb d VAMO ST W nd EXISTING GENERIC WIND Onl ne 0 165 NotHyb d VAMO ST Small Hyd o EX STING GENERIC INSTATE SMALL HYDRO Onl ne 0 14 NotHyb d VAMO ST Geothe mal EX STING GENERIC GEOTHERMAL Onl ne 0 70 NotHyb d Gene c ST B omass _EX STING_GENER C_BIOMASS/WOOD PlannedEx st ng 0 20 NotHyb d Gene c ST Sola EXISTING GENER C SOLAR FIXED PlannedEx st ng 0 99 NotHyb d Gene c ST W nd EXISTING GENERIC WIND PlannedEx st ng 0 378 NotHyb d Gene c ST Small Hyd o EX STING_GENERIC_INSTATE_SMALL_HYDRO PlannedEx st ng 0 40 NotHyb d Gene c ST Geothe mal EX STING GENERIC GEOTHERMAL PlannedEx st ng 0 125 NotHyb d Gene c ST La ge Hyd o/ACS EX STING GENERIC NW HYDRO PlannedEx st ng 0 144 NotHyb d Gene c LDS_2030 _NEW_GENERIC_BATTERY_STORAGE PlannedNew batte y_ca so_planned 50 50 50 0 NotHyb d Gene c 4 Hou Sto age 2028 NEW GENERIC BATTERY STORAGE PlannedNew batte y ca so planned 200 200 200 0 NotHyb d Gene c 4 Hou Sto age 2034 NEW GENERIC BATTERY STORAGE PlannedNew batte y ca so planned 200 200 200 0 NotHyb d Gene c CCGT RA_2023 _EXISTING_GENERIC_COMBINED_CYCLE PlannedEx st ng 750 750 750 0 NotHyb d Gene c CCGT RA 2024 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 686 686 686 0 NotHyb d Gene c CCGT RA 2025 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 639 639 639 0 NotHyb d Gene c CCGT RA 2026 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 731 731 731 0 NotHyb d Gene c CCGT RA 2027 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 672 672 672 0 NotHyb d Gene c CCGT RA_2028 _EXISTING_GENERIC_COMBINED_CYCLE PlannedEx st ng 498 498 498 0 NotHyb d Gene c CCGT RA 2029 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 535 535 535 0 NotHyb d Gene c CCGT RA 2030 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 425 425 425 0 NotHyb d Gene c CCGT RA_2031 _EXISTING_GENERIC_COMBINED_CYCLE PlannedEx st ng 518 518 518 0 NotHyb d Gene c CCGT RA 2032 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 542 542 542 0 NotHyb d Gene c CCGT RA 2033 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 530 530 530 0 NotHyb d Gene c CCGT RA_2034 _EXISTING_GENERIC_COMBINED_CYCLE PlannedEx st ng 541 541 541 0 NotHyb d Gene c CCGT RA 2035 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 549 549 549 0 NotHyb d RESI RA 2 NS MCE NEW GENERIC DR Rev ew d ca so planned 15 15 15 0 NotHyb d PGE Onl ne ccgt 1 EXISTING GENERIC COMBINED CYCLE Onl ne 44 44 0 NotHyb d PGE Onl ne ccgt 2 EXISTING GENERIC COMBINED CYCLE Onl ne 39 39 0 NotHyb d PGE_Onl ne_ccgt_3 _EXISTING_GENERIC_COMBINED_CYCLE Onl ne 61 61 0 NotHyb d PGE Onl ne chp EXISTING GENERIC COGEN Onl ne 4 4 0 NotHyb d PGE Onl ne chp 1 EXISTING GENERIC COGEN Onl ne 3 0 5 NotHyb d PGE_Onl ne_chp_2 _EXISTING_GENERIC_COGEN Onl ne 1 1 7 NotHyb d PGE Onl ne batte y EX STING GENER C BATTERY STORAGE Onl ne 23 23 0 NotHyb d PGE Development batte y 1 NEW GENERIC BATTERY STORAGE Development 6 5 0 NotHyb d PGE_Development_batte y_2 _NEW_GENERIC_BATTERY_STORAGE Development 0 0 0 NotHyb d Attachment B - 25 MMT RDT

un que_cont acts
lse_unique_contract_id
Ost om_MCE
Hay MCE
Geyse s MCE
L ncoln MCE
Voyage II MCE
WM_MCE
Antelope 2 MCE
Cooley I MCE
Cost Plus_MCE
Dese t Ha vest MCE
F eethy 1 MCE
F eethy 2_MCE
G eat Valley MCE
L ttle Bea 1 MCE
L ttle Bea 3 MCE
L ttle Bea 4 MCE
L ttle Bea 5_MCE
SR A po t MCE
Mustang MCE
Soscal Fe y Sola C_MCE
Soscal Fe y Sola D MCE
Ame can Canyon Sola A MCE
Ame can Canyon Sola B_MCE
Ame can Canyon Sola C MCE
S lve a Ranch A MCE
S lve a Ranch B_MCE
SR A po t 2 MCE
EO P oducts MCE
Oakley RV & Boat Sto age MCE
DRES Qua y 2.4 MCE
Co co an_MCE
Goose Lake MCE
Buck MCE
MCE Sola 1_8.5_MCE
MCE Sola 1 2.0 MCE
Ke n Tule PCC1 1 LT MCE
S lve a Ranch C_MCE
Lake He man PCC1 1 LT MCE
By on Sola PCC1 1 LT MCE
St auss PCC1 1 LT MCE
By on Sola PCC1 2 LT MCE
Haywo th_PCC1_1_LT_MCE
Fallon PCC1 1 LT MCE
RPCA PCC1 1 LT MCE
Napa_PCC1_1_LT_MCE
CMSA PCC1 2 LT MCE
EBCE PCC1 Sale 1 MCE
SJCE_PCC1_Sale_1_MCE
PCEA PCC1 Sale 1 MCE
Golden F elds PCC1 LT MCE
Ranch Se eno_PCC1_LT_MCE
CES Elect on Fa m PCC1 DAC 1 LT MCE
CES Elect on Fa m PCC1 DAC 2 LT MCE
Daggett PCC1 1 LT MCE
Ma sh Land ng LLC RA 1 BAF MCE
WELLHEAD_RA_3_POF_MCE
CALPINE RA 35 S F MCE
CALPINE RA 34 NS MCE
CALPINE_RA_44_NS_MCE
CALPINE RA 67 NS MCE
CALPINE RA 68 NSF MCE
ENERSPONSE_RA_2_SS_MCE
Hecate Sto age RA 2024
EBMUD B1 MCE
EBMUD B1 MCE
SENA CF 13 MCE
MSCG_CF_5_MCE
B ookf eld CF 4 MCE
TENASKA CF 2 MCE
POWEREX_CF_3_MCE
Powe ex CF 4 MCE
Powe ex CF 5 MCE
WAPA_BR_MCE
WAPA BR 2 MCE
GHG F ee A locat on
DR A locat on
Gene c LT W nd NM 2030
Gene c LT W nd_2033
Gene c LT Geothe mal 2030
MTR LDS 2026
VAMO_ST_B omass
VAMO ST Sola PV
VAMO ST W nd
VAMO ST Small Hyd o
VAMO ST Geothe mal
Gene c ST B omass
Gene c ST Sola
Gene c ST W nd
Gene c ST Small Hyd o
Gene c ST Geothe mal
Gene c ST La ge Hyd o/ACS
Gene c LDS_2030
Gene c 4 Hou Sto age 2028
Gene c 4 Hou Sto age 2034
Gene c CCGT RA_2023
Gene c CCGT RA 2024
Gene c CCGT RA 2025
Gene c CCGT RA 2026
Gene c CCGT RA 2027
Gene c CCGT RA_2028
Gene c CCGT RA 2029
Gene c CCGT RA 2030
Gene c CCGT RA_2031
Gene c CCGT RA 2032
Gene c CCGT RA 2033
Gene c CCGT RA_2034
Gene c CCGT RA 2035
RESI RA 2 NS MCE
PGE Onl ne ccgt 1
PGE Onl ne ccgt 2
PGE_Onl ne_ccgt_3
PGE Onl ne chp
PGE Onl ne chp 1
PGE_Onl ne_chp_2
PGE Onl ne batte y
PGE Development batte y 1
PGE_Development_batte y_2
total_generator_mw contracted_generator_mw total_storage_mw contracted_storage_mw solar_technology_sub_type storage_technology_sub_type total_storage_depth_mwh contracted_storage_depth_mwh viability_cod_reasonableness viabil ty_technical_feasibility viability_f nancing_sitecontrol resource_mix d1911016_vamo_ghgfree buy_sell_own 1Ax s
F xed
F xed
1Ax s
F xed
F xed
1Ax s
1Ax s
1Ax s
1Ax s
1Ax s
F xed
1Ax s
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
4 3 5
F xed
F xed
F xed
F xed 4 3 4
F xed
F xed Sell
F xed Sell
F xed Sell
100 100 92 92 1Ax s L 368 368 4 3 3
2 2 0 8 0 8 F xed L 3 2 3 2 4 3 3
F xed 4 3 3
F xed 4 3 3
110 110 60 60 1Ax s L 240 240 4 3 5
L 740 740 4 3 5
GHG f ee PCIA Buy
Buy
1 2 1
1 2 1
1 2 1
L 320 320 1 1 1
VAMO Buy
VAMO Buy
VAMO Buy
VAMO Buy
VAMO Buy
L 400 400 1 1 1
L 800 800 1 2 1
L 800 800 1 2 1
4 3 5
CAM
CAM
CAM
CAM
CAM
CAM
L 93 CAM
L 23 CAM
L 0 CAM
Attachment B - 25 MMT RDT

un que_cont acts
lse_unique_contract_id
Ost om_MCE
Hay MCE
Geyse s MCE
L ncoln MCE
Voyage II MCE
WM_MCE
Antelope 2 MCE
Cooley I MCE
Cost Plus_MCE
Dese t Ha vest MCE
F eethy 1 MCE
F eethy 2_MCE
G eat Valley MCE
L ttle Bea 1 MCE
L ttle Bea 3 MCE
L ttle Bea 4 MCE
L ttle Bea 5_MCE
SR A po t MCE
Mustang MCE
Soscal Fe y Sola C_MCE
Soscal Fe y Sola D MCE
Ame can Canyon Sola A MCE
Ame can Canyon Sola B_MCE
Ame can Canyon Sola C MCE
S lve a Ranch A MCE
S lve a Ranch B_MCE
SR A po t 2 MCE
EO P oducts MCE
Oakley RV & Boat Sto age MCE
DRES Qua y 2.4 MCE
Co co an_MCE
Goose Lake MCE
Buck MCE
MCE Sola 1_8.5_MCE
MCE Sola 1 2.0 MCE
Ke n Tule PCC1 1 LT MCE
S lve a Ranch C_MCE
Lake He man PCC1 1 LT MCE
By on Sola PCC1 1 LT MCE
St auss PCC1 1 LT MCE
By on Sola PCC1 2 LT MCE
Haywo th_PCC1_1_LT_MCE
Fallon PCC1 1 LT MCE
RPCA PCC1 1 LT MCE
Napa_PCC1_1_LT_MCE
CMSA PCC1 2 LT MCE
EBCE PCC1 Sale 1 MCE
SJCE_PCC1_Sale_1_MCE
PCEA PCC1 Sale 1 MCE
Golden F elds PCC1 LT MCE
Ranch Se eno_PCC1_LT_MCE
CES Elect on Fa m PCC1 DAC 1 LT MCE
CES Elect on Fa m PCC1 DAC 2 LT MCE
Daggett PCC1 1 LT MCE
Ma sh Land ng LLC RA 1 BAF MCE
WELLHEAD_RA_3_POF_MCE
CALPINE RA 35 S F MCE
CALPINE RA 34 NS MCE
CALPINE_RA_44_NS_MCE
CALPINE RA 67 NS MCE
CALPINE RA 68 NSF MCE
ENERSPONSE_RA_2_SS_MCE
Hecate Sto age RA 2024
EBMUD B1 MCE
EBMUD B1 MCE
SENA CF 13 MCE
MSCG_CF_5_MCE
B ookf eld CF 4 MCE
TENASKA CF 2 MCE
POWEREX_CF_3_MCE
Powe ex CF 4 MCE
Powe ex CF 5 MCE
WAPA_BR_MCE
WAPA BR 2 MCE
GHG F ee A locat on
DR A locat on
OS22 New W nd 2026
Gene c LT W nd NM 2030
Gene c LT W nd_2033
Gene c LT Geothe mal 2030
MTR LDS 2026
VAMO_ST_B omass
VAMO ST Sola PV
VAMO ST W nd
VAMO ST Small Hyd o
VAMO ST Geothe mal
Gene c ST B omass
Gene c ST Sola
Gene c ST W nd
Gene c ST Small Hyd o
Gene c ST Geothe mal
Gene c ST La ge Hyd o/ACS
Gene c LDS_2030
Gene c 4 Hou Sto age 2028
Gene c 4 Hou Sto age 2034
Gene c CCGT RA_2023
Gene c CCGT RA 2024
Gene c CCGT RA 2025
Gene c CCGT RA 2026
Gene c CCGT RA 2027
Gene c CCGT RA_2028
Gene c CCGT RA 2029
Gene c CCGT RA 2030
Gene c CCGT RA_2031
Gene c CCGT RA 2032
Gene c CCGT RA 2033
Gene c CCGT RA_2034
Gene c CCGT RA 2035
RESI RA 2 NS MCE
PGE Onl ne ccgt 1
PGE Onl ne ccgt 2
PGE_Onl ne_ccgt_3
PGE Onl ne chp
PGE Onl ne chp 1
PGE_Onl ne_chp_2
PGE Onl ne batte y
PGE Development batte y 1
PGE_Development_batte y_2
counterparty generator_supplier developer_name capacity_area capacity_sub_area cpuc_approval_ref county COD_year COD_month COD_day contract_start_date_year contract_start_date_month contract_start_date_day contract_end_date_year contract_end_date_month contract_end_date_day NA S e a YubaCounty 2013 7 1 2013 7 1 2031 6 30
NA PacGE SolanoCounty 2013 7 1 2013 7 1 2033 6 30
NA No thCoastNo thBay SonomaCounty 1980 1 1 2017 1 1 2026 12 31 NA S e a Place County 1985 1 1 2013 2 14 2033 2 13
NA SCE Ke nCounty 2018 12 29 2018 12 29 2030 12 28
NA No thCoastNo thBay No_sub_a ea Ma nCounty 2017 9 14 2017 9 14 2037 9 13 NA B gC eekVentu a LosAngelesCounty 2019 1 1 2019 1 1 2038 12 31 NA G eate Bay Ma nCounty 2017 7 5 2017 3 1 2037 2 28
NA G eate Bay Ma nCounty 2016 9 1 2016 9 1 2036 8 31
NA SCE R ve s deCounty 2020 12 17 2020 12 17 2040 12 16 NA G eate Bay Cont aCostaCount 2016 10 6 2016 10 6 2036 10 5 NA G eate Bay Cont aCostaCount 2016 10 6 2016 10 6 2036 10 5 NA G eate F esno F esnoCounty 2018 4 14 2018 4 14 2033 4 13 NA G eate F esno F esnoCounty 2020 12 10 2020 12 10 2040 12 9 NA G eate F esno F esnoCounty 2020 12 10 2020 12 10 2040 12 9 NA G eate F esno F esnoCounty 2020 12 10 2020 12 10 2040 12 9 NA G eate F esno F esnoCounty 2020 12 10 2020 12 10 2040 12 9 NA G eate Bay Ma nCounty 2012 10 23 2012 10 23 2032 10 22 NA G eate F esno K ngsCounty 2015 6 25 2015 6 25 2032 12 31 NA PacGE NapaCounty 2020 12 11 2020 8 30 2040 8 29
NA PacGE NapaCounty 2020 12 11 2020 8 30 2040 8 29
NA PacGE NapaCounty 2019 9 24 2019 9 1 2039 8 31
NA PacGE NapaCounty 2019 9 24 2019 9 1 2039 8 31
NA PacGE NapaCounty 2019 9 24 2019 9 1 2039 8 31
NA PacGE Ma nCounty 2021 3 30 2021 3 30 2041 3 29
NA PacGE Ma nCounty 2021 3 30 2021 3 30 2041 3 29
NA PacGE Ma nCounty 2020 8 28 2020 9 30 2040 9 29
NA G eate Bay Ma nCounty 2018 12 10 2018 12 10 2038 12 9 NA G eate Bay Cont aCostaCount 2018 7 23 2018 7 31 2038 7 30 NA G eate Bay Ma nCounty 2019 5 24 2019 5 14 2039 5 13
NA G eate F esno K ngsCounty 2015 5 22 2015 5 22 2040 4 30 NA G eate F esno K ngsCounty 2015 5 22 2015 5 22 2040 4 30 NA G eate Bay Ma nCounty 2015 5 22 2015 5 22 2040 4 30
NA G eate Bay No_sub_a ea Cont aCostaCount 2017 12 22 2017 12 22 2037 12 21 NA G eate Bay No sub a ea Cont aCostaCount 2017 12 22 2017 12 22 2037 12 21 NA PacGE Ke nCounty 2021 6 9 2021 7 5 2036 7 4
NA PacGE NapaCounty 2021 3 30 2021 3 30 2041 3 29
NA PacGE SolanoCounty 2021 9 14 2021 9 30 2041 9 29
NA PacGE Cont aCostaCount 2022 5 21 2022 5 21 2042 5 20 BayWa RE PacGE No sub a ea SantaBa ba aCounty 2042 12 30 NA PacGE Cont aCostaCount 2021 12 10 2021 12 1 2041 11 30 NA PacGE Cont aCostaCount 2022 3 7 2021 10 1 2041 9 30
NA PacGE Ma nCounty 2022 4 4 2021 12 1 2041 11 30
RPCA Sola 3, LLC PacGE Cont aCostaCount 2022 11 30 2022 11 30 2042 11 29 NA PacGE NapaCounty 2022 4 13 2021 11 1 2041 10 31
NA G eate Bay Ma nCounty 2022 7 15 2022 7 16 2032 7 15
East Bay Commun ty Ene gy NA G eate F esno K ngsCounty 2015 5 22 2021 9 6 2024 12 31 San Jose Clean Ene gy NA G eate F esno K ngsCounty 2015 5 22 2021 11 1 2024 12 31 Pen nsula Clean Ene gy Autho ty NA G eate F esno K ngsCounty 2015 5 22 2022 1 17 2024 12 31 Clea way Ene gy G oup SCE No sub a ea Ke nCounty 2025 3 1 2025 3 1 2040 2 29 Ranch Se eno Clean Powe LLC PacGE Cont aCostaCount 2024 2 22 2024 2 22 2044 2 21 CES Elect on Fa m One, LLC PacGE F esnoCounty 2023 12 31 2023 12 31 2043 12 30 CES Elect on Fa m One, LLC PacGE F esnoCounty 2023 12 31 2023 12 31 2043 12 30 Clea way Ene gy G oup SCE No sub a ea SanBe na d noCoun 2023 8 28 2023 8 28 2038 8 27 NA G eate Bay Cont aCostaCount 2013 5 1 2023 5 1 2026 9 30 NA G eate F esno F esnoCounty 2001 1 1 2020 1 1 2030 12 31 NA S e a Sutte County 2002 12 23 2023 1 1 2024 12 31
NA BANC No sub a ea Sutte County 2001 7 1 2021 1 1 2023 12 31 NA PacGE Cal fo n a 2022 1 1 2028 12 31
NA PacGE Cal fo n a 2022 7 1 2030 12 31
NA PacGE Cal fo n a 2023 1 1 2030 12 31
NA PacGE Cal fo n a 2023 4 1 2025 12 31
Hecate G d SCE LosAngelesCounty 2024 4 1 2024 4 1 2034 3 31 NA Stockton SanJoaqu nCounty 1983 1 1 2015 7 1 2025 6 30 NA PacGE Calave asCounty 1930 1 1 2023 1 1 2024 12 31
NA PacGE Cal fo n a 2024 1 1 2024 12 31
NA PACW O egon 2021 1 1 2024 12 31
NA PACW O egon 2021 1 1 2024 12 31
NA S e a Place County 1966 1 1 2022 1 1 2024 12 31
NA PACW O egon 2023 1 1 2025 12 31
NA PACW O egon 2022 5 20 2025 12 31
NA PACW O egon 2023 1 1 2025 12 31
NA BANC Cal fo n a 2015 1 1 2024 12 31
NA BANC Cal fo n a 2025 1 1 2054 12 31
Pac f c Gas & Elect c NA PacGE Cal fo n a 2024 1 1 2043 12 31 Pac f c Gas & Elect c NA PacGE Cal fo n a 2023 1 1 2042 12 31 Unknown SCE Ke nCounty 2026 1 1 2026 1 1 2045 12 31
Unknown PacGE NewMex co 2030 1 1 2030 1 1 2049 12 31
Unknown PacGE Cal fo n a 2033 1 1 2033 1 1 2052 12 31
Unknown I D Impe alCounty 2030 1 1 2030 1 1 2049 12 31
Unknown PacGE Cont aCostaCount 2026 1 1 2026 1 1 2045 12 31 Pac f c Gas & Elect c NA PacGE Cal fo n a 2023 1 1 2024 12 31 Pac f c Gas & Elect c NA PacGE Cal fo n a 2023 1 1 2024 12 31 Pac f c Gas & Elect c NA PacGE Cal fo n a 2023 1 1 2024 12 31 Pac f c Gas & Elect c NA PacGE Cal fo n a 2023 1 1 2024 12 31 Pac f c Gas & Elect c NA PacGE Cal fo n a 2023 1 1 2024 12 31 NA PacGE Cal fo n a 2023 1 1 2042 12 31
NA PacGE Cal fo n a 2023 1 1 2042 12 31
NA PacGE Cal fo n a 2023 1 1 2042 12 31
NA PacGE Cal fo n a 2023 1 1 2042 12 31
NA PacGE Cal fo n a 2023 1 1 2042 12 31
NA PacGE Cal fo n a 2023 1 1 2042 12 31
Unknown PacGE Cont aCostaCount 2030 1 1 2030 1 1 2049 12 31 Unknown PacGE SolanoCounty 2028 1 1 2028 1 1 2047 12 31 Unknown PacGE NapaCounty 2034 1 1 2034 1 1 2053 12 31
NA PacGE Cal fo n a 2023 1 1 2023 12 31
NA PacGE Cal fo n a 2024 1 1 2024 12 31
NA PacGE Cal fo n a 2025 1 1 2025 12 31
NA PacGE Cal fo n a 2026 1 1 2026 12 31
NA PacGE Cal fo n a 2027 1 1 2027 12 31
NA PacGE Cal fo n a 2028 1 1 2028 12 31
NA PacGE Cal fo n a 2029 1 1 2029 12 31
NA PacGE Cal fo n a 2030 1 1 2030 12 31
NA PacGE Cal fo n a 2031 1 1 2031 12 31
NA PacGE Cal fo n a 2032 1 1 2032 12 31
NA PacGE Cal fo n a 2033 1 1 2033 12 31
NA PacGE Cal fo n a 2034 1 1 2034 12 31
NA PacGE Cal fo n a 2035 1 1 2035 12 31
Res Stat on, LLC PacGE Cal fo n a 2023 1 1 2023 1 1 2032 12 31 Pac f c Gas & Elect c 2018 1 1 2024 1 1 2026 12 31
Pac f c Gas & Elect c 2018 1 1 2024 1 1 2025 12 31
Pac f c Gas & Elect c 2018 1 1 2024 1 1 2024 12 31
Pac f c Gas & Elect c 2018 1 1 2024 1 1 2024 12 31
Pac f c Gas & Elect c 2018 1 1 2024 1 1 2025 12 31
Pac f c Gas & Elect c 2018 1 1 2024 1 1 2026 12 31
Pac f c Gas & Elect c 2018 1 1 2024 1 1 2035 12 31
Pac f c Gas & Elect c 2024 1 1 2025 1 1 2035 12 31
Pac f c Gas & Elect c 2024 1 1 2024 1 1 2035 12 31
Attachment B - 25 MMT RDT

un que_cont acts
lse_unique_contract_id
Ost om_MCE
Hay MCE
Geyse s MCE
L ncoln MCE
Voyage II MCE
WM_MCE
Antelope 2 MCE
Cooley I MCE
Cost Plus_MCE
Dese t Ha vest MCE
F eethy 1 MCE
F eethy 2_MCE
G eat Valley MCE
L ttle Bea 1 MCE
L ttle Bea 3 MCE
L ttle Bea 4 MCE
L ttle Bea 5_MCE
SR A po t MCE
Mustang MCE
Soscal Fe y Sola C_MCE
Soscal Fe y Sola D MCE
Ame can Canyon Sola A MCE
Ame can Canyon Sola B_MCE
Ame can Canyon Sola C MCE
S lve a Ranch A MCE
S lve a Ranch B_MCE
SR A po t 2 MCE
EO P oducts MCE
Oakley RV & Boat Sto age MCE
DRES Qua y 2.4 MCE
Co co an_MCE
Goose Lake MCE
Buck MCE
MCE Sola 1_8.5_MCE
MCE Sola 1 2.0 MCE
Ke n Tule PCC1 1 LT MCE
S lve a Ranch C_MCE
Lake He man PCC1 1 LT MCE
By on Sola PCC1 1 LT MCE
St auss PCC1 1 LT MCE
By on Sola PCC1 2 LT MCE
Haywo th_PCC1_1_LT_MCE
Fallon PCC1 1 LT MCE
RPCA PCC1 1 LT MCE
Napa_PCC1_1_LT_MCE
CMSA PCC1 2 LT MCE
EBCE PCC1 Sale 1 MCE
SJCE_PCC1_Sale_1_MCE
PCEA PCC1 Sale 1 MCE
Golden F elds PCC1 LT MCE
Ranch Se eno_PCC1_LT_MCE
CES Elect on Fa m PCC1 DAC 1 LT MCE
CES Elect on Fa m PCC1 DAC 2 LT MCE
Daggett PCC1 1 LT MCE
Ma sh Land ng LLC RA 1 BAF MCE
WELLHEAD_RA_3_POF_MCE
CALPINE RA 35 S F MCE
CALPINE RA 34 NS MCE
CALPINE_RA_44_NS_MCE
CALPINE RA 67 NS MCE
CALPINE RA 68 NSF MCE
ENERSPONSE_RA_2_SS_MCE
Hecate Sto age RA 2024
EBMUD B1 MCE
EBMUD B1 MCE
SENA CF 13 MCE
MSCG_CF_5_MCE
B ookf eld CF 4 MCE
TENASKA CF 2 MCE
POWEREX_CF_3_MCE
Powe ex CF 4 MCE
Powe ex CF 5 MCE
WAPA_BR_MCE
WAPA BR 2 MCE
GHG F ee A locat on
DR A locat on
OS22 New W nd 2026
Gene c LT W nd NM 2030
Gene c LT W nd_2033
Gene c LT Geothe mal 2030
MTR LDS 2026
VAMO_ST_B omass
VAMO ST Sola PV
VAMO ST W nd
VAMO ST Small Hyd o
VAMO ST Geothe mal
Gene c ST B omass
Gene c ST Sola
Gene c ST W nd
Gene c ST Small Hyd o
Gene c ST Geothe mal
Gene c ST La ge Hyd o/ACS
Gene c LDS_2030
Gene c 4 Hou Sto age 2028
Gene c 4 Hou Sto age 2034
Gene c CCGT RA_2023
Gene c CCGT RA 2024
Gene c CCGT RA 2025
Gene c CCGT RA 2026
Gene c CCGT RA 2027
Gene c CCGT RA_2028
Gene c CCGT RA 2029
Gene c CCGT RA 2030
Gene c CCGT RA_2031
Gene c CCGT RA 2032
Gene c CCGT RA 2033
Gene c CCGT RA_2034
Gene c CCGT RA 2035
RESI RA 2 NS MCE
PGE Onl ne ccgt 1
PGE Onl ne ccgt 2
PGE_Onl ne_ccgt_3
PGE Onl ne chp
PGE Onl ne chp 1
PGE_Onl ne_chp_2
PGE Onl ne batte y
PGE Development batte y 1
PGE_Development_batte y_2
contract_execution_date_year contract_execut on_date_month contract_execut on_date_day tx_upgrades tx_upgrade_date_year tx_upgrade_date_month tx_upgrade_date_day tx_upgrade_descript on d1911016_tranche d2106035_procurement_cat mtr_tranche1_NQC mtr_tranche2_NQC mtr_tranche3_NQC mtr_tranche4_NQC_LDES mtr_tranche4_NQC_firm_ZE mtr_NQC_ZE_gen_paired_dr previous_COD_year 2010 12 3 NA NA
2010 12 3 NA NA
2013 7 11 NA NA
2012 7 6 NA NA
2016 12 5 NA NA
2014 11 6 NA 3 NA 2017
2016 11 15 NA NA
2014 10 7 NA NA
2015 4 14 NA NA
2016 11 18 NA NA
2015 9 4 NA NA
2015 9 4 NA NA
2016 9 15 NA NA
2016 9 23 NA NA
2016 9 23 NA NA
2016 9 23 NA NA
2016 9 23 NA NA
2012 5 8 NA NA
2014 10 3 NA NA
2018 8 30 NA NA
2018 8 30 NA NA
2018 8 30 NA NA
2018 8 30 NA NA
2018 8 30 NA NA
2019 3 7 NA NA
2019 3 7 NA NA
2018 10 24 NA NA
2018 10 31 NA NA
2018 5 8 NA NA
2018 3 23 NA NA
2011 7 8 NA NA
2011 7 8 NA NA
2011 7 8 NA NA
2017 5 30 NA 3 NA 2017
2017 5 30 NA 3 NA 2017
2020 1 22 NA NA
2019 3 7 NA NA
2020 7 29 NA NA
2020 10 15 NA NA
2018 10 19 YES Completed 3 NA 2022
2020 12 11 NA NA
2021 3 8 NA NA
2021 4 5 NA NA
2021 3 29 NA NA
2021 4 14 NA NA
2021 7 16 NA NA
2021 9 6 NA NA
2021 11 1 NA NA
2021 11 29 NA NA
2022 2 4 YES 2024 10 1 NA gene al & ZE gen pa ed d 75 61.3 2022 2 23 NO NA NA
2022 3 20 NA NA
2022 3 20 NA NA
2020 9 25 YES NA gene al & ZE gen pa ed d 58 7.9 48.1 2022 2022 7 26 NA NA
2019 8 1 NA NA
NA NA
2020 2 28 NA 1&2 NA 2001
NA NA
NA NA
NA NA
NA NA
2022 8 4 NA gene al 167.795
2015 6 22 NA NA
2015 6 22 NA NA
2019 4 26 NA NA
2020 9 15 NA NA
2020 2 14 NA NA
2021 12 17 NA NA
2022 4 11 NA NA
2022 5 18 NA NA
2022 5 18 NA NA
2011 12 14 NA NA
2021 3 18 NA NA
NA NA
NA NA

NA NA NA

NA NA NA

NA NA NA

NA NA NA
NA NA long du at on sto age 31.28
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA

NA NA NA

NA NA NA

NA NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
2022 8 31 NA 3
2017 1 1
2017 1 1
2017 1 1
2017 1 1
2017 1 1
2017 1 1
2017 1 1
2022 1 1
2022 1 1
Attachment B - 25 MMT RDT

un que_cont acts
lse_unique_contract_id
Ost om_MCE
Hay MCE
Geyse s MCE
L ncoln MCE
Voyage II MCE
WM_MCE
Antelope 2 MCE
Cooley I MCE
Cost Plus_MCE
Dese t Ha vest MCE
F eethy 1 MCE
F eethy 2_MCE
G eat Valley MCE
L ttle Bea 1 MCE
L ttle Bea 3 MCE
L ttle Bea 4 MCE
L ttle Bea 5_MCE
SR A po t MCE
Mustang MCE
Soscal Fe y Sola C_MCE
Soscal Fe y Sola D MCE
Ame can Canyon Sola A MCE
Ame can Canyon Sola B_MCE
Ame can Canyon Sola C MCE
S lve a Ranch A MCE
S lve a Ranch B_MCE
SR A po t 2 MCE
EO P oducts MCE
Oakley RV & Boat Sto age MCE
DRES Qua y 2.4 MCE
Co co an_MCE
Goose Lake MCE
Buck MCE
MCE Sola 1_8.5_MCE
MCE Sola 1 2.0 MCE
Ke n Tule PCC1 1 LT MCE
S lve a Ranch C_MCE
Lake He man PCC1 1 LT MCE
By on Sola PCC1 1 LT MCE
St auss PCC1 1 LT MCE
By on Sola PCC1 2 LT MCE
Haywo th_PCC1_1_LT_MCE
Fallon PCC1 1 LT MCE
RPCA PCC1 1 LT MCE
Napa_PCC1_1_LT_MCE
CMSA PCC1 2 LT MCE
EBCE PCC1 Sale 1 MCE
SJCE_PCC1_Sale_1_MCE
PCEA PCC1 Sale 1 MCE
G ld n F PC 1 LT MCE
Ranch Se eno_PCC1_LT_MCE
CES Elect on Fa m PCC1 DAC 1 LT MCE
CES Elect on Fa m PCC1 DAC 2 LT MCE
D g e t PCC1 1 T MCE
Ma sh Land ng LLC RA 1 BAF MCE
WELLHEAD_RA_3_POF_MCE
CALPINE RA 35 S F MCE
CALPINE RA 34 NS MCE
CALPINE_RA_44_NS_MCE
CALPINE RA 67 NS MCE
CALPINE RA 68 NSF MCE
ENERSPONSE_RA_2_SS_MCE
Hecate Sto age RA 2024
EBMUD B1 MCE
EBMUD B1 MCE
SENA CF 13 MCE
MSCG_CF_5_MCE
B ookf eld CF 4 MCE
TENASKA CF 2 MCE
POWEREX_CF_3_MCE
Powe ex CF 4 MCE
Powe ex CF 5 MCE
WAPA_BR_MCE
WAPA BR 2 MCE
GHG F ee A locat on
DR A locat on
OS22 New W nd 2026
Gene c LT W nd NM 2030
Gene c LT W nd_2033
Gene c LT Geothe mal 2030
MTR LDS 2026
VAMO_ST_B omass
VAMO ST Sola PV
VAMO ST W nd
VAMO ST Small Hyd o
VAMO ST Geothe mal
Gene c ST B omass
Gene c ST Sola
Gene c ST W nd
Gene c ST Small Hyd o
Gene c ST Geothe mal
Gene c ST La ge Hyd o/ACS
Gene c LDS_2030
Gene c 4 Hou Sto age 2028
Gene c 4 Hou Sto age 2034
Gene c CCGT RA_2023
Gene c CCGT RA 2024
Gene c CCGT RA 2025
Gene c CCGT RA 2026
Gene c CCGT RA 2027
Gene c CCGT RA_2028
Gene c CCGT RA 2029
Gene c CCGT RA 2030
Gene c CCGT RA_2031
Gene c CCGT RA 2032
Gene c CCGT RA 2033
Gene c CCGT RA_2034
Gene c CCGT RA 2035
RESI RA 2 NS MCE
PGE Onl ne ccgt 1
PGE Onl ne ccgt 2
PGE_Onl ne_ccgt_3
PGE Onl ne chp
PGE Onl ne chp 1
PGE_Onl ne_chp_2
PGE Onl ne batte y
PGE Development batte y 1
PGE_Development_batte y_2
prev ous_COD_month previous_COD_day remediat on_plan signed_contract notice_to_proceed public_contract buying_energy_capac ty NQC_reporting_source procurement_origin csp_resource_category csp_annual_2024 csp_annual_2026 csp_annual_2030 csp_annual_2035 macro_supertype notes YES Ene gyCapac ty Calculated RPS, RA B ogas (GWh) 12 12 12 0 phys cal YES Ene gyCapac ty Calculated RPS, RA B ogas (GWh) 11 11 11 0 phys cal YES Ene gyCapac ty Calculated RPS, RA Geothe mal (GWh) 88 88 0 0 phys cal YES Ene gyCapac ty Calculated RPS, RA B ogas (GWh) 27 27 27 0 phys cal YES Ene gyCapac ty Calculated RPS, RA W nd Ex st ng Cal fo n a GWh) 138 138 137 0 phys cal 9 14 NO YES NO s YES es u ce a c pable of e g ble D 1 11 0 6 s fo f D E gyCapa ty C lc ate RPS, R B gas GWh 30 0 0 3 MCE p ov executed cont act n ts Feb ua y 1, 2021 compl anc y cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 294 292 286 279 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 2 2 2 2 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 1 1 1 1 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 258 255 250 243 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 2 2 2 2 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 2 2 2 2 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 286 284 281 0 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 108 107 105 102 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 54 53 52 51 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 135 133 131 127 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 135 133 131 127 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 2 2 2 0 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 82 81 79 0 phys cal YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 2 2 2 0 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 1 1 0 0 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 2 2 2 2 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 1 1 0 0 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 28 28 27 26 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 31 30 30 29 phys cal YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 2 1 ex st nggene c 12 22 NO YES NO s YES es u ce a c pable of e g ble ou c p .19 1 - 1 MCE s fo f D E gyCapa ty C lc ate RPS, R S l Ex st g l o a GWh) 17 7 7 1 MCE p ov executed cont act n ts Feb ua y 1, 2021 compl anc y cal 12 22 NO YES NO s YES En g Ca ac y e u e t capa l o e g e so p D. 1 16 MCE n o . C lc t d RPS RA S la E st Ca fo ( W ) 4 4 M E ov executed cont act n ts Feb ua y 1, 2021 compl anc h s al YES Ene gyCapac ty Calculated RPS, RA Sma l Hyd o (GWh) 37 37 37 37 phys cal YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c h s u e s a c 7 g e 1 YES a co 1 6 MW f NQ tow d 19 1 0 6 e u v ded t e o t act a d 3) s gned land le e 1 co e D S p mp d t e Co med at on Plan and (2) a P oject T mel ne. In ts Feb YES YES a y n c a at on n e y a a t C lc t d RP , R W Ne PG E (GWh) 91 2 90 290 y l YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 8 8 8 8 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 2 2 2 2 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 2 2 2 2 ex st nggene c YES Yes, but p c ng and any f nanc al nfo mat on oEne gyCapac ty Calculated RPS, RA Sola D st buted (GWh) 14 14 14 13 newgene c Feed n ta ff YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 1 1 1 1 ex st nggene c YES Ene gyCapac ty Calculated RPS B omass (GWh) 4 4 4 0 ex st nggene c YES Ene gyOnly Calculated RPS Sola Ex st ng Cal fo n a (GWh) 8 0 0 0 phys cal YES Ene gyOnly Calculated RPS Sola Ex st ng Cal fo n a (GWh) 4 0 0 0 phys cal YES Ene gyOnly Calculated RPS Sola Ex st ng Cal fo n a (GWh) 10 0 0 0 phys cal M p ns to us t u c to Y S Y , t p c n n n f n nf n o y 75 M QC t wa s MCE s t a D.21 0 e en . MC a o ce t c et ng t e b et u n n e d o p ac t e D ablo C n a h t f e le ty o m e u ava lab l ty equ ement (~61MW of NQC) and the g E e C a t Cal t d R S D.21-06-0 5 Hyb d P d S la att ( Wh) 0 30 95 2 5 ne gen YES Yes, but p c ng and any f nanc al nfo mat on oEne gyCapac ty Calculated RPS, RA Sola D st buted (GWh) 5 5 5 5 newgene c Feed n ta ff YES Yes, but p c ng and any f nanc al nfo mat on oEne gyCapac ty Calculated RPS,RA Sola D st buted (GWh) 1 1 1 1 newgene c Feed n ta ff YES Yes, but p c ng and any f nanc al nfo mat on oEne gyCapac ty Calculated RPS Sola D st buted (GWh) 12 12 12 12 newgene c Feed n ta ff M E la s s t so el 1 31 p ten e t ly 6 M o QC ow ds M E o l D 21 q ment MCE e ou to g he su equ m t n en e t p c the D abl C Pl h a es t e ou e s b DCPP 5 hou ava lab l ty equ ement.MCE plans to u NA YES Y b t c g n f n c l nf m n oEne Ca a C lcula d RPS, R Hy d So a a d Ba t (GW ) 3 324 319 11 wge YES Capac tyOnly Calculated RA NA 0 0 0 0 phys cal
YES Capac tyOnly In the cont act RA NA 0 0 0 0 phys cal YES Capac tyOnly In the cont act RA NA 0 0 0 0 phys cal 7 1 NO YES NO YES o ew cont l g bl a em me t e D.1 1 t 5 D m C UC ex cu n ts Feb ua y 1, 2021 compl ance f l ng pe D.20-12- Cap c t O y th ont act D19 101 RA NA 0 0 s e ed m t YES Capac tyOnly In the cont act RA NA 0 0 0 0 ex st nggene c YES Capac tyOnly In the cont act RA NA 0 0 0 0 ex st nggene c YES Capac tyOnly In the cont act RA NA 0 0 0 0 ex st nggene c YES Capac tyOnly In the cont act RA NA 0 0 0 0 ex st nggene c YES Yes, but p c ng and any f nanc al nfo mat on Capac tyOnly Calculated D2106035 Batte y Sto age MWh Ene gy Capac ty) 555 n RA u c o 7 0 740 7 0 nety com l nt pu suant to D.21-06-035. MCE ntends and expect YES Ene gyOnly Calculated RPS Sma l Hyd o (GWh) 45.8 0 0 0 phys cal YES Ene gyOnly Calculated RPS Sma l Hyd o (GWh) 139 5 0 0 0 phys cal YES Ene gyOnly Calculated pol cy La ge Hyd o (GWh) 200 0 0 0 ex st nggene c YES Ene gyOnly Calculated pol cy Impo ted Hyd o (GWh) 400 0 0 0 ex st nggene c YES Ene gyOnly Calculated pol cy Impo ted Hyd o (GWh) 200 0 0 0 ex st nggene c YES Ene gyOnly Calculated pol cy La ge Hyd o (GWh) 120 0 0 0 phys cal YES Ene gyOnly Calculated pol cy Impo ted Hyd o (GWh) 250 0 0 0 ex st nggene c YES Ene gyOnly Calculated pol cy Impo ted Hyd o (GWh) 200 0 0 0 ex st nggene c YES Ene gyOnly Calculated pol cy Impo ted Hyd o (GWh) 100 0 0 0 ex st nggene c YES Ene gyOnly Calculated RPS La ge Hyd o (GWh) 25 0 0 0 ex st nggene c YES Ene gyOnly Calculated RPS La ge Hyd o (GWh) 0 25 25 25 ex st nggene c No Ene gyOnly Calculated allocat on La ge Hyd o (GWh) 500 500 500 500 ex st nggene c No Capac tyOnly In the cont act allocat on Shed DR MW) 0 0 0 0 ex st nggene c NA NO No Ene gyCapac ty Calculated RPS, RA W nd New SCE SDG&E (GWh) 0 263 263 263 newgene c Gene c NA NO No Ene gyCapac ty Calculated RPS, RA W nd New Mex co (GWh) 0 0 250 250 new esolve Gene c NA NO No Ene gyCapac ty Calculated RPS, RA W nd Offsho e Mo o Bay (GWh) 0 0 0 400 new esolve Gene c NA NO No Ene gyCapac ty Calculated RPS, RA Geothe mal (GWh) 0 0 580 580 newgene c Gene c NA NO No Ene gyCapac ty Calculated D2106035 Batte y Sto age MWh Ene gy Capac ty) 0 0 0 0 newgene c Gene c Yes Ene gyOnly Calculated allocat on B omass (GWh) 33 0 0 0 ex st nggene c Yes Ene gyOnly Calculated allocat on Sola Ex st ng Cal fo n a (GWh) 206 0 0 0 ex st nggene c Yes Ene gyOnly Calculated allocat on W nd Ex st ng Cal fo n a GWh) 165 0 0 0 ex st nggene c Yes Ene gyOnly Calculated allocat on Sma l Hyd o (GWh) 14 0 0 0 ex st nggene c Yes Ene gyOnly Calculated allocat on Geothe mal (GWh) 70 0 0 0 ex st nggene c No Ene gyOnly Calculated RPS B omass (GWh) 28 34 0 16 ex st nggene c No Ene gyOnly Calculated RPS Sola Ex st ng Cal fo n a (GWh) 138 171 0 79 ex st nggene c No Ene gyOnly Calculated RPS W nd Ex st ng Cal fo n a GWh) 303 558 214 374 ex st nggene c No Ene gyOnly Calculated RPS Sma l Hyd o (GWh) 55 69 0 32 ex st nggene c No Ene gyOnly Calculated RPS Geothe mal (GWh) 142 98 117 149 ex st nggene c No Ene gyOnly Calculated RPS Impo ted Hyd o (GWh) 0 766 69 120 ex st nggene c NA NO No Ene gyCapac ty Calculated RA Batte y Sto age MWh Ene gy Capac ty) 0 0 400 400 newgene c Gene c NA NO No Ene gyCapac ty Calculated RA Batte y Sto age MWh Ene gy Capac ty) 0 0 800 800 newgene c Gene c NA NO No Ene gyCapac ty Calculated RA Batte y Sto age MWh Ene gy Capac ty) 0 0 0 800 newgene c Gene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c YES NO b any f nanc al nfo mat on Capac tyOnly In the cont act D1911016, RA Shed DR MW)T s c n 15 15 15 M es u e east 15 MW of nc emental NQC towa ds MCE's D 19 1 0 new e e Ene gyCapac ty NA 0 0 0 0
Ene gyCapac ty NA 0 0 0 0
Ene gyCapac ty NA 0 0 0 0
Ene gyCapac ty NA 0 0 0 0
Ene gyCapac ty NA 0 0 0 0
Ene gyCapac ty NA 0 0 0 0
Capac tyOnly Batte y Sto age MWh Ene gy Capac ty) 93.23439546 93.23439546 93.23439546 93.23439546 Capac tyOnly Batte y Sto age MWh Ene gy Capac ty) 23.30859887 23.30859887 23.30859887 23.30859887 Ene gyCapac ty Batte y Sto age MWh Ene gy Capac ty) 0.385368835 0 385368835 0 385368835 0 385368835 Attachment B - 25 MMT RDT

Calcs
resource contract_status contracted_nameplate_capacity is_hybrid_paired can_charge_from_grid contracted_generator_mw contracted_storage_mw contracted_storage_depth_mwh buy_sell_own contract_start_date_year contract_start_date_month contract_start_date_day WHEATL_6_LNDFIL Online 2 NotHybrid 0 0 0 0 0 2013 7 1
PEABDY 2 LNDFIL Online 2 NotHybrid 0 0 0 0 0 2013 7 1
GEYS13_7_UNIT13 Online 10 NotHybrid 0 0 0 0 0 2017 1 1
PLSNTG_7_LNCLND Online 5 NotHybrid 0 0 0 0 0 2013 2 14
VOYAGR_2_VOYWD3 Online 0 NotHybrid 0 0 0 0 0 2018 12 29 NOVATO_6_LNDFL Online 4 NotHybrid 0 0 0 0 0 2017 9 14
BGSKYN 2 AS2SR1 Online 105 NotHybrid 0 0 0 0 0 2019 1 1 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2017 3 1 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2016 9 1 DSRTHV_2_DH1SR1 Online 80 NotHybrid 0 0 0 0 0 2020 12 17 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2016 10 6 EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2016 10 6 TRNQL8_2_ROJSR1 Online 100 NotHybrid 0 0 0 0 0 2018 4 14 LTBERA_1_LB1SR1 Online 40 NotHybrid 0 0 0 0 0 2020 12 10 LTBEAR_1_LB3SR3 Online 20 NotHybrid 0 0 0 0 0 2020 12 10 LTBEAR_1_LB4SR4 Online 50 NotHybrid 0 0 0 0 0 2020 12 10 LTBEAR 1 LB4SR5 Online 50 NotHybrid 0 0 0 0 0 2020 12 10 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2012 10 23 MSTANG_2_SOLAR4 Online 30 NotHybrid 0 0 0 0 0 2015 6 25 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2020 8 30 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2020 8 30 EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2019 9 1 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2019 9 1 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2019 9 1 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2021 3 30 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2021 3 30 EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2020 9 30 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2018 12 10 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2018 7 31 _EXISTING_GENERIC_SOLAR_FIXED Online 0 NotHybrid 0 0 0 0 0 2019 5 14 CORCAN_1_SOLAR2 Online 11 NotHybrid 0 0 0 0 0 2015 5 22 GOOSLK 1 SOLAR1 Online 12 NotHybrid 0 0 0 0 0 2015 5 22 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2015 5 22 RICHMN_1_CHVSR2 Online 9 NotHybrid 0 0 0 0 0 2017 12 22 RICHMN_1_SOLAR Online 2 NotHybrid 0 0 0 0 0 2017 12 22
KRNCNY_6_UNIT Online 11 NotHybrid 0 0 0 0 0 2021 7 5
EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2021 3 30 _EXISTING_GENERIC_SOLAR_FIXED Online 5 NotHybrid 0 0 0 0 0 2021 9 30 _EXISTING_GENERIC_SOLAR_FIXED Online 3 NotHybrid 0 0 0 0 0 2022 5 21 STRAUSSWIND Development 91 NotHybrid 0 0 0 0 0
_EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2021 12 1 EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2021 10 1 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2021 12 1 _NEW_GENERIC_SOLAR_FIXED Development 5 NotHybrid 0 0 0 0 0 2022 11 30 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2021 11 1 _EXISTING_GENERIC_BIOMASS/WOOD Online 1 NotHybrid 0 0 0 0 0 2022 7 16 GOOSLK 1 SOLAR1 Online 0 NotHybrid 0 0 0 0 Sell 2021 9 6 CORCAN_1_SOLAR2 Online 0 NotHybrid 0 0 0 0 Sell 2021 11 1 GOOSLK_1_SOLAR1 Online 0 NotHybrid 0 0 0 0 Sell 2022 1 17 _NEW_GENERIC_SOLAR_1AXIS Development 100 NewSolarNewStorage NO 100 92 368 0 2025 3 1 _NEW_GENERIC_SOLAR_1AXIS Development 2 NewSolarNewStorage NO 2 0.8 3.2 0 2024 2 22 NEW GENERIC SOLAR 1AXIS Development 0 NotHybrid 0 0 0 0 0 2023 12 31 _NEW_GENERIC_SOLAR_1AXIS Development 4 NotHybrid 0 0 0 0 0 2023 12 31 _NEW_GENERIC_SOLAR_1AXIS Development 110 NewSolarNewStorage NO 110 60 240 0 2023 8 28 COCOPP_2_CTG4 Online 81 NotHybrid 0 0 0 0 0 2023 5 1
AGRICO_7_UNIT Online 50 NotHybrid 0 0 0 0 0 2020 1 1
BOGUE 1 UNITA1 Online 32 NotHybrid 0 0 0 0 0 2023 1 1
SUTTER_2_CISO Online 70 NotHybrid 0 0 0 0 0 2021 1 1
_EXISTING_GENERIC_COMBINED_CYCLE Online 25 NotHybrid 0 0 0 0 0 2022 1 1 _EXISTING_GENERIC_COMBINED_CYCLE Online 15 NotHybrid 0 0 0 0 0 2022 7 1 _EXISTING_GENERIC_COMBINED_CYCLE Online 15 NotHybrid 0 0 0 0 0 2023 1 1 EXISTING GENERIC DR Online 20 NotHybrid 0 0 0 0 0 2023 4 1 _NEW_GENERIC_BATTERY_STORAGE Development 185 NotHybrid 0 0 0 740 0 2024 4 1 CAMCHE_1_PL1X3 Online 0 NotHybrid 0 0 0 0 0 2015 7 1
PARDEB_6_UNITS Online 0 NotHybrid 0 0 0 0 0 2023 1 1
_EXISTING_GENERIC_INSTATE_LARGE_HYOnline 0 NotHybrid 0 0 0 0 0 2024 1 1 EXISTING GENERIC NW HYDRO Online 0 NotHybrid 0 0 0 0 0 2021 1 1 _EXISTING_GENERIC_NW_HYDRO Online 0 NotHybrid 0 0 0 0 0 2021 1 1 EXCHEC_7_UNIT 1 Online 0 NotHybrid 0 0 0 0 0 2022 1 1
_EXISTING_GENERIC_NW_HYDRO Online 0 NotHybrid 0 0 0 0 0 2023 1 1 _EXISTING_GENERIC_NW_HYDRO Online 0 NotHybrid 0 0 0 0 0 2022 5 20 EXISTING GENERIC NW HYDRO Online 0 NotHybrid 0 0 0 0 0 2023 1 1 _EXISTING_GENERIC_INSTATE_LARGE_HYOnline 0 NotHybrid 0 0 0 0 0 2015 1 1 _EXISTING_GENERIC_INSTATE_LARGE_HYOnline 0 NotHybrid 0 0 0 0 0 2025 1 1 _EXISTING_GENERIC_INSTATE_LARGE_HYPlannedExisting 0 NotHybrid 0 0 0 0 Buy 2024 1 1 EXISTING GENERIC DR Online 0 NotHybrid 0 0 0 0 Buy 2023 1 1 NEW GENERIC WIND PlannedNew 100 NotHybrid 0 0 0 0 0 2026 1 1 _CREZ_GENERIC_NEW_MEXICO_WIND PlannedNew 70 NotHybrid 0 0 0 0 0 2030 1 1 _CREZ_GENERIC_MORRO_BAY_OFFSHOR PlannedNew 95 NotHybrid 0 0 0 0 0 2033 1 1 _NEW_GENERIC_GEOTHERMAL PlannedNew 75 NotHybrid 0 0 0 0 0 2030 1 1 _NEW_GENERIC_BATTERY_STORAGE PlannedNew 40 NotHybrid 0 0 0 320 0 2026 1 1 EXISTING GENERIC BIOMASS/WOOD Online 0 NotHybrid 0 0 0 0 Buy 2023 1 1 _EXISTING_GENERIC_SOLAR_FIXED Online 0 NotHybrid 0 0 0 0 Buy 2023 1 1 Attachment B - 25 MMT RDT

Calcs
_EXISTING_GENERIC_WIND Online0 NotHybrid0000 Buy 202311 _EXISTING_GENERIC_INSTATE_SMALL_HYOnline0 NotHybrid0000 Buy 202311 EXISTING GENERIC GEOTHERMAL Online0 NotHybrid0000 Buy 202311 _EXISTING_GENERIC_BIOMASS/WOOD PlannedExisting0 NotHybrid00000 202311 _EXISTING_GENERIC_SOLAR_FIXED PlannedExisting0 NotHybrid00000 202311 _EXISTING_GENERIC_WIND PlannedExisting0 NotHybrid00000 202311 _EXISTING_GENERIC_INSTATE_SMALL_HYPlannedExisting0 NotHybrid00000 202311 EXISTING GENERIC GEOTHERMAL PlannedExisting0 NotHybrid00000 202311 _EXISTING_GENERIC_NW_HYDRO PlannedExisting0 NotHybrid00000 202311 _NEW_GENERIC_BATTERY_STORAGE PlannedNew 50 NotHybrid000 4000 203011 _NEW_GENERIC_BATTERY_STORAGE PlannedNew 200 NotHybrid000 8000 202811 _NEW_GENERIC_BATTERY_STORAGE PlannedNew 200 NotHybrid000 8000 203411 EXISTING GENERIC COMBINED CYCLE PlannedExisting 750 NotHybrid00000 202311 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting 686 NotHybrid00000 202411 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting 639 NotHybrid00000 202511 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting 731 NotHybrid00000 202611 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting 672 NotHybrid00000 202711 EXISTING GENERIC COMBINED CYCLE PlannedExisting 498 NotHybrid00000 202811 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting 535 NotHybrid00000 202911 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting 425 NotHybrid00000 203011 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting 518 NotHybrid00000 203111 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting 542 NotHybrid00000 203211 EXISTING GENERIC COMBINED CYCLE PlannedExisting 530 NotHybrid00000 203311 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting 541 NotHybrid00000 203411 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting 549 NotHybrid00000 203511 _NEW_GENERIC_DR Review 15 NotHybrid00000 202311
_EXISTING_GENERIC_COMBINED_CYCLE Online 44 NotHybrid00000 202411 EXISTING GENERIC COMBINED CYCLE Online 39 NotHybrid00000 202411 _EXISTING_GENERIC_COMBINED_CYCLE Online 61 NotHybrid00000 202411 _EXISTING_GENERIC_COGEN Online4 NotHybrid00000 202411
_EXISTING_GENERIC_COGEN Online3 NotHybrid00000 202411
_EXISTING_GENERIC_COGEN Online1 NotHybrid00000 202411
EXISTING GENERIC BATTERY STORAGE Online 23 NotHybrid000 93.234395460 202411 _NEW_GENERIC_BATTERY_STORAGE Development6 NotHybrid000 23.308598870 202511 _NEW_GENERIC_BATTERY_STORAGE Development0 NotHybrid000 0.3853688350 202411 Attachment B - 25 MMT RDT

Attachment B - 25 MMT RDT

Calcs
2024 12 31 EnergyOnly0 in_state_w n/a in_state_w 2023 2024 100% 100%000000000000 2024 12 31 EnergyOnly0 hydro n/a hydro 2023 2024 100% 100%000000000000 2024 12 31 EnergyOnly0 geotherma n/a geotherma 2023 2024 100% 100%000000000000 2042 12 31 EnergyOnly0 biomass_w n/a biomass_w 2023 2042 100% 100%000000000000 2042 12 31 EnergyOnly0 utility_pv n/a utility_pv 2023 2042 100% 100%000000000000 2042 12 31 EnergyOnly0 in_state_w n/a in_state_w 2023 2042 100% 100%000000000000 2042 12 31 EnergyOnly0 hydro n/a hydro 2023 2042 100% 100%000000000000 2042 12 31 EnergyOnly0 geotherma n/a geotherma 2023 2042 100% 100%000000000000 2042 12 31 EnergyOnly0 hydro n/a hydro 2023 2042 100% 100%000000000000 2049 12 31 EnergyCapacity1 8hr_batter n/a 8hr_batter 2030 2049 100% 100%000000 44.5 42.56 40.62 38.68 36.74 34.8 2047 12 31 EnergyCapacity1 4hr_batter n/a 4hr_batter 2028 2047 100% 100%0000 163.2 170.6 178 158.44 138.88 119.32 99.76 80.2 2053 12 31 EnergyCapacity1 4hr_batter n/a 4hr_batter 2034 2053 100% 100%0000000000 99.76 80.2 2023 12 31 CapacityOnly1 gas cc n/a gas cc 2023 2023 100% 100%000000000000 2024 12 31 CapacityOnly1 gas_cc n/a gas_cc 2024 2024 100% 100% 579.02200000000000 2025 12 31 CapacityOnly1 gas_cc n/a gas_cc 2025 2025 100% 100%0 545.57060000000000 2026 12 31 CapacityOnly1 gas_cc n/a gas_cc 2026 2026 100% 100%00 630.9817000000000 2027 12 31 CapacityOnly1 gas_cc n/a gas_cc 2027 2027 100% 100%000 582.187100000000 2028 12 31 CapacityOnly1 gas cc n/a gas cc 2028 2028 100% 100%0000 432.85110000000 2029 12 31 CapacityOnly1 gas_cc n/a gas_cc 2029 2029 100% 100%00000 459.8663000000 2030 12 31 CapacityOnly1 gas_cc n/a gas_cc 2030 2030 100% 100%000000 361.227700000 2031 12 31 CapacityOnly1 gas_cc n/a gas_cc 2031 2031 100% 100%0000000 446.20750000 2032 12 31 CapacityOnly1 gas_cc n/a gas_cc 2032 2032 100% 100%00000000 473.0909000 2033 12 31 CapacityOnly1 gas cc n/a gas cc 2033 2033 100% 100%000000000 468.688700 2034 12 31 CapacityOnly1 gas_cc n/a gas_cc 2034 2034 100% 100%0000000000 484.61440 2035 12 31 CapacityOnly1 gas_cc n/a gas_cc 2035 2035 100% 100%00000000000 498.0705 2032 12 31 CapacityOnly1 demand_re n/a demand_re 2023 2032 100% 100% 11.58606 11.96252 12.33898 11.6229 10.90682 11.92616 12.9455 10.7884 8.6313000 2026 12 31 EnergyCapacity1 gas_cc n/a gas_cc 2024 2026 100% 100% 37.38013 37.81115 38.24217000000000 2025 12 31 EnergyCapacity1 gas cc n/a gas cc 2024 2025 100% 100% 33.11748 33.499350000000000 2024 12 31 EnergyCapacity1 gas_cc n/a gas_cc 2024 2024 100% 100% 51.6763800000000000 2024 12 31 EnergyCapacity1 cogen n/a cogen 2024 2024 100% 100% 3.40233100000000000 2025 12 31 EnergyCapacity1 cogen n/a cogen 2024 2025 100% 100% 2.895601 2.8897290000000000 2026 12 31 EnergyCapacity1 cogen n/a cogen 2024 2026 100% 100% 1.266825 1.264257 1.261688000000000 2035 12 31 CapacityOnly1 4hr batter n/a 4hr batter 2024 2035 100% 100% 19.90554 20.13863 20.37172 19.69577 19.01982 19.88223 20.74465 18.46507 16.18549 13.90591 11.62633 9.346748 2035 12 31 CapacityOnly1 4hr_batter n/a 4hr_batter 2025 2035 100% 100%0 5.034657 5.092929 4.923942 4.754954 4.970559 5.186163 4.616268 4.046373 3.476478 2.906582 2.336687 2035 12 31 EnergyCapacity1 4hr_batter n/a 4hr_batter 2024 2035 100% 100% 0.066352 0.067129 0.067906 0.065653 0.063399 0.066274 0.069149 0.06155 0.053952 0.046353 0.038754 0.031156 Attachment B - 25 MMT RDT

Attachment B - 25 MMT RDT

Attachment B - 25 MMT RDT

Attachment B - 25 MMT RDT

Attachment B - 25 MMT RDT

CSPReportSheet
Resource 2024 2026 2030 2035 Units Type
Large Hydro 845 525 525 525 GWh GHG-Free
Imported Hydro 1,150 766 69 120 GWh GHG-Free
Asset Controlling Supplier - - - - GWh GHG-Free (Partial) Nuclear - - - - GWh GHG-Free
Biogas 80 80 80 30 GWh RPS Eligible
Biomass 65 38 4 16 GWh RPS Eligible
Geothermal 332 454 1,753 1,785 GWh RPS Eligible
Small Hydro 291 106 37 69 GWh RPS Eligible
Wind Resources
Wind Existing California 606 783 438 461 GWh RPS Eligible Wind New PG&E 291 290 290 290 GWh RPS Eligible
Wind New SCE SDG&E - 263 263 263 GWh RPS Eligible
Wind Pacific Northwest - - - - GWh RPS Eligible
Wind Wyoming - - - - GWh RPS Eligible
Wind New Mexico - - 250 250 GWh RPS Eligible
Wind Offshore Morro Bay - - - 400 GWh RPS Eligible
Wind Offshore Humboldt - - - - GWh RPS Eligible
Solar Resources
Solar Existing California 1,815 1,649 1,451 1,137 GWh RPS Eligible Solar New PG&E - - - - GWh RPS Eligible
Solar New SCE SDG&E - - - - GWh RPS Eligible
Solar Distributed 32 32 32 31 GWh RPS Eligible
Hybrid
Hybrid or Paired Solar and Battery 328 626 614 596 GWh RPS Eligible Storage & DR
Shed DR 15 15 15 - MW GHG-Free
Pumped Storage - - - - MW n/a
Battery Storage 649 857 2,057 2,117 MWh Energy Capacity n/a User-Specified Profies
Storage Resource Custom Profile - - - - MW n/a
RPS Resource Custom Profile - - - - GWh RPS Eligible
GHG-free non-RPS Resource - - - - GWh GHG-Free
Coal
Coal - - - - GWh n/a
Attachment B - 25 MMT RDT

ATTACHMENT C
un que_cont acts

lse_unique_contract_id resource alternative_resource_name contract_status project_interconnection_position interconnection_substat on marginal_addition marginal_add tion_to total_nameplate_capacity contracted_nameplate_capacity sep_contracted_mw_nqc contract_gwh_annual s_hybrid_paired can_charge_from_grid Ost om_MCE WHEATL_6_LNDFIL Onl ne NA NA NA 2 2 12 NotHyb d Hay MCE PEABDY 2 LNDF L Onl ne NA NA NA 2 2 11 NotHyb d Geyse s MCE GEYS13 7 UNIT13 Onl ne NA NA NA 10 10 88 NotHyb d L ncoln MCE PLSNTG 7 LNCLND Onl ne NA NA NA 5 4 27 NotHyb d Voyage II MCE VOYAGR 2 VOYWD3 Onl ne NA NA NA 5 138 NotHyb d WM_MCE NOVATO_6_LNDFL Onl ne NA NA NA 4 3 30 NotHyb d
Antelope 2 MCE BGSKYN 2 AS2SR1 Onl ne NA NA NA 105 12 289 NotHyb d Cooley I MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d Cost Plus_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 1 NotHyb d Dese t Ha vest MCE DSRTHV 2 DH1SR1 Onl ne NA NA NA 80 9 252 NotHyb d F eethy 1 MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d F eethy 2_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d G eat Valley MCE TRNQL8 2 ROJSR1 Onl ne NA NA NA 100 11 285 NotHyb d L ttle Bea 1 MCE LTBERA 1 LB1SR1 Onl ne NA NA NA 40 4 105 NotHyb d L ttle Bea 3 MCE LTBEAR 1 LB3SR3 Onl ne NA NA NA 20 2 52 NotHyb d L ttle Bea 4 MCE LTBEAR 1 LB4SR4 Onl ne NA NA NA 50 6 132 NotHyb d L ttle Bea 5_MCE LTBEAR_1_LB4SR5 Onl ne NA NA NA 50 6 132 NotHyb d SR A po t MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d Mustang MCE MSTANG 2 SOLAR4 Onl ne NA NA NA 30 3 82 NotHyb d Soscal Fe y Sola C_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d Soscal Fe y Sola D MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d Ame can Canyon Sola A MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d Ame can Canyon Sola B_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d Ame can Canyon Sola C MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d S lve a Ranch A MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d S lve a Ranch B_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d SR A po t 2 MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d EO P oducts MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 1 NotHyb d Oakley RV & Boat Sto age MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d DRES Qua y 2.4 MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 0 0 0 1 NotHyb d Co co an_MCE CORCAN_1_SOLAR2 Onl ne NA NA NA 11 1 27 NotHyb d Goose Lake MCE GOOSLK 1 SOLAR1 Onl ne NA NA NA 12 1 30 NotHyb d Buck MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d MCE Sola 1_8.5_MCE R CHMN_1_CHVSR2 Onl ne NA NA NA 9 1 17 NotHyb d MCE Sola 1 2.0 MCE R CHMN 1 SOLAR Onl ne NA NA NA 2 0 4 NotHyb d Ke n Tule PCC1 1 LT MCE KRNCNY 6 UNIT Onl ne NA NA NA 11 5 37 NotHyb d S lve a Ranch C_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d Lake He man PCC1 1 LT MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 5 5 0 13 NotHyb d By on Sola PCC1 1 LT MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 3 3 0 8 NotHyb d St auss PCC1 1 LT MCE STRAUSSWIND Development WDT-1320 NA NA NA NotHyb d By on Sola PCC1 2 LT MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 3 NotHyb d Haywo th_PCC1_1_LT_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d Fallon PCC1 1 LT MCE EXISTING GENER C SOLAR FIXED Onl ne NA NA NA 1 1 0 2 NotHyb d RPCA PCC1 1 LT MCE NEW GENERIC SOLAR FIXED Development B entwood 2105 NA NA 5 5 0 13 NotHyb d Napa_PCC1_1_LT_MCE _EXISTING_GENER C_SOLAR_FIXED Onl ne NA NA NA 1 1 0 1 NotHyb d CMSA PCC1 2 LT MCE EX STING GENER C BIOMASS/WOOD Onl ne NA NA NA 1 1 0 3 NotHyb d EBCE PCC1 Sale 1 MCE GOOSLK 1 SOLAR1 Onl ne NA NA NA 0 8 NotHyb d SJCE_PCC1_Sale_1_MCE CORCAN_1_SOLAR2 Onl ne NA NA NA 0 4 NotHyb d PCEA PCC1 Sale 1 MCE GOOSLK 1 SOLAR1 Onl ne NA NA NA 0 10 NotHyb d Golden F elds PCC1 LT MCE NEW GENERIC SOLAR 1AXIS Development Q-1212 NA NA NA 100 100 103 272 NewSola NewSto age NO Ranch Se eno_PCC1_LT_MCE _NEW_GENERIC_SOLAR_1AXIS Development WDT-2597 NA NA NA 2 2 1 5 NewSola NewSto age NO CES Elect on Fa m PCC1 DAC 1 LT MCE NEW GENERIC SOLAR 1AXIS Development NA NA 0 0 0 1 NotHyb d CES Elect on Fa m PCC1 DAC 2 LT MCE NEW GENERIC SOLAR 1AXIS Development NA NA 4 4 0 12 NotHyb d Daggett PCC1 1 LT MCE NEW GENERIC SOLAR 1AXIS Development Q-1314 NA NA NA 110 110 66 317 NewSola NewSto age NO Ma sh Land ng LLC RA 1 BAF MCE COCOPP 2 CTG4 Onl ne NA NA NA 81 77 0 NotHyb d WELLHEAD_RA_3_POF_MCE AGRICO_7_UNIT Onl ne NA NA NA 50 48 0 NotHyb d CALPINE RA 35 S F MCE BOGUE 1 UNITA1 Onl ne NA NA NA 32 32 0 NotHyb d CALPINE RA 34 NS MCE SUTTER 2 CISO Onl ne NA NA NA 70 70 0 NotHyb d CALPINE_RA_44_NS_MCE _EXISTING_GENERIC_COMBINED_CYCLE Onl ne NA NA NA 25 25 0 NotHyb d CALPINE RA 67 NS MCE EXISTING GENERIC COMBINED CYCLE Onl ne NA NA NA 15 15 0 NotHyb d CALPINE RA 68 NSF MCE EXISTING GENERIC COMBINED CYCLE Onl ne NA NA NA 15 15 0 NotHyb d ENERSPONSE_RA_2_SS_MCE _EXISTING_GENER C_DR Onl ne NA NA NA 20 20 20 0 NotHyb d Hecate Sto age RA 2024 NEW GENERIC BATTERY STORAGE Development 185 185 185 0 NotHyb d EBMUD B1 MCE CAMCHE 1 PL1X3 Onl ne NA NA NA 10 0 46 NotHyb d EBMUD B1 MCE PARDEB 6 UNITS Onl ne NA NA NA 30 0 140 NotHyb d SENA CF 13 MCE EX STING GENERIC INSTATE LARGE HYDRO Onl ne NA NA NA 0 200 NotHyb d MSCG_CF_5_MCE _EX STING_GENERIC_NW_HYDRO Onl ne NA NA NA 0 400 NotHyb d B ookf eld CF 4 MCE EX STING GENERIC NW HYDRO Onl ne NA NA NA 0 200 NotHyb d TENASKA CF 2 MCE EXCHEC 7 UNIT 1 Onl ne NA NA NA 95 0 120 NotHyb d POWEREX_CF_3_MCE _EX STING_GENERIC_NW_HYDRO Onl ne NA NA NA 0 250 NotHyb d Powe ex CF 4 MCE EX STING GENERIC NW HYDRO Onl ne NA NA NA 0 206 NotHyb d Powe ex CF 5 MCE EX STING GENERIC NW HYDRO Onl ne NA NA NA 0 100 NotHyb d WAPA_BR_MCE EX STING_GENERIC_INSTATE_LARGE_HYDRO Onl ne NA NA NA 0 25 NotHyb d WAPA BR 2 MCE EX STING GENERIC INSTATE LARGE HYDRO Onl ne NA NA NA 0 25 NotHyb d GHG F ee A locat on EX STING GENERIC INSTATE LARGE HYDRO PlannedEx st ng 0 500 NotHyb d DR l t EXISTING GENER C DR O l 19 0 N tH
Gene c LT W nd NM 2030 CREZ GENER C NEW MEX CO WIND PlannedNew w nd mpo t planned 70 70 20 250 NotHyb d Gene c LT W nd_2033 EZ_GENER C_MORRO_BAY_OFFSHORE_WIND PlannedNew w nd_ca so_planned 95 95 41 400 NotHyb d Gene c LT Geothe mal 2030 NEW GENERIC GEOTHERMAL PlannedNew geothe mal mpo t planned 75 75 70 580 NotHyb d MTR LDS 2026 NEW GENERIC BATTERY STORAGE PlannedNew batte y ca so planned 40 40 40 0 NotHyb d VAMO_ST_B omass _EX STING_GENER C_BIOMASS/WOOD Onl ne 0 33 NotHyb d VAMO ST Sola PV EXISTING GENER C SOLAR FIXED Onl ne 0 206 NotHyb d VAMO ST W nd EXISTING GENERIC WIND Onl ne 0 165 NotHyb d VAMO ST Small Hyd o EX STING GENERIC INSTATE SMALL HYDRO Onl ne 0 14 NotHyb d VAMO ST Geothe mal EX STING GENERIC GEOTHERMAL Onl ne 0 70 NotHyb d Gene c ST B omass _EX STING_GENER C_BIOMASS/WOOD PlannedEx st ng 0 20 NotHyb d Gene c ST Sola EXISTING GENER C SOLAR FIXED PlannedEx st ng 0 99 NotHyb d Gene c ST W nd EXISTING GENERIC WIND PlannedEx st ng 0 378 NotHyb d Gene c ST Small Hyd o EX STING_GENERIC_INSTATE_SMALL_HYDRO PlannedEx st ng 0 40 NotHyb d Gene c ST Geothe mal EX STING GENERIC GEOTHERMAL PlannedEx st ng 0 125 NotHyb d Gene c ST La ge Hyd o/ACS EX STING GENERIC NW HYDRO PlannedEx st ng 0 144 NotHyb d Gene c LDS_2030 _NEW_GENERIC_BATTERY_STORAGE PlannedNew batte y_ca so_planned 50 50 50 0 NotHyb d Gene c 4 Hou Sto age 2028 NEW GENERIC BATTERY STORAGE PlannedNew batte y ca so planned 200 200 200 0 NotHyb d Gene c 4 Hou Sto age 2034 NEW GENERIC BATTERY STORAGE PlannedNew batte y ca so planned 200 200 200 0 NotHyb d Gene c CCGT RA_2023 _EXISTING_GENERIC_COMBINED_CYCLE PlannedEx st ng 750 750 750 0 NotHyb d Gene c CCGT RA 2024 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 686 686 686 0 NotHyb d Gene c CCGT RA 2025 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 639 639 639 0 NotHyb d Gene c CCGT RA 2026 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 731 731 731 0 NotHyb d Gene c CCGT RA 2027 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 672 672 672 0 NotHyb d Gene c CCGT RA_2028 _EXISTING_GENERIC_COMBINED_CYCLE PlannedEx st ng 498 498 498 0 NotHyb d Gene c CCGT RA 2029 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 535 535 535 0 NotHyb d Gene c CCGT RA 2030 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 425 425 425 0 NotHyb d Gene c CCGT RA_2031 _EXISTING_GENERIC_COMBINED_CYCLE PlannedEx st ng 518 518 518 0 NotHyb d Gene c CCGT RA 2032 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 542 542 542 0 NotHyb d Gene c CCGT RA 2033 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 530 530 530 0 NotHyb d Gene c CCGT RA_2034 _EXISTING_GENERIC_COMBINED_CYCLE PlannedEx st ng 541 541 541 0 NotHyb d Gene c CCGT RA 2035 EXISTING GENERIC COMBINED CYCLE PlannedEx st ng 549 549 549 0 NotHyb d RESI RA 2 NS MCE NEW GENERIC DR Rev ew d ca so planned 15 15 15 0 NotHyb d PGE Onl ne ccgt 1 EXISTING GENERIC COMBINED CYCLE Onl ne 44 44 0 NotHyb d PGE Onl ne ccgt 2 EXISTING GENERIC COMBINED CYCLE Onl ne 39 39 0 NotHyb d PGE_Onl ne_ccgt_3 _EXISTING_GENERIC_COMBINED_CYCLE Onl ne 61 61 0 NotHyb d PGE Onl ne chp EXISTING GENERIC COGEN Onl ne 4 4 0 NotHyb d PGE Onl ne chp 1 EXISTING GENERIC COGEN Onl ne 3 0 5 NotHyb d PGE_Onl ne_chp_2 _EXISTING_GENERIC_COGEN Onl ne 1 1 7 NotHyb d PGE Onl ne batte y EX STING GENER C BATTERY STORAGE Onl ne 23 23 0 NotHyb d PGE Development batte y 1 NEW GENERIC BATTERY STORAGE Development 6 5 0 NotHyb d PGE_Development_batte y_2 _NEW_GENERIC_BATTERY_STORAGE Development 0 0 0 NotHyb d Attachment C - 30 MMT RDT

un que_cont acts

lse_unique_contract_id
Ost om_MCE
Hay MCE
Geyse s MCE
L ncoln MCE
Voyage II MCE
WM_MCE
Antelope 2 MCE
Cooley I MCE
Cost Plus_MCE
Dese t Ha vest MCE
F eethy 1 MCE
F eethy 2_MCE
G eat Valley MCE
L ttle Bea 1 MCE
L ttle Bea 3 MCE
L ttle Bea 4 MCE
L ttle Bea 5_MCE
SR A po t MCE
Mustang MCE
Soscal Fe y Sola C_MCE
Soscal Fe y Sola D MCE
Ame can Canyon Sola A MCE
Ame can Canyon Sola B_MCE
Ame can Canyon Sola C MCE
S lve a Ranch A MCE
S lve a Ranch B_MCE
SR A po t 2 MCE
EO P oducts MCE
Oakley RV & Boat Sto age MCE
DRES Qua y 2.4 MCE
Co co an_MCE
Goose Lake MCE
Buck MCE
MCE Sola 1_8.5_MCE
MCE Sola 1 2.0 MCE
Ke n Tule PCC1 1 LT MCE
S lve a Ranch C_MCE
Lake He man PCC1 1 LT MCE
By on Sola PCC1 1 LT MCE
St auss PCC1 1 LT MCE
By on Sola PCC1 2 LT MCE
Haywo th_PCC1_1_LT_MCE
Fallon PCC1 1 LT MCE
RPCA PCC1 1 LT MCE
Napa_PCC1_1_LT_MCE
CMSA PCC1 2 LT MCE
EBCE PCC1 Sale 1 MCE
SJCE_PCC1_Sale_1_MCE
PCEA PCC1 Sale 1 MCE
Golden F elds PCC1 LT MCE
Ranch Se eno_PCC1_LT_MCE
CES Elect on Fa m PCC1 DAC 1 LT MCE
CES Elect on Fa m PCC1 DAC 2 LT MCE
Daggett PCC1 1 LT MCE
Ma sh Land ng LLC RA 1 BAF MCE
WELLHEAD_RA_3_POF_MCE
CALPINE RA 35 S F MCE
CALPINE RA 34 NS MCE
CALPINE_RA_44_NS_MCE
CALPINE RA 67 NS MCE
CALPINE RA 68 NSF MCE
ENERSPONSE_RA_2_SS_MCE
Hecate Sto age RA 2024
EBMUD B1 MCE
EBMUD B1 MCE
SENA CF 13 MCE
MSCG_CF_5_MCE
B ookf eld CF 4 MCE
TENASKA CF 2 MCE
POWEREX_CF_3_MCE
Powe ex CF 4 MCE
Powe ex CF 5 MCE
WAPA_BR_MCE
WAPA BR 2 MCE
GHG F ee A locat on
DR A locat on
OS22 New W nd 2026
Gene c LT W nd NM 2030
Gene c LT W nd_2033
Gene c LT Geothe mal 2030
MTR LDS 2026
VAMO_ST_B omass
VAMO ST Sola PV
VAMO ST W nd
VAMO ST Small Hyd o
VAMO ST Geothe mal
Gene c ST B omass
Gene c ST Sola
Gene c ST W nd
Gene c ST Small Hyd o
Gene c ST Geothe mal
Gene c ST La ge Hyd o/ACS
Gene c LDS_2030
Gene c 4 Hou Sto age 2028
Gene c 4 Hou Sto age 2034
Gene c CCGT RA_2023
Gene c CCGT RA 2024
Gene c CCGT RA 2025
Gene c CCGT RA 2026
Gene c CCGT RA 2027
Gene c CCGT RA_2028
Gene c CCGT RA 2029
Gene c CCGT RA 2030
Gene c CCGT RA_2031
Gene c CCGT RA 2032
Gene c CCGT RA 2033
Gene c CCGT RA_2034
Gene c CCGT RA 2035
RESI RA 2 NS MCE
PGE Onl ne ccgt 1
PGE Onl ne ccgt 2
PGE_Onl ne_ccgt_3
PGE Onl ne chp
PGE Onl ne chp 1
PGE_Onl ne_chp_2
PGE Onl ne batte y
PGE Development batte y 1
PGE_Development_batte y_2
total_generator_mw contracted_generator_mw total_storage_mw contracted_storage_mw solar_technology_sub_type storage_technology_sub_type total_storage_depth_mwh contracted_storage_depth_mwh viability_cod_reasonableness viabil ty_technical_feasibility viability_f nancing_sitecontrol resource_mix d1911016_vamo_ghgfree buy_sell_own 1Ax s
F xed
F xed
1Ax s
F xed
F xed
1Ax s
1Ax s
1Ax s
1Ax s
1Ax s
F xed
1Ax s
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
F xed
4 3 5
F xed
F xed
F xed
F xed 4 3 4
F xed
F xed Sell
F xed Sell
F xed Sell
100 100 92 92 1Ax s L 368 368 4 3 3
2 2 0 8 0 8 F xed L 3 2 3 2 4 3 3
F xed 4 3 3
F xed 4 3 3
110 110 60 60 1Ax s L 240 240 4 3 5
L 740 740 4 3 5
GHG f ee PCIA Buy
Buy
1 2 1
1 2 1
1 2 1
1 2 1
L 320 320 1 1 1
VAMO Buy
VAMO Buy
VAMO Buy
VAMO Buy
VAMO Buy
L 400 400 1 1 1
L 800 800 1 2 1
L 800 800 1 2 1
4 3 5
CAM
CAM
CAM
CAM
CAM
CAM
L 93.23439546 CAM
L 23.30859887 CAM
L 0.385368835 CAM
Attachment C - 30 MMT RDT

un que_cont acts

lse_unique_contract_id
Ost om_MCE
Hay MCE
Geyse s MCE
L ncoln MCE
Voyage II MCE
WM_MCE
Antelope 2 MCE
Cooley I MCE
Cost Plus_MCE
Dese t Ha vest MCE
F eethy 1 MCE
F eethy 2_MCE
G eat Valley MCE
L ttle Bea 1 MCE
L ttle Bea 3 MCE
L ttle Bea 4 MCE
L ttle Bea 5_MCE
SR A po t MCE
Mustang MCE
Soscal Fe y Sola C_MCE
Soscal Fe y Sola D MCE
Ame can Canyon Sola A MCE
Ame can Canyon Sola B_MCE
Ame can Canyon Sola C MCE
S lve a Ranch A MCE
S lve a Ranch B_MCE
SR A po t 2 MCE
EO P oducts MCE
Oakley RV & Boat Sto age MCE
DRES Qua y 2.4 MCE
Co co an_MCE
Goose Lake MCE
Buck MCE
MCE Sola 1_8.5_MCE
MCE Sola 1 2.0 MCE
Ke n Tule PCC1 1 LT MCE
S lve a Ranch C_MCE
Lake He man PCC1 1 LT MCE
By on Sola PCC1 1 LT MCE
St auss PCC1 1 LT MCE
By on Sola PCC1 2 LT MCE
Haywo th_PCC1_1_LT_MCE
Fallon PCC1 1 LT MCE
RPCA PCC1 1 LT MCE
Napa_PCC1_1_LT_MCE
CMSA PCC1 2 LT MCE
EBCE PCC1 Sale 1 MCE
SJCE_PCC1_Sale_1_MCE
PCEA PCC1 Sale 1 MCE
Golden F elds PCC1 LT MCE
Ranch Se eno_PCC1_LT_MCE
CES Elect on Fa m PCC1 DAC 1 LT MCE
CES Elect on Fa m PCC1 DAC 2 LT MCE
Daggett PCC1 1 LT MCE
Ma sh Land ng LLC RA 1 BAF MCE
WELLHEAD_RA_3_POF_MCE
CALPINE RA 35 S F MCE
CALPINE RA 34 NS MCE
CALPINE_RA_44_NS_MCE
CALPINE RA 67 NS MCE
CALPINE RA 68 NSF MCE
ENERSPONSE_RA_2_SS_MCE
Hecate Sto age RA 2024
EBMUD B1 MCE
EBMUD B1 MCE
SENA CF 13 MCE
MSCG_CF_5_MCE
B ookf eld CF 4 MCE
TENASKA CF 2 MCE
POWEREX_CF_3_MCE
Powe ex CF 4 MCE
Powe ex CF 5 MCE
WAPA_BR_MCE
WAPA BR 2 MCE
GHG F ee A locat on
DR A locat on
OS22 New W nd 2026
Gene c LT W nd NM 2030
Gene c LT W nd_2033
Gene c LT Geothe mal 2030
MTR LDS 2026
VAMO_ST_B omass
VAMO ST Sola PV
VAMO ST W nd
VAMO ST Small Hyd o
VAMO ST Geothe mal
Gene c ST B omass
Gene c ST Sola
Gene c ST W nd
Gene c ST Small Hyd o
Gene c ST Geothe mal
Gene c ST La ge Hyd o/ACS
Gene c LDS_2030
Gene c 4 Hou Sto age 2028
Gene c 4 Hou Sto age 2034
Gene c CCGT RA_2023
Gene c CCGT RA 2024
Gene c CCGT RA 2025
Gene c CCGT RA 2026
Gene c CCGT RA 2027
Gene c CCGT RA_2028
Gene c CCGT RA 2029
Gene c CCGT RA 2030
Gene c CCGT RA_2031
Gene c CCGT RA 2032
Gene c CCGT RA 2033
Gene c CCGT RA_2034
Gene c CCGT RA 2035
RESI RA 2 NS MCE
PGE Onl ne ccgt 1
PGE Onl ne ccgt 2
PGE_Onl ne_ccgt_3
PGE Onl ne chp
PGE Onl ne chp 1
PGE_Onl ne_chp_2
PGE Onl ne batte y
PGE Development batte y 1
PGE_Development_batte y_2
counterparty generator_supplier developer_name capacity_area capacity_sub_area cpuc_approval_ref county COD_year COD_month COD_day contract_start_date_year contract_start_date_month contract_start_date_day contract_end_date_year contract_end_date_month contract_end_date_day NA S e a YubaCounty 2013 7 1 2013 7 1 2031 6 30
NA PacGE SolanoCounty 2013 7 1 2013 7 1 2033 6 30
NA No thCoastNo thBay SonomaCounty 1980 1 1 2017 1 1 2026 12 31 NA S e a Place County 1985 1 1 2013 2 14 2033 2 13
NA SCE Ke nCounty 2018 12 29 2018 12 29 2030 12 28
NA No thCoastNo thBay No_sub_a ea Ma nCounty 2017 9 14 2017 9 14 2037 9 13 NA B gC eekVentu a LosAngelesCounty 2019 1 1 2019 1 1 2038 12 31 NA G eate Bay Ma nCounty 2017 7 5 2017 3 1 2037 2 28
NA G eate Bay Ma nCounty 2016 9 1 2016 9 1 2036 8 31
NA SCE R ve s deCounty 2020 12 17 2020 12 17 2040 12 16 NA G eate Bay Cont aCostaCount 2016 10 6 2016 10 6 2036 10 5 NA G eate Bay Cont aCostaCount 2016 10 6 2016 10 6 2036 10 5 NA G eate F esno F esnoCounty 2018 4 14 2018 4 14 2033 4 13 NA G eate F esno F esnoCounty 2020 12 10 2020 12 10 2040 12 9 NA G eate F esno F esnoCounty 2020 12 10 2020 12 10 2040 12 9 NA G eate F esno F esnoCounty 2020 12 10 2020 12 10 2040 12 9 NA G eate F esno F esnoCounty 2020 12 10 2020 12 10 2040 12 9 NA G eate Bay Ma nCounty 2012 10 23 2012 10 23 2032 10 22 NA G eate F esno K ngsCounty 2015 6 25 2015 6 25 2032 12 31 NA PacGE NapaCounty 2020 12 11 2020 8 30 2040 8 29
NA PacGE NapaCounty 2020 12 11 2020 8 30 2040 8 29
NA PacGE NapaCounty 2019 9 24 2019 9 1 2039 8 31
NA PacGE NapaCounty 2019 9 24 2019 9 1 2039 8 31
NA PacGE NapaCounty 2019 9 24 2019 9 1 2039 8 31
NA PacGE Ma nCounty 2021 3 30 2021 3 30 2041 3 29
NA PacGE Ma nCounty 2021 3 30 2021 3 30 2041 3 29
NA PacGE Ma nCounty 2020 8 28 2020 9 30 2040 9 29
NA G eate Bay Ma nCounty 2018 12 10 2018 12 10 2038 12 9 NA G eate Bay Cont aCostaCount 2018 7 23 2018 7 31 2038 7 30 NA G eate Bay Ma nCounty 2019 5 24 2019 5 14 2039 5 13
NA G eate F esno K ngsCounty 2015 5 22 2015 5 22 2040 4 30 NA G eate F esno K ngsCounty 2015 5 22 2015 5 22 2040 4 30 NA G eate Bay Ma nCounty 2015 5 22 2015 5 22 2040 4 30
NA G eate Bay No_sub_a ea Cont aCostaCount 2017 12 22 2017 12 22 2037 12 21 NA G eate Bay No sub a ea Cont aCostaCount 2017 12 22 2017 12 22 2037 12 21 NA PacGE Ke nCounty 2021 6 9 2021 7 5 2036 7 4
NA PacGE NapaCounty 2021 3 30 2021 3 30 2041 3 29
NA PacGE SolanoCounty 2021 9 14 2021 9 30 2041 9 29
NA PacGE Cont aCostaCount 2022 5 21 2022 5 21 20 2 5 20 BayWa RE PacGE No sub a ea SantaBa ba aCount
NA PacGE Cont aCostaCount 2021 12 10 2021 12 1 2041 11 30 NA PacGE Cont aCostaCount 2022 3 7 2021 10 1 2041 9 30
NA PacGE Ma nCounty 2022 4 4 2021 12 1 2041 11 30
RPCA Sola 3, LLC PacGE Cont aCostaCount 2022 11 30 2022 11 30 2042 11 29 NA PacGE NapaCounty 2022 4 13 2021 11 1 2041 10 31
NA G eate Bay Ma nCounty 2022 7 15 2022 7 16 2032 7 15
East Bay Commun ty Ene gy NA G eate F esno K ngsCounty 2015 5 22 2021 9 6 2024 12 31 San Jose Clean Ene gy NA G eate F esno K ngsCounty 2015 5 22 2021 11 1 2024 12 31 Pen nsula Clean Ene gy Autho ty NA G eate F esno K ngsCounty 2015 5 22 2022 1 17 2024 12 31 Clea way Ene gy G oup SCE No sub a ea Ke nCounty 2025 3 1 2025 3 1 2040 2 29 Ranch Se eno Clean Powe LLC PacGE Cont aCostaCount 2024 2 22 2024 2 22 2044 2 21 CES Elect on Fa m One, LLC PacGE F esnoCounty 2023 12 31 2023 12 31 2043 12 30 CES Elect on Fa m One, LLC PacGE F esnoCounty 2023 12 31 2023 12 31 2043 12 30 Clea way Ene gy G oup SCE No sub a ea SanBe na d noCoun 2023 8 28 2023 8 28 2038 8 27 NA G eate Bay Cont aCostaCount 2013 5 1 2023 5 1 2026 9 30 NA G eate F esno F esnoCounty 2001 1 1 2020 1 1 2030 12 31 NA S e a Sutte County 2002 12 23 2023 1 1 2024 12 31
NA BANC No sub a ea Sutte County 2001 7 1 2021 1 1 2023 12 31 NA PacGE Cal fo n a 2022 1 1 2028 12 31
NA PacGE Cal fo n a 2022 7 1 2030 12 31
NA PacGE Cal fo n a 2023 1 1 2030 12 31
NA PacGE Cal fo n a 2023 4 1 2025 12 31
Hecate G d SCE LosAngelesCounty 2024 4 1 2024 4 1 2034 3 31 NA Stockton SanJoaqu nCounty 1983 1 1 2015 7 1 2025 6 30 NA PacGE Calave asCounty 1930 1 1 2023 1 1 2024 12 31
NA PacGE Cal fo n a 2024 1 1 2024 12 31
NA PACW O egon 2021 1 1 2024 12 31
NA PACW O egon 2021 1 1 2024 12 31
NA S e a Place County 1966 1 1 2022 1 1 2024 12 31
NA PACW O egon 2023 1 1 2025 12 31
NA PACW O egon 2022 5 20 2025 12 31
NA PACW O egon 2023 1 1 2025 12 31
NA BANC Cal fo n a 2015 1 1 2024 12 31
NA BANC Cal fo n a 2025 1 1 2054 12 31
Pac f c Gas & Elect c NA PacGE Cal fo n a 2024 1 1 2043 12 31 Pac f c Gas & Elect c NA PacGE Cal fo n a 2023 1 1 2042 12 31 Unknown SCE Ke nCounty 2026 1 1 2026 1 1 2045 12 31
Unknown PacGE NewMex co 2030 1 1 2030 1 1 2049 12 31
Unknown PacGE Cal fo n a 2033 1 1 2033 1 1 2052 12 31
Unknown I D Impe alCounty 2030 1 1 2030 1 1 2049 12 31
Unknown PacGE Cont aCostaCount 2026 1 1 2026 1 1 2045 12 31 Pac f c Gas & Elect c NA PacGE Cal fo n a 2023 1 1 2024 12 31 Pac f c Gas & Elect c NA PacGE Cal fo n a 2023 1 1 2024 12 31 Pac f c Gas & Elect c NA PacGE Cal fo n a 2023 1 1 2024 12 31 Pac f c Gas & Elect c NA PacGE Cal fo n a 2023 1 1 2024 12 31 Pac f c Gas & Elect c NA PacGE Cal fo n a 2023 1 1 2024 12 31 NA PacGE Cal fo n a 2023 1 1 2042 12 31
NA PacGE Cal fo n a 2023 1 1 2042 12 31
NA PacGE Cal fo n a 2023 1 1 2042 12 31
NA PacGE Cal fo n a 2023 1 1 2042 12 31
NA PacGE Cal fo n a 2023 1 1 2042 12 31
NA PacGE Cal fo n a 2023 1 1 2042 12 31
Unknown PacGE Cont aCostaCount 2030 1 1 2030 1 1 2049 12 31 Unknown PacGE SolanoCounty 2028 1 1 2028 1 1 2047 12 31 Unknown PacGE NapaCounty 2034 1 1 2034 1 1 2053 12 31
NA PacGE Cal fo n a 2023 1 1 2023 12 31
NA PacGE Cal fo n a 2024 1 1 2024 12 31
NA PacGE Cal fo n a 2025 1 1 2025 12 31
NA PacGE Cal fo n a 2026 1 1 2026 12 31
NA PacGE Cal fo n a 2027 1 1 2027 12 31
NA PacGE Cal fo n a 2028 1 1 2028 12 31
NA PacGE Cal fo n a 2029 1 1 2029 12 31
NA PacGE Cal fo n a 2030 1 1 2030 12 31
NA PacGE Cal fo n a 2031 1 1 2031 12 31
NA PacGE Cal fo n a 2032 1 1 2032 12 31
NA PacGE Cal fo n a 2033 1 1 2033 12 31
NA PacGE Cal fo n a 2034 1 1 2034 12 31
NA PacGE Cal fo n a 2035 1 1 2035 12 31
Res Stat on, LLC PacGE Cal fo n a 2023 1 1 2023 1 1 2032 12 31 Pac f c Gas & Elect c 2018 1 1 2024 1 1 2026 12 31
Pac f c Gas & Elect c 2018 1 1 2024 1 1 2025 12 31
Pac f c Gas & Elect c 2018 1 1 2024 1 1 2024 12 31
Pac f c Gas & Elect c 2018 1 1 2024 1 1 2024 12 31
Pac f c Gas & Elect c 2018 1 1 2024 1 1 2025 12 31
Pac f c Gas & Elect c 2018 1 1 2024 1 1 2026 12 31
Pac f c Gas & Elect c 2018 1 1 2024 1 1 2035 12 31
Pac f c Gas & Elect c 2024 1 1 2025 1 1 2035 12 31
Pac f c Gas & Elect c 2024 1 1 2024 1 1 2035 12 31
Attachment C - 30 MMT RDT

un que_cont acts

lse_unique_contract_id
Ost om_MCE
Hay MCE
Geyse s MCE
L ncoln MCE
Voyage II MCE
WM_MCE
Antelope 2 MCE
Cooley I MCE
Cost Plus_MCE
Dese t Ha vest MCE
F eethy 1 MCE
F eethy 2_MCE
G eat Valley MCE
L ttle Bea 1 MCE
L ttle Bea 3 MCE
L ttle Bea 4 MCE
L ttle Bea 5_MCE
SR A po t MCE
Mustang MCE
Soscal Fe y Sola C_MCE
Soscal Fe y Sola D MCE
Ame can Canyon Sola A MCE
Ame can Canyon Sola B_MCE
Ame can Canyon Sola C MCE
S lve a Ranch A MCE
S lve a Ranch B_MCE
SR A po t 2 MCE
EO P oducts MCE
Oakley RV & Boat Sto age MCE
DRES Qua y 2.4 MCE
Co co an_MCE
Goose Lake MCE
Buck MCE
MCE Sola 1_8.5_MCE
MCE Sola 1 2.0 MCE
Ke n Tule PCC1 1 LT MCE
S lve a Ranch C_MCE
Lake He man PCC1 1 LT MCE
By on Sola PCC1 1 LT MCE
St auss PCC1 1 LT MCE
By on Sola PCC1 2 LT MCE
Haywo th_PCC1_1_LT_MCE
Fallon PCC1 1 LT MCE
RPCA PCC1 1 LT MCE
Napa_PCC1_1_LT_MCE
CMSA PCC1 2 LT MCE
EBCE PCC1 Sale 1 MCE
SJCE_PCC1_Sale_1_MCE
PCEA PCC1 Sale 1 MCE
Golden F elds PCC1 LT MCE
Ranch Se eno_PCC1_LT_MCE
CES Elect on Fa m PCC1 DAC 1 LT MCE
CES Elect on Fa m PCC1 DAC 2 LT MCE
Daggett PCC1 1 LT MCE
Ma sh Land ng LLC RA 1 BAF MCE
WELLHEAD_RA_3_POF_MCE
CALPINE RA 35 S F MCE
CALPINE RA 34 NS MCE
CALPINE_RA_44_NS_MCE
CALPINE RA 67 NS MCE
CALPINE RA 68 NSF MCE
ENERSPONSE_RA_2_SS_MCE
Hecate Sto age RA 2024
EBMUD B1 MCE
EBMUD B1 MCE
SENA CF 13 MCE
MSCG_CF_5_MCE
B ookf eld CF 4 MCE
TENASKA CF 2 MCE
POWEREX_CF_3_MCE
Powe ex CF 4 MCE
Powe ex CF 5 MCE
WAPA_BR_MCE
WAPA BR 2 MCE
GHG F ee A locat on
DR A locat on
OS22 New W nd 2026
Gene c LT W nd NM 2030
Gene c LT W nd_2033
Gene c LT Geothe mal 2030
MTR LDS 2026
VAMO_ST_B omass
VAMO ST Sola PV
VAMO ST W nd
VAMO ST Small Hyd o
VAMO ST Geothe mal
Gene c ST B omass
Gene c ST Sola
Gene c ST W nd
Gene c ST Small Hyd o
Gene c ST Geothe mal
Gene c ST La ge Hyd o/ACS
Gene c LDS_2030
Gene c 4 Hou Sto age 2028
Gene c 4 Hou Sto age 2034
Gene c CCGT RA_2023
Gene c CCGT RA 2024
Gene c CCGT RA 2025
Gene c CCGT RA 2026
Gene c CCGT RA 2027
Gene c CCGT RA_2028
Gene c CCGT RA 2029
Gene c CCGT RA 2030
Gene c CCGT RA_2031
Gene c CCGT RA 2032
Gene c CCGT RA 2033
Gene c CCGT RA_2034
Gene c CCGT RA 2035
RESI RA 2 NS MCE
PGE Onl ne ccgt 1
PGE Onl ne ccgt 2
PGE_Onl ne_ccgt_3
PGE Onl ne chp
PGE Onl ne chp 1
PGE_Onl ne_chp_2
PGE Onl ne batte y
PGE Development batte y 1
PGE_Development_batte y_2
contract_execution_date_year contract_execut on_date_month contract_execut on_date_day tx_upgrades tx_upgrade_date_year tx_upgrade_date_month tx_upgrade_date_day tx_upgrade_descript on d1911016_tranche d2106035_procurement_cat mtr_tranche1_NQC mtr_tranche2_NQC mtr_tranche3_NQC mtr_tranche4_NQC_LDES mtr_tranche4_NQC_firm_ZE mtr_NQC_ZE_gen_paired_dr previous_COD_year 2010 12 3 NA NA
2010 12 3 NA NA
2013 7 11 NA NA
2012 7 6 NA NA
2016 12 5 NA NA
2014 11 6 NA 3 NA 2017
2016 11 15 NA NA
2014 10 7 NA NA
2015 4 14 NA NA
2016 11 18 NA NA
2015 9 4 NA NA
2015 9 4 NA NA
2016 9 15 NA NA
2016 9 23 NA NA
2016 9 23 NA NA
2016 9 23 NA NA
2016 9 23 NA NA
2012 5 8 NA NA
2014 10 3 NA NA
2018 8 30 NA NA
2018 8 30 NA NA
2018 8 30 NA NA
2018 8 30 NA NA
2018 8 30 NA NA
2019 3 7 NA NA
2019 3 7 NA NA
2018 10 24 NA NA
2018 10 31 NA NA
2018 5 8 NA NA
2018 3 23 NA NA
2011 7 8 NA NA
2011 7 8 NA NA
2011 7 8 NA NA
2017 5 30 NA 3 NA 2017
2017 5 30 NA 3 NA 2017
2020 1 22 NA NA
2019 3 7 NA NA
2020 7 29 NA NA
2020 10 15 NA NA
2018 10 19 YES Completed 3 NA 2022
2020 12 11 NA NA
2021 3 8 NA NA
2021 4 5 NA NA
2021 3 29 NA NA
2021 4 14 NA NA
2021 7 16 NA NA
2021 9 6 NA NA
2021 11 1 NA NA
2021 11 29 NA NA
2022 2 4 YES 2024 10 1 NA gene al & ZE gen pa ed d 75 61.3 2022 2 23 NO NA NA
2022 3 20 NA NA
2022 3 20 NA NA
2020 9 25 YES NA gene al & ZE gen pa ed d 58 7.9 48.1 2022 2022 7 26 NA NA
2019 8 1 NA NA
NA NA
2020 2 28 NA 1&2 NA 2001
NA NA
NA NA
NA NA
NA NA
2022 8 4 NA gene al 167.795
2015 6 22 NA NA
2015 6 22 NA NA
2019 4 26 NA NA
2020 9 15 NA NA
2020 2 14 NA NA
2021 12 17 NA NA
2022 4 11 NA NA
2022 5 18 NA NA
2022 5 18 NA NA
2011 12 14 NA NA
2021 3 18 NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA long du at on sto age 31.28
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
NA NA
2022 8 31 NA 3
2017 1 1
2017 1 1
2017 1 1
2017 1 1
2017 1 1
2017 1 1
2017 1 1
2022 1 1
2022 1 1
Attachment C - 30 MMT RDT

un que_cont acts

lse_unique_contract_id
Ost om_MCE
Hay MCE
Geyse s MCE
L ncoln MCE
Voyage II MCE
WM_MCE
Antelope 2 MCE
Cooley I MCE
Cost Plus_MCE
Dese t Ha vest MCE
F eethy 1 MCE
F eethy 2_MCE
G eat Valley MCE
L ttle Bea 1 MCE
L ttle Bea 3 MCE
L ttle Bea 4 MCE
L ttle Bea 5_MCE
SR A po t MCE
Mustang MCE
Soscal Fe y Sola C_MCE
Soscal Fe y Sola D MCE
Ame can Canyon Sola A MCE
Ame can Canyon Sola B_MCE
Ame can Canyon Sola C MCE
S lve a Ranch A MCE
S lve a Ranch B_MCE
SR A po t 2 MCE
EO P oducts MCE
Oakley RV & Boat Sto age MCE
DRES Qua y 2.4 MCE
Co co an_MCE
Goose Lake MCE
Buck MCE
MCE Sola 1_8.5_MCE
MCE Sola 1 2.0 MCE
Ke n Tule PCC1 1 LT MCE
S lve a Ranch C_MCE
Lake He man PCC1 1 LT MCE
By on Sola PCC1 1 LT MCE
St auss PCC1 1 LT MCE
By on Sola PCC1 2 LT MCE
Haywo th_PCC1_1_LT_MCE
Fallon PCC1 1 LT MCE
RPCA PCC1 1 LT MCE
Napa_PCC1_1_LT_MCE
CMSA PCC1 2 LT MCE
EBCE PCC1 Sale 1 MCE
SJCE_PCC1_Sale_1_MCE
PCEA PCC1 Sale 1 MCE
Golden F elds PCC1 LT MCE
Ranch Se eno_PCC1_LT_MCE
CES Elect on Fa m PCC1 DAC 1 LT MCE
CES Elect on Fa m PCC1 DAC 2 LT MCE
Daggett PCC1 1 LT MCE
Ma sh Land ng LLC RA 1 BAF MCE
WELLHEAD_RA_3_POF_MCE
CALPINE RA 35 S F MCE
CALPINE RA 34 NS MCE
CALPINE_RA_44_NS_MCE
CALPINE RA 67 NS MCE
CALPINE RA 68 NSF MCE
ENERSPONSE_RA_2_SS_MCE
Hecate Sto age RA 2024
EBMUD B1 MCE
EBMUD B1 MCE
SENA CF 13 MCE
MSCG_CF_5_MCE
B ookf eld CF 4 MCE
TENASKA CF 2 MCE
POWEREX_CF_3_MCE
Powe ex CF 4 MCE
Powe ex CF 5 MCE
WAPA_BR_MCE
WAPA BR 2 MCE
GHG F ee A locat on
DR A locat on
OS22 New W nd 2026
Gene c LT W nd NM 2030
Gene c LT W nd_2033
Gene c LT Geothe mal 2030
MTR LDS 2026
VAMO_ST_B omass
VAMO ST Sola PV
VAMO ST W nd
VAMO ST Small Hyd o
VAMO ST Geothe mal
Gene c ST B omass
Gene c ST Sola
Gene c ST W nd
Gene c ST Small Hyd o
Gene c ST Geothe mal
Gene c ST La ge Hyd o/ACS
Gene c LDS_2030
Gene c 4 Hou Sto age 2028
Gene c 4 Hou Sto age 2034
Gene c CCGT RA_2023
Gene c CCGT RA 2024
Gene c CCGT RA 2025
Gene c CCGT RA 2026
Gene c CCGT RA 2027
Gene c CCGT RA_2028
Gene c CCGT RA 2029
Gene c CCGT RA 2030
Gene c CCGT RA_2031
Gene c CCGT RA 2032
Gene c CCGT RA 2033
Gene c CCGT RA_2034
Gene c CCGT RA 2035
RESI RA 2 NS MCE
PGE Onl ne ccgt 1
PGE Onl ne ccgt 2
PGE_Onl ne_ccgt_3
PGE Onl ne chp
PGE Onl ne chp 1
PGE_Onl ne_chp_2
PGE Onl ne batte y
PGE Development batte y 1
PGE_Development_batte y_2
prev ous_COD_month previous_COD_day remediat on_plan signed_contract notice_to_proceed public_contract buying_energy_capac ty NQC_reporting_source procurement_origin csp_resource_category csp_annual_2024 csp_annual_2026 csp_annual_2030 csp_annual_2035 macro_supertype notes YES Ene gyCapac ty Calculated RPS, RA B ogas (GWh) 12 12 12 0 phys cal YES Ene gyCapac ty Calculated RPS, RA B ogas (GWh) 11 11 11 0 phys cal YES Ene gyCapac ty Calculated RPS, RA Geothe mal (GWh) 88 88 0 0 phys cal YES Ene gyCapac ty Calculated RPS, RA B ogas (GWh) 27 27 27 0 phys cal YES Ene gyCapac ty Calculated RPS, RA W nd Ex st ng Cal fo n a GWh) 138 138 137 0 phys cal 9 14 NO YES NO s YES es u ce a c pable of e g ble D 1 11 0 6 s fo f D E gyCapa ty C lc ate RPS, R B gas GWh 30 0 0 3 MCE p ov executed cont act n ts Feb ua y 1, 2021 compl anc y cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 294 292 286 279 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 2 2 2 2 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 1 1 1 1 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 258 255 250 243 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 2 2 2 2 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 2 2 2 2 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 286 284 281 0 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 108 107 105 102 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 54 53 52 51 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 135 133 131 127 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 135 133 131 127 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 2 2 2 0 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 82 81 79 0 phys cal YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 2 2 2 0 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 1 1 0 0 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 2 2 2 2 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 1 1 0 0 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 28 28 27 26 phys cal YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 31 30 30 29 phys cal YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 2 1 ex st nggene c 12 22 NO YES NO s YES es u ce a c pable of e g ble ou c p .19 1 - 1 MCE s fo f D E gyCapa ty C lc ate RPS, R S l Ex st g l o a GWh) 17 7 7 1 MCE p ov executed cont act n ts Feb ua y 1, 2021 compl anc y cal 12 22 NO YES NO s YES En g Ca ac y e u e t capa l o e g e so p D. 1 16 MCE n o . C lc t d RPS RA S la E st Ca fo ( W ) 4 4 M E ov executed cont act n ts Feb ua y 1, 2021 compl anc h s al YES Ene gyCapac ty Calculated RPS, RA Sma l Hyd o (GWh) 37 37 37 37 phys cal YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c YES Ene gyCapac ty Calculated RPS, RA Sola Ex st ng Cal fo n a (GWh) 3 3 3 3 ex st nggene c h s u e s a c 7 g e 1 YES a co 1 6 MW f NQ tow d 19 1 0 6 e u v ded t e o t act a d 3) s gned land le e 1 co e D S p mp d t e Co med at on Plan and (2) a P oject T mel ne. In ts Feb YES YES a y n c a at on n e y a a t C lc t d RP , R W Ne PG E (GWh) 91 2 90 290 y l YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 8 8 8 8 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 2 2 2 2 ex st nggene c YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 2 2 2 2 ex st nggene c YES Yes, but p c ng and any f nanc al nfo mat on oEne gyCapac ty Calculated RPS, RA Sola D st buted (GWh) 14 14 14 13 newgene c Feed n ta ff YES Ene gyCapac ty Calculated RPS Sola Ex st ng Cal fo n a (GWh) 1 1 1 1 ex st nggene c YES Ene gyCapac ty Calculated RPS B omass (GWh) 4 4 4 0 ex st nggene c YES Ene gyOnly Calculated RPS Sola Ex st ng Cal fo n a (GWh) 8 0 0 0 phys cal YES Ene gyOnly Calculated RPS Sola Ex st ng Cal fo n a (GWh) 4 0 0 0 phys cal YES Ene gyOnly Calculated RPS Sola Ex st ng Cal fo n a (GWh) 10 0 0 0 phys cal YES Yes, but p c ng and any f nanc al nfo mat on o o e t e o te m- el e equ me t u D.2 0 . C te a xp c s t Ene y apa ty C lc ate RPS D.21-06- 35 o P e So an Batte (GWh) 0 l 7 a d 06 0 295 5 so e pe s count towa ds meet ng the subset of MCE's equ em n w n YES Yes, but p c ng and any f nanc al nfo mat on oEne gyCapac ty Calculated RPS, RA Sola D st buted (GWh) 5 5 5 5 newgene c Feed n ta ff YES Yes, but p c ng and any f nanc al nfo mat on oEne gyCapac ty Calculated RPS,RA Sola D st buted (GWh) 1 1 1 1 newgene c Feed n ta ff YES Yes, but p c ng and any f nanc al nfo mat on oEne gyCapac ty Calculated RPS Sola D st buted (GWh) 12 12 12 12 newgene c Feed n ta ff 12 31 NA YES Yes, but p c ng and any f nanc al nfo mat on oEne gyCapac ty o us h d-te m mpl ce q em t p u t to D. 1 06-0 e d so a p W of D.2 0 0 Cal lated RPS R Hy Pa S la a d tt G 328 32 319 31 n en c . MCE also expects th s esou ce to count towa ds me YES Capac tyOnly Calculated RA NA 0 0 0 0 phys cal
YES Capac tyOnly In the cont act RA NA 0 0 0 0 phys cal YES Capac tyOnly In the cont act RA NA 0 0 0 0 phys cal 7 1 NO YES NO YES o ew cont l g bl a em me t e D.1 1 t 5 D m C UC ex cu n ts Feb ua y 1, 2021 compl ance f l ng pe D.20-12- Cap c t O y th ont act D19 101 RA NA 0 0 s e ed m t YES Capac tyOnly In the cont act RA NA 0 0 0 0 ex st nggene c YES Capac tyOnly In the cont act RA NA 0 0 0 0 ex st nggene c YES Capac tyOnly In the cont act RA NA 0 0 0 0 ex st nggene c YES Capac tyOnly In the cont act RA NA 0 0 0 0 ex st nggene c YES Yes, but p c ng and any f nanc al nfo mat on Capac tyOnly Calculated D2106035 Batte y Sto age MWh Ene gy Capac ty) 555 n RA u c o 7 0 740 7 0 nety com l nt pu suant to D.21-06-035. MCE ntends and expect YES Ene gyOnly Calculated RPS Sma l Hyd o (GWh) 45.8 0 0 0 phys cal YES Ene gyOnly Calculated RPS Sma l Hyd o (GWh) 139 5 0 0 0 phys cal YES Ene gyOnly Calculated pol cy La ge Hyd o (GWh) 200 0 0 0 ex st nggene c YES Ene gyOnly Calculated pol cy Impo ted Hyd o (GWh) 400 0 0 0 ex st nggene c YES Ene gyOnly Calculated pol cy Impo ted Hyd o (GWh) 200 0 0 0 ex st nggene c YES Ene gyOnly Calculated pol cy La ge Hyd o (GWh) 120 0 0 0 phys cal YES Ene gyOnly Calculated pol cy Impo ted Hyd o (GWh) 250 0 0 0 ex st nggene c YES Ene gyOnly Calculated pol cy Impo ted Hyd o (GWh) 200 0 0 0 ex st nggene c YES Ene gyOnly Calculated pol cy Impo ted Hyd o (GWh) 100 0 0 0 ex st nggene c YES Ene gyOnly Calculated RPS La ge Hyd o (GWh) 25 0 0 0 ex st nggene c YES Ene gyOnly Calculated RPS La ge Hyd o (GWh) 0 25 25 25 ex st nggene c No Ene gyOnly Calculated allocat on La ge Hyd o (GWh) 500 500 500 500 ex st nggene c No Capac tyOnly In the cont act allocat on Shed DR MW) 0 0 0 0 ex st nggene c NA NO No Ene gyCapac ty Calculated RPS, RA W nd New SCE SDG&E (GWh) 0 263 263 263 newgene c Gene c NA NO No Ene gyCapac ty Calculated RPS, RA W nd New Mex co (GWh) 0 0 250 250 new esolve Gene c NA NO No Ene gyCapac ty Calculated RPS, RA W nd Offsho e Mo o Bay (GWh) 0 0 0 400 new esolve Gene c NA NO No Ene gyCapac ty Calculated RPS, RA Geothe mal (GWh) 0 0 580 580 newgene c Gene c NA NO No Ene gyCapac ty Calculated D2106035 Batte y Sto age MWh Ene gy Capac ty) 0 0 0 0 newgene c Gene c Yes Ene gyOnly Calculated allocat on B omass (GWh) 33 0 0 0 ex st nggene c Yes Ene gyOnly Calculated allocat on Sola Ex st ng Cal fo n a (GWh) 206 0 0 0 ex st nggene c Yes Ene gyOnly Calculated allocat on W nd Ex st ng Cal fo n a GWh) 165 0 0 0 ex st nggene c Yes Ene gyOnly Calculated allocat on Sma l Hyd o (GWh) 14 0 0 0 ex st nggene c Yes Ene gyOnly Calculated allocat on Geothe mal (GWh) 70 0 0 0 ex st nggene c No Ene gyOnly Calculated RPS B omass (GWh) 28 34 0 16 ex st nggene c No Ene gyOnly Calculated RPS Sola Ex st ng Cal fo n a (GWh) 138 171 0 79 ex st nggene c No Ene gyOnly Calculated RPS W nd Ex st ng Cal fo n a GWh) 303 558 214 374 ex st nggene c No Ene gyOnly Calculated RPS Sma l Hyd o (GWh) 55 69 0 32 ex st nggene c No Ene gyOnly Calculated RPS Geothe mal (GWh) 142 98 117 149 ex st nggene c No Ene gyOnly Calculated RPS Impo ted Hyd o (GWh) 0 766 69 120 ex st nggene c NA NO No Ene gyCapac ty Calculated RA Batte y Sto age MWh Ene gy Capac ty) 0 0 400 400 newgene c Gene c NA NO No Ene gyCapac ty Calculated RA Batte y Sto age MWh Ene gy Capac ty) 0 0 800 800 newgene c Gene c NA NO No Ene gyCapac ty Calculated RA Batte y Sto age MWh Ene gy Capac ty) 0 0 0 800 newgene c Gene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c No Capac tyOnly Calculated RA NA 0 0 0 0 ex st nggene c YES NO b any f nanc al nfo mat on Capac tyOnly In the cont act D1911016, RA Shed DR MW)T s c n 15 15 15 M es u e east 15 MW of nc emental NQC towa ds MCE's D 19 1 0 new e e Ene gyCapac ty NA 0 0 0 0
Ene gyCapac ty NA 0 0 0 0
Ene gyCapac ty NA 0 0 0 0
Ene gyCapac ty NA 0 0 0 0
Ene gyCapac ty NA 0 0 0 0
Ene gyCapac ty NA 0 0 0 0
Capac tyOnly Batte y Sto age MWh Ene gy Capac ty) 93.23439546 93.23439546 93.23439546 93.23439546 Capac tyOnly Batte y Sto age MWh Ene gy Capac ty) 23.30859887 23.30859887 23.30859887 23.30859887 Ene gyCapac ty Batte y Sto age MWh Ene gy Capac ty) 0.385368835 0 385368835 0 385368835 0 385368835 Attachment C - 30 MMT RDT

Calcs
resource contract_status contracted_nameplate_capacity is_hybrid_paired can_charge_from_grid contracted_generator_mw contracted_storage_mw contracted_storage_depth_mwh buy_sell_own contract_start_date_year contract_start_date_month contract_start_date_day contract_end_date_year WHEATL_6_LNDFIL Online 2 NotHybrid 0 0 0 0 0 2013 7 1 2031 PEABDY_2_LNDFIL Online 2 NotHybrid 0 0 0 0 0 2013 7 1 2033 GEYS13_7_UNIT13 Online 10 NotHybrid 0 0 0 0 0 2017 1 1 2026 PLSNTG_7_LNCLND Online 5 NotHybrid 0 0 0 0 0 2013 2 14 2033 VOYAGR_2_VOYWD3 Online 0 NotHybrid 0 0 0 0 0 2018 12 29 2030 NOVATO_6_LNDFL Online 4 NotHybrid 0 0 0 0 0 2017 9 14 2037 BGSKYN_2_AS2SR1 Online 105 NotHybrid 0 0 0 0 0 2019 1 1 2038 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2017 3 1 2037 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2016 9 1 2036 DSRTHV_2_DH1SR1 Online 80 NotHybrid 0 0 0 0 0 2020 12 17 2040 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2016 10 6 2036 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2016 10 6 2036 TRNQL8_2_ROJSR1 Online 100 NotHybrid 0 0 0 0 0 2018 4 14 2033 LTBERA 1 LB1SR1 Online 40 NotHybrid 0 0 0 0 0 2020 12 10 2040 LTBEAR 1 LB3SR3 Online 20 NotHybrid 0 0 0 0 0 2020 12 10 2040 LTBEAR 1 LB4SR4 Online 50 NotHybrid 0 0 0 0 0 2020 12 10 2040 LTBEAR 1 LB4SR5 Online 50 NotHybrid 0 0 0 0 0 2020 12 10 2040 EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2012 10 23 2032 MSTANG 2 SOLAR4 Online 30 NotHybrid 0 0 0 0 0 2015 6 25 2032 EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2020 8 30 2040 EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2020 8 30 2040 EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2019 9 1 2039 EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2019 9 1 2039 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2019 9 1 2039 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2021 3 30 2041 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2021 3 30 2041 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2020 9 30 2040 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2018 12 10 2038 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2018 7 31 2038 _EXISTING_GENERIC_SOLAR_FIXED Online 0 NotHybrid 0 0 0 0 0 2019 5 14 2039 CORCAN_1_SOLAR2 Online 11 NotHybrid 0 0 0 0 0 2015 5 22 2040 GOOSLK_1_SOLAR1 Online 12 NotHybrid 0 0 0 0 0 2015 5 22 2040 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2015 5 22 2040 RICHMN_1_CHVSR2 Online 9 NotHybrid 0 0 0 0 0 2017 12 22 2037 RICHMN_1_SOLAR Online 2 NotHybrid 0 0 0 0 0 2017 12 22 2037 KRNCNY_6_UNIT Online 11 NotHybrid 0 0 0 0 0 2021 7 5 2036 _EXISTING_GENERIC_SOLAR_FIXED Online 1 NotHybrid 0 0 0 0 0 2021 3 30 2041 _EXISTING_GENERIC_SOLAR_FIXED Online 5 NotHybrid 0 0 0 0 0 2021 9 30 2041 EXISTING GENERIC SOLAR FIXED Online 3 NotHybrid 0 0 0 0 0 2022 5 21 2042 STRAUSSWIND Development 91 NotHybrid 0 0 0 0 0
EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2021 12 1 2041 EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2021 10 1 2041 EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2021 12 1 2041 NEW GENERIC SOLAR FIXED Development 5 NotHybrid 0 0 0 0 0 2022 11 30 2042 EXISTING GENERIC SOLAR FIXED Online 1 NotHybrid 0 0 0 0 0 2021 11 1 2041 EXISTING GENERIC BIOMASS/WOOD Online 1 NotHybrid 0 0 0 0 0 2022 7 16 2032 GOOSLK 1 SOLAR1 Online 0 NotHybrid 0 0 0 0 Sell 2021 9 6 2024 CORCAN 1 SOLAR2 Online 0 NotHybrid 0 0 0 0 Sell 2021 11 1 2024 GOOSLK_1_SOLAR1 Online 0 NotHybrid 0 0 0 0 Sell 2022 1 17 2024 _NEW_GENERIC_SOLAR_1AXIS Development 100 NewSolarNewStorage NO 100 92 368 0 2025 3 1 2040 _NEW_GENERIC_SOLAR_1AXIS Development 2 NewSolarNewStorage NO 2 0.8 3.2 0 2024 2 22 2044 _NEW_GENERIC_SOLAR_1AXIS Development 0 NotHybrid 0 0 0 0 0 2023 12 31 2043 _NEW_GENERIC_SOLAR_1AXIS Development 4 NotHybrid 0 0 0 0 0 2023 12 31 2043 _NEW_GENERIC_SOLAR_1AXIS Development 110 NewSolarNewStorage NO 110 60 240 0 2023 8 28 2038 COCOPP_2_CTG4 Online 81 NotHybrid 0 0 0 0 0 2023 5 1 2026 AGRICO_7_UNIT Online 50 NotHybrid 0 0 0 0 0 2020 1 1 2030 BOGUE_1_UNITA1 Online 32 NotHybrid 0 0 0 0 0 2023 1 1 2024 SUTTER_2_CISO Online 70 NotHybrid 0 0 0 0 0 2021 1 1 2023 _EXISTING_GENERIC_COMBINED_CYCLE Online 25 NotHybrid 0 0 0 0 0 2022 1 1 2028 _EXISTING_GENERIC_COMBINED_CYCLE Online 15 NotHybrid 0 0 0 0 0 2022 7 1 2030 _EXISTING_GENERIC_COMBINED_CYCLE Online 15 NotHybrid 0 0 0 0 0 2023 1 1 2030 _EXISTING_GENERIC_DR Online 20 NotHybrid 0 0 0 0 0 2023 4 1 2025 _NEW_GENERIC_BATTERY_STORAGE Development 185 NotHybrid 0 0 0 740 0 2024 4 1 2034 CAMCHE 1 PL1X3 Online 0 NotHybrid 0 0 0 0 0 2015 7 1 2025 PARDEB 6 UNITS Online 0 NotHybrid 0 0 0 0 0 2023 1 1 2024 EXISTING GENERIC INSTATE LARGE H Online 0 NotHybrid 0 0 0 0 0 2024 1 1 2024 EXISTING GENERIC NW HYDRO Online 0 NotHybrid 0 0 0 0 0 2021 1 1 2024 EXISTING GENERIC NW HYDRO Online 0 NotHybrid 0 0 0 0 0 2021 1 1 2024 EXCHEC 7 UNIT 1 Online 0 NotHybrid 0 0 0 0 0 2022 1 1 2024 EXISTING GENERIC NW HYDRO Online 0 NotHybrid 0 0 0 0 0 2023 1 1 2025 EXISTING GENERIC NW HYDRO Online 0 NotHybrid 0 0 0 0 0 2022 5 20 2025 EXISTING GENERIC NW HYDRO Online 0 NotHybrid 0 0 0 0 0 2023 1 1 2025 EXISTING GENERIC INSTATE LARGE H Online 0 NotHybrid 0 0 0 0 0 2015 1 1 2024 _EXISTING_GENERIC_INSTATE_LARGE_H Online 0 NotHybrid 0 0 0 0 0 2025 1 1 2054 _EXISTING_GENERIC_INSTATE_LARGE_H PlannedExisting 0 NotHybrid 0 0 0 0 Buy 2024 1 1 2043 EXISTING GENERIC DR Online 0 NotHybrid 0 0 0 0 Buy 2023 1 1 2042 _NEW_GENERIC_WIND PlannedNew 100 NotHybrid 0 0 0 0 0 2026 1 1 2045 _CREZ_GENERIC_NEW_MEXICO_WIND PlannedNew 70 NotHybrid 0 0 0 0 0 2030 1 1 2049 _CREZ_GENERIC_MORRO_BAY_OFFSHOR PlannedNew 95 NotHybrid 0 0 0 0 0 2033 1 1 2052 _NEW_GENERIC_GEOTHERMAL PlannedNew 75 NotHybrid 0 0 0 0 0 2030 1 1 2049 _NEW_GENERIC_BATTERY_STORAGE PlannedNew 40 NotHybrid 0 0 0 320 0 2026 1 1 2045 _EXISTING_GENERIC_BIOMASS/WOOD Online 0 NotHybrid 0 0 0 0 Buy 2023 1 1 2024 _EXISTING_GENERIC_SOLAR_FIXED Online 0 NotHybrid 0 0 0 0 Buy 2023 1 1 2024 EXISTING GENERIC WIND Online 0 NotHybrid 0 0 0 0 Buy 2023 1 1 2024 EXISTING GENERIC INSTATE SMALL H Online 0 NotHybrid 0 0 0 0 Buy 2023 1 1 2024 EXISTING GENERIC GEOTHERMAL Online 0 NotHybrid 0 0 0 0 Buy 2023 1 1 2024 EXISTING GENERIC BIOMASS/WOOD PlannedExisting 0 NotHybrid 0 0 0 0 0 2023 1 1 2042 EXISTING GENERIC SOLAR FIXED PlannedExisting 0 NotHybrid 0 0 0 0 0 2023 1 1 2042 EXISTING GENERIC WIND PlannedExisting 0 NotHybrid 0 0 0 0 0 2023 1 1 2042 EXISTING GENERIC INSTATE SMALL H PlannedExisting 0 NotHybrid 0 0 0 0 0 2023 1 1 2042 EXISTING GENERIC GEOTHERMAL PlannedExisting 0 NotHybrid 0 0 0 0 0 2023 1 1 2042 EXISTING GENERIC NW HYDRO PlannedExisting 0 NotHybrid 0 0 0 0 0 2023 1 1 2042 NEW GENERIC BATTERY STORAGE PlannedNew 50 NotHybrid 0 0 0 400 0 2030 1 1 2049 Attachment C - 30 MMT RDT