This bill requires the Department of Water Resources (DWR) to procure eligible renewable energy and zero‑carbon resources to meet the electricity obligations of the State Water Resources Development System under Public Utilities Code section 454.53. It adds eligibility and geographic constraints for new purchases, permits behind‑the‑meter installations on State Water Project property, and builds in limited timing flexibility to avoid economically harmful early termination of pre‑2010 fossil contracts.
Beyond procurement rules, the measure prescribes cost‑mitigation steps — coordinating with the California Infrastructure and Economic Development Bank, pursuing incentives, and optionally taking ownership stakes — and sets financial handling rules for federal Inflation Reduction Act direct payments (deposit to a state bond account plus legislative notice). It also requires retirement of renewable energy credits used to meet the obligation and mandates multicraft project labor agreements for new generation facilities the department contracts with.
At a Glance
What It Does
Mandates that DWR procure eligible renewable and zero‑carbon electricity to satisfy State Water Project obligations, allows limited deferral tied to legacy fossil contracts or extraordinary events (but not later than Dec 31, 2040), and requires that post‑2022 resources be new or incremental and physically tied to California. It also prioritizes on‑site (behind‑the‑meter) options and requires retirement of associated RECs.
Who It Affects
Directly affects the Department of Water Resources, developers and owners of generation projects bidding to serve the State Water Project, local publicly owned utilities that build incremental resources for sale, the California Infrastructure and Economic Development Bank, and construction labor markets due to the project labor agreement mandate.
Why It Matters
It transforms how a major state water infrastructure operator sources electricity by codifying in‑state and vintage requirements, reallocating certain federal tax credit receipts to a state bond account, and imposing labor and REC constraints that will influence project finance, siting, and bid competitiveness.
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What This Bill Actually Does
The bill directs the Department of Water Resources to buy eligible renewable energy and zero‑carbon generation to meet the State Water Project’s statutory electricity obligations. If meeting those obligations would force early termination of an existing fossil‑fuel contract signed before 2010 and doing so would cause substantial uneconomic costs, the department may delay procuring replacement zero‑carbon energy equal to the contracted amount — but only up to December 31, 2040.
The Governor can move that compliance deadline earlier if catastrophic or extraordinary events make the statutory deadline infeasible, but may not extend it past 2040.
To expand options, the measure lets DWR meet part or all of its obligation by installing or connecting generation behind the meter on State Water Project properties so long as those resources satisfy the bill’s eligibility rules. For any procurement made after February 1, 2022, the bill requires resources to be newly developed or to represent incremental output from existing facilities and to reach commercial operation on or after January 1, 2023.
It also restricts eligible facilities to those located in California or those whose first point of interconnection is to a California balancing authority, which narrows the geographic market for bids.When evaluating procurements, DWR must weigh job creation, economic development, resource attributes (including resource adequacy and flexibility), and Public Utilities Commission integrated resource planning results, along with portfolio diversity and typical peak hours. The bill directs the department to pursue cost‑reducing measures such as low‑cost financing coordination with the Infrastructure Bank, tapping existing state incentives, and where advantageous, securing ownership stakes or royalties in projects.
If DWR elects direct payment of federal Inflation Reduction Act credits, those payments go into the California Water Resources Development Bond Account and DWR must notify the Joint Legislative Budget Committee within 10 days of deposit.Practically, procured generation must serve DWR’s load first; starting January 1, 2036, any year’s excess can be carried forward to future compliance obligations but only after all environmental and renewable attributes are retired. The bill explicitly requires retirement of renewable energy credits associated with electricity used to satisfy the obligation so those RECs cannot be resold.
Finally, DWR can contract with a new generation facility only if the seller requires contractors to use a multicraft project labor agreement conforming to prevailing industry standards, including provisions for high‑voltage transmission work.
The Five Things You Need to Know
The department may defer replacing electricity from pre‑2010 fossil contracts if early termination would cause significant uneconomic costs, but the deferral cannot extend past December 31, 2040.
Resources contracted after February 1, 2022 must be newly developed or represent incremental production and reach commercial operation on or after January 1, 2023.
Eligible facilities must be located in California or have their first point of interconnection to a California balancing authority.
If the department elects direct payment of Inflation Reduction Act credits, those payments must be deposited into the California Water Resources Development Bond Account and DWR must notify the Joint Legislative Budget Committee within 10 days.
DWR may only contract with a new generation facility whose seller requires contractors to work under a multicraft project labor agreement consistent with Section 2500(b)(1) of the Public Contract Code.
Section-by-Section Breakdown
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Primary procurement mandate and timing flexibility
This subsection obligates the department to procure eligible renewable and zero‑carbon resources to meet the State Water Project’s statutory supply of clean electricity. It creates two timing flexibilities: a narrow contractual deferral for certain legacy fossil contracts executed before 2010 where early termination would be uneconomic, and a Governor‑level authority to advance the compliance date earlier if extraordinary circumstances make the statutory schedule infeasible. Both flexibilities are bounded by a hard deadline of December 31, 2040.
Behind‑the‑meter procurement option
Allows the department to meet some or all of the obligation by installing or connecting zero‑carbon or renewable resources on State Water Project property to serve its load directly. This creates a distinct procurement pathway that can avoid market purchases, but it imports practical constraints around site availability, interconnection capacity, and operations.
Eligibility: vintage and location requirements
Sets clear eligibility caps for resources procured after Feb 1, 2022: they must be newly developed via DWR contracting or be genuine incremental output and reach commercial operations on or after Jan 1, 2023. It also requires facilities to be in California or to first interconnect to a California balancing authority, limiting the pool of supply to resources effectively delivering into the California grid.
Procurement evaluation criteria
Directs DWR to consider economic development and employment impacts, operational attributes (resource adequacy, flexibility, firming capability), CPUC integrated resource planning outputs, and portfolio diversity when selecting resources. That directs the department to balance short‑term price signals with longer‑term system needs and local benefits when scoring proposals.
Cost reduction tools, ownership stakes, and IRA credit handling
Encourages coordination with the California Infrastructure and Economic Development Bank for financing, with other agencies for incentives, and permits securing ownership stakes or royalties to capture incremental value. Importantly, if DWR takes direct payment of federal tax credits, the bill requires depositing those receipts into the California Water Resources Development Bond Account and sending a written notice to the Joint Legislative Budget Committee within 10 days, creating a traceable state revenue flow.
Usage priority, REC retirement, and excess procurement rules
Requires procured resources to serve DWR load first and mandates retirement of any renewable energy credit associated with electricity used to meet the obligation (no resale). From Jan 1, 2036, excess procurement above 100% of annual retail sales (with retired attributes) may be carried forward to meet future obligations, which shapes how DWR may overprocure in earlier years to hedge future needs.
Project labor agreement requirement
Conditions DWR’s contracts for new generation on sellers’ requirement that contractors use a multicraft project labor agreement defined under Public Contract Code Section 2500(b)(1), and insists those agreements align with recent industry standard agreements (including side letters for transmission work). This binds project developers to unionized labor terms as a contract prerequisite.
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Explore Energy in Codify Search →Who Benefits and Who Bears the Cost
Every bill creates winners and losers. Here's who stands to gain and who bears the cost.
Who Benefits
- Department of Water Resources — gains statutory clarity and multiple procurement pathways (market purchases and behind‑the‑meter) to meet its electricity obligations while retaining limited tools to avoid economically damaging contract breakage.
- California clean energy developers and in‑state renewable projects — receive a predictable buyer that favors new or incremental in‑state capacity and may access financing or incentives funneled through state coordination efforts.
- Construction and local workforces — stand to gain jobs from the bill’s explicit emphasis on maximum long‑term employment and the multicraft project labor agreement requirement, which channels work to organized labor and may raise local hiring.
- California grid and air quality — benefit from more zero‑carbon generation physically tied to the state balancing authority, potentially reducing local emissions and integrating more clean capacity into the grid.
Who Bears the Cost
- Owners of legacy fossil contracts and associated ratepayers — face the risk that uneconomic contract terminations could produce stranded costs (the bill mitigates but does not eliminate that risk), and earlier retirements could shift financial burdens.
- Project developers and bidders — must locate facilities in California or first interconnect to a California balancing authority and meet vintage/commercial‑operation thresholds, narrowing eligible projects and possibly raising development cost.
- Developers and owners of new generation — will need to comply with multicraft project labor agreements, which can increase construction costs and affect competitive dynamics among bidders.
- State budget and administrative units — will carry oversight tasks: coordinating financing and incentives, processing IRA direct payments into a bond account, and providing timely legislative notice, adding administrative workload and potential fiscal reporting requirements.
- Potential off‑state renewable suppliers — lost sales opportunities because the bill prioritizes in‑state or California‑interconnected resources, shrinking the market for out‑of‑state capacity that could be lower cost.
Key Issues
The Core Tension
The central trade‑off is between accelerating in‑state, verifiable clean electricity to decarbonize a large public operator quickly and preserving flexible, cost‑effective procurement that minimizes stranded costs and keeps projects financeable; the bill favors environmental integrity and local economic benefits, but those priorities can raise prices and constrain the pool of viable suppliers.
The bill stitches together climate, labor, and fiscal rules in a way that shifts risk across parties but leaves several practical questions open. Requiring new or incremental in‑state resources and retiring the associated RECs strengthens environmental integrity but reduces the number of projects that can competitively bid, which could increase procurement costs.
Similarly, mandating multicraft project labor agreements improves job quality and local economic impact but can raise construction bids and deter nonunion or out‑of‑state firms, affecting project finance and timing.
Key implementation ambiguities remain. The statute allows deferral where early termination of pre‑2010 contracts would cause “significant uneconomic costs” but does not define the metric for that determination or the process for calculating compensation or mitigation.
The Governor’s authority to set an “earliest feasible date” under catastrophic circumstances also invites interpretation: agencies will need procedural guardrails to avoid ad hoc extensions or premature deadlines. Finally, directing IRA direct‑payment proceeds to a state bond account creates an administrative pipeline that may run up against federal requirements for credit assignment, and the value of foregoing tradable RECs will change project underwriting and revenue models in ways that could reduce private capital appetite without explicit replacement revenue streams.
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