Distressed Energy and Power Deals: Renewables and Conventional Opportunities

Distressed Energy Deals: A Practical 2025 Playbook

Distressed energy and power deals involve buying debt or equity in projects or companies that cannot meet obligations without new capital. Renewables here means solar, wind, and storage assets; conventional means gas, coal, and midstream. The mechanics are straightforward in concept: identify who holds the keys across lenders, tax equity, offtakers, independent system operators, and regulators, map consents, and follow how cash actually moves through the structure. The payoff for buyers is speed, optionality, and basis-adjusted returns if you can close with certainty.

Where stress is surfacing now

Higher base rates have lifted the cost of capital across project finance and exposed tight structures. With the federal funds rate holding at a 5.25% to 5.50% target range since mid 2023, cushions eroded and equity marks fell as discount rates reset. Projects financed with 2020 to 2021 cost assumptions and optimistic curtailment views are missing debt service coverage ratios at current grid conditions. Until rate cuts or refinancing windows reopen, pressure persists and outcomes hinge on deal-by-deal consent paths.

Grid congestion and curtailment are crimping cash flows in high penetration markets. In California, renewable curtailment has been significant during midday hours, pushing down realized capture rates and stressing hedges that assumed firmer shapes. The practical impact is lower net revenue and lumpier settlements that make liquidity management harder.

Capacity market repricing is giving many conventional assets a lifeline. PJM’s 2025 to 2026 auction cleared about $270 per MW-day across the RTO, a material uplift for gas-fired peakers and combined-cycle units with accreditation. In plain terms, lenders and buyers can often underwrite interest coverage on capacity payments alone, with higher certainty where accreditation is clear.

The tax credit transfer market is active but not smooth. More than $9 billion in clean energy credits changed hands by early 2024, frequently at discounts to face value to compensate for counterparty and documentation risk. Construction budgets that assume timely transfer proceeds face squeezes when registrations lag. Rescue capital can earn attractive all-in yields for bridging notice-to-proceed and energization milestones, but execution discipline is essential.

Policy risk is reshaping the useful life of conventional assets. The Environmental Protection Agency’s 2024 standards impose stringent controls on new baseload gas and extend obligations on coal units. Owners must choose retrofit or early retirement and price noncompliance risk, which introduces large capital outlays and schedule risk into underwriting.

Storage revenue variance is real and immediate. As deployments rise, spreads compress and ancillary services saturate in ERCOT and CAISO. Scarcity adders and accreditation drive the forward view. Merchant storage without hedges is among the first to miss debt service in volatile weeks, which emphasizes the need for tolling or resource-adequacy value.

Valuation and cash drivers that matter

Low levelized cost of energy does not guarantee solvency when financing, interconnection, and congestion drive outcomes. Lazard’s 2024 analysis places solar and wind at the low end of the cost curve, yet realized returns depend on spreads, curtailment, and the capital stack. The bottom line is simple: cheap energy can still miss covenants if the cash waterfall starves junior claims under downside scenarios.

Entry paths into distress and when to use them

Section 363 sales: Acquire projects or assets free and clear, pay cure costs, and run PPA and ISO consents in parallel. Stalking horse terms and DIP-to-exit structures shape the field. Expect clean title and court oversight, but the calendar follows both the court and consent timelines. See an overview of Section 363 sales for mechanics and common steps.
Out-of-court amend-and-extend: Lenders trade maturity relief and covenant resets for fees, sweeps, and collateral. Sponsors often add modest equity to protect tax positions. Closing is faster, but residual leverage can remain heavy.
Article 9 foreclosures: Collateral agents take HoldCo equity after back leverage defaults. Buyers inherit tax equity and project debt terms and must fund cure payments. Entry price is lower, complexity higher.
Consent-driven asset sales: Parents monetize noncore assets or minority stakes. Tax equity, PPA, and lenders set consent conditions and may require guarantees or reserve funding. Strategics with balance sheets have an edge.
Rescue capital: HoldCo PIK, superpriority DIPs, vendor take-back paper, and bridge facilities plug transfer delays or interconnection funding gaps. These earn high all-in yields with strong covenants and quick deployment. In bankruptcy auctions, stalking horse bids can also secure breakup fees and bid protections.

As a practical note, credit investors can enhance options by preparing a credit bid play if their claims are unimpaired and the collateral value supports it. Where the business is viable, a going concern sale should remain the base case. For company-level fixes, compare paths in distressed M&A versus secured loan or asset sales.

Structures, consents, and flow of funds you must master

Most projects sit in Delaware LLCs with separateness covenants. Project lenders hold all-asset liens and HoldCo pledges, with account control agreements and, in ERCOT and CAISO, ISO collateral hooks. Documents typically follow New York law. Conventional assets often live in corporate stacks with mortgages and assignment of material contracts.

True-sale tax equity with substance generally stands up in bankruptcy. Partnership flips allocate cash and tax attributes to tax equity until a target internal rate of return or target date. Back leverage sits behind tax equity distributions and is subject to forbearance and standstill provisions. Read the cash waterfall before you model recovery because priority distributions and reserves dictate where value breaks.

Cash waterfalls drive outcomes and usually follow this order:

Operating costs: O&M, taxes, insurance, and ISO fees pay first.
Senior obligations: Senior secured debt and hedge settlements follow.
Reserves: Debt service, major maintenance, and negotiated curtailment or basis risk reserves build.
Tax equity: Priority distributions flow through the flip.
Back leverage: Interest and required amortization are serviced.
Sponsor: Distributions arrive last and only if all triggers are clear.

Common triggers include DSCR and LLCR sweeps, PPA termination events, interconnection suspensions, and prolonged force majeure. Hedge structures matter. Fixed volume swaps and virtual PPAs can invert economics if generation or nodal pricing deviates from the assumed shape. Basis between node and hub can dominate results. ISO collateral calls rise in volatile weeks and must be funded quickly because settlements run daily. Build this into liquidity plans from day one.

Consent rights are decisive and not fungible across deals:

Tax equity: Control changes, new debt, material amendments, O&M changes, and cure or replacement rights.
Lenders: Approval over material contracts, hedges, and change-in-law settlements, plus intercreditor standstills and replacement rights.
Offtakers: Consent for PPA assignment or project interest transfers. Affiliate transfers can help but rarely bypass change-of-control clauses.
ISOs: Novation or re-registration for market participation and collateral. Bankruptcy timetables must accommodate ISO approvals.

Prepare your document map early. Include credit agreements and security packages, tax equity partnership and LLC agreements, intercreditor and forbearance documents, ISDA schedules and confirmations for hedges, and project agreements like PPA, interconnection, EPC, O&M, LTSA, land, and permits. Add bankruptcy items such as DIP and sale orders, cure schedules, and adequate assurance packages. Stand up a secure virtual data room with SCADA and ISO settlements during week one to accelerate diligence.

Economics, fee stack, and a quick math check

Distressed buyers earn by buying basis-adjusted yield, fixing contracts, and leveraging platform synergies. DIPs are pricing at double-digit all-in yields against current base rates, often with original issue discount and exit fees. Rights offering backstops and plan sponsor fees can deliver low to mid single-digit fees for credible parties.

Tax credit transfer discounts are a lever in construction rescues. Discounts compensate buyers for registration, enforceability, and indemnity risk. Forward sale agreements can bridge overruns, but delays require real cash cushions. On operating assets, O&M resets add value when you rebid LTSAs, rationalize inventory, and tighten costs without harming reliability. Additional upside comes from basis hedges and curtailment tools. Capacity and ancillary rule changes can re-rate assets quickly, and PJM’s recent clearing price is a live example.

Consider the math. A 200 MW gas peaker with 180 MW UCAP at $270 per MW-day generates about $17.7 million of capacity revenue. If fixed O&M is $12 million and energy margins cover variable costs, capacity alone can cover interest on a $120 million term loan at 10% and minimal capex. If accreditation falls or penalties bite, the math reverses. Always model both cases and include sensitivity to penalties and derates.

Accounting, tax, and reporting checkpoints

Under ASC 810, most project SPVs are variable interest entities. Sponsors consolidate when they control significant activities or absorb most expected losses. Back leverage lenders typically do not consolidate. Tax equity may qualify for proportional amortization under ASU 2023-02, which better aligns recognition with the economics of tax benefits.

Sections 6417 and 6418 tax credits require registration and robust documentation. Sellers may treat proceeds as income or a basis reduction depending on policy and auditor guidance. Buyers record a deferred tax asset or reduce tax expense when credits are applied. ASU 2023-09 raises the bar for income tax disclosures, so plan for expanded notes.

Acquired distressed debt is measured at fair value under ASC 820. Use probability-weighted cash flows that reflect court versus out-of-court paths and net out cure and consent costs. For long-lived assets, ASC 360 impairment triggers when curtailment or compliance costs materially reduce expected cash flows. Calibrate your write-downs to objective evidence rather than optimistic case narratives.

Regulatory approvals and timing risk

FERC Section 203 approvals can add months and bring data requests on market power and affiliate rules. Hart-Scott-Rodino thresholds may trigger filings, and second request risk must be priced. CFIUS can be relevant for sensitive sites or foreign capital, and mitigation can alter operations. ISO participation and credit rules require careful coordination to avoid triggering defaults during ownership changes. Plan sequencing so the slowest consent sets the critical path.

Risks you must model, not just list

Hedge misalignment: Fixed-shape hedges against variable output can invert economics when weather or outages hit.
Congestion and basis: Negative node-to-hub basis in congested zones can dominate project results and wipe out merchant upside.
Interconnection: Upgrade costs and queue delays can reallocate costs from withdrawals and exceed liquidity plans.
Offtaker credit: Community choice aggregators and small retailers can weaken quickly; ISO credit postings offer early warning.
Environmental compliance: New standards can force downtime or capex that does not pencil without capacity or tolling revenue.
Tax execution: Prevailing wage and apprenticeship errors can strip bonuses; wrong placed-in-service dates misalign credits and depreciation.

Opportunity sets right now

Renewables that are actionable

Stranded pre-NTP pipelines: Buy interconnection positions and permits with staged payments tied to upgrade clarity. Monetize via tax credit transfers once equipment orders and prevailing wage records are complete.
Operating solar and wind under curtailment: Reprice debt, add basis hedges, retrofit storage or flexible load, and renegotiate delivery windows with receptive offtakers.
Storage with volatile revenue: Pivot to tolling with LSEs or CCAs where possible, lock capacity value where offered, and model conservative degradation and augmentation.
Community and C&I portfolios: Standardize O&M and billing, migrate to stronger credits, and require collateral or parent guarantees where CCAs are shaky.

Conventional assets with a bid

PJM-accredited gas: Refinance on capacity uplift, invest in reliability to maximize accreditation, and consider seasonal dual-fuel where it pencils.
Coal with liabilities: Underwrite near-term capacity value and grid constraints prudently, price compliance capex and retirement, and plan site repurposing for storage or data center interconnect value.
Midstream with basin risk: Reset minimum volume commitments to realistic levels and share uplift with producers, favor systems with premium hub access, and use tariff tools where helpful.
Utility carve-outs: Unregulated generation fleets or development arms can trade, but affiliate rules and approvals set timing.

Execution timeline that actually closes

Day one is about stabilizing cash and preserving options. Weeks zero to two focus on liquidity triage, forbearance with lenders and hedge parties, ISO collateral and critical vendors, hiring counsel and a financial advisor, and launching a data room with SCADA and ISO settlements. Weeks two to eight is when you pick the path. If pursuing a 363, file first-day motions, secure a DIP, and launch the sale. If out of court, negotiate extensions, fees, new collateral, and tax equity alignment while starting offtaker and ISO consent outreach. Weeks eight to 14 is for bids, naming a stalking horse, locking consents in principle, drafting the APA and cure lists, and filing the sale motion. Weeks 14 to 20 is for closing, funding cures and reserves, replacing letters of credit, novating market participation, transitioning O&M and settlements, and implementing hedges and basis management.

Fast triage scorecard

Consents map in 48 hours: List every consent and who signs. If a key consent has no viable path, pivot or walk.
Liquidity runway: Cash plus committed lines must cover ISO collateral plus 45 to 60 days of downside.
Hedge fit: If the hedge shape is off versus resource profile and node, price a hedge reset or add collars before close.
Tax equity stance: Alignment with documented timelines, indemnities, and replacement rights is a green light, uncertainty is a red light.

Bid tactics and investment committee takeaways

Winning bids combine speed with certainty. Pre-wired DIPs and letter-of-credit backstops beat higher nominal prices without closing certainty. ISO and offtaker credibility also matters because ready collateral and clean compliance records accelerate approvals. Practical O&M plans that cut costs without harming reliability and a safety record that clears committees are essential. Hedges under firm risk limits and credit lines support higher leverage and tighter pricing. For broader opportunity sourcing and context, see this overview of special situations strategies.

For investment committees, the discipline is consistent. Price optionality because contracts and market rules behave like options, and avoid false precision on nodal and policy risk. Build the consent map on day one and time the plan to the slowest approval. Use court tools where needed because 363 processes can clear liens and unblock operations. Align incentives to cash and risk reduction, not megawatt counts or asset count.

Closing Thoughts

Distressed energy deals reward buyers who can read the cash waterfall, map consents, and close fast. Focus on liquidity, hedge fit, accreditation, and tax execution. If you combine these with credible operations and basis management, you can underwrite durable returns in a market where capital is still scarce and timelines decide outcomes.