Nature-Dependent Electricity Contracts: Build One PPA Finance Model
New IFRS requirements for contracts linked to wind and solar output are now effective. Companies need more than an accounting memo: they need a contract-level operating model connecting procurement intent, expected electricity usage, settlement data, hedge designation and investor-ready disclosure.
Corporate power purchase agreements can support price certainty and access to renewable electricity, but their financial reporting has long been complicated by one physical fact: wind and solar output is not produced on demand. A buyer may be required to take electricity when it is generated, even when its own consumption is lower, and sell the surplus back into the market. A virtual arrangement may settle financially against output that varies with the weather.
The International Accounting Standards Board responded with targeted changes to IFRS 9 and IFRS 7. The IASB's announcement of the amendments identifies three core changes: clarification of the own-use requirements, permission for specified hedge accounting and new disclosures about effects on performance and cash flows. The requirements apply for annual reporting periods beginning on or after 1 January 2026.
The finance challenge is now implementation. A defensible conclusion depends on contract terms, expected usage, market design, delivery and sale patterns, forecasts and management purpose. Those facts sit across procurement, facilities, energy management, treasury, accounting, legal, tax, sustainability and technology. A company that treats the change as a year-end technical exercise risks inconsistent classifications, missing evidence and late disclosure work.
The better approach is one PPA finance model: a governed process that follows each nature-dependent electricity contract from commercial approval through monthly accounting and external reporting.
Understand what the amendments cover
The authoritative IFRS 9 and IFRS 7 amendments define contracts referencing nature-dependent electricity as arrangements that expose an entity to variability in the underlying amount of electricity because generation depends on uncontrollable natural conditions, such as weather. The scope includes contracts to buy or sell such electricity and financial instruments that reference it.
This is narrower than every contract marketed as renewable or sustainable. A conventional fixed-volume electricity contract does not automatically enter the targeted guidance merely because renewable certificates accompany it. Nor do the amendments settle every accounting question connected to a generation project. Depending on structure, other requirements covering leases, joint arrangements, associates or service concessions may be relevant. Scope assessment must start from contractual rights and obligations, not the commercial label.
Companies should create a population using search terms, vendor and counterparty data, energy-procurement records and derivative registers, then validate it with legal and accounting review. The inventory should include physical PPAs, virtual PPAs and other contracts whose settlement or delivery is linked to variable natural output.
Build a contract-level evidence record
Capture commercial purpose and operating facts
For each contract, record facility, technology, market, delivery point, term, pricing formula, volume mechanics, take obligations, settlement process, certificates, termination rights and guarantees. Link the contract to the consuming sites or forecast transaction that management says it supports.
The evidence record should also identify who approved the contract and why. Commercial purpose does not determine accounting by itself, but it provides context for assessing whether the arrangement is held for expected usage, used as a hedge or managed for another objective. Procurement papers, board approvals and treasury mandates should tell the same story.
Preserve forecast versions and actual outcomes
Own-use and hedge-accounting judgements rely on evidence that changes over time. Finance should retain versioned forecasts of electricity demand and expected generation, plus actual consumption, delivery, sales and settlements. A current forecast without history cannot show how management assessed the contract when decisions were made.
This is a data-governance problem as much as an accounting problem. Each forecast needs a timestamp, owner, methodology, unit of measure, site coverage and reconciliation to actuals. Weather-driven generation forecasts should not be confused with the company's demand forecast. The model should make both visible and explain their interaction.
Apply own-use as a monitored conclusion
The amendments provide application guidance for a purchaser assessing whether a contract continues to be held for receipt of electricity in accordance with expected usage requirements. Under the targeted approach, sales of unused electricity do not automatically defeat own-use when they arise from the market structure and the buyer remains a net purchaser over a reasonable period, among other relevant requirements.
That relief should not be converted into a blanket policy. Finance needs a repeatable assessment of expected purchases, actual usage and sales. Surplus-sale behaviour should be analysed for cause, volume, frequency and economics. A sale forced by the timing of generation and market settlement is different from deliberate short-term trading, but the conclusion needs contemporaneous evidence.
A monthly control can compare delivered volume, consumed volume and market sales, with thresholds for investigation. A quarterly review can reconsider forecasts, site changes, production shutdowns, contract modifications and changes in management intent. Material deviations should trigger an accounting reassessment rather than wait for year-end.
Make hedge designation match variable output
For eligible arrangements accounted for as financial instruments, the amendments permit a variable nominal amount of forecast electricity transactions to be designated as the hedged item when it aligns with the variable amount expected to be delivered by the referenced generation facility. They also provide a highly probable presumption in specified circumstances when the contract cash flows are conditional on the designated forecast transaction.
This can improve alignment between the economic arrangement and hedge accounting, but the ordinary discipline of hedge documentation remains. At inception, treasury and accounting should document the risk-management objective, hedging instrument, hedged item, nature of the risk and method for assessing effectiveness. The company should define how the variable amount will be determined and how forecast purchases are mapped to the generation profile.
The process should prevent a common disconnect: procurement negotiates a contract, treasury manages price exposure, and accounting receives only a summary after execution. A pre-signing finance gate can test whether the proposed terms are operationally supportable, whether required market data will be available and whether systems can produce the expected designation and measurement evidence.
Design disclosures from the data backward
The amendments add IFRS 7 disclosures for certain contracts treated as executory under the own-use guidance and for nature-dependent electricity contracts designated in hedging relationships. The objective is to help investors understand effects on financial performance and the amount, timing and uncertainty of future cash flows.
That objective calls for more than a contract count. The amendment includes information about contractual features, commitments, financial effects and qualitative factors affecting future cash flows. Where relevant information is spread across notes, cross-references should allow readers to find the complete picture without duplication.
The IFRS Accounting Taxonomy update for these contracts confirms that the new disclosure requirements have also been reflected in digital reporting. The taxonomy work introduced dedicated elements, which means data lineage should extend through tagging and filing review.
Companies should work backward from a disclosure prototype. Define every data point, narrative owner, system source, calculation, control and review step before the reporting close. This exposes gaps while there is time to repair them. It also reduces the risk that legal, procurement and sustainability narratives describe the same contract differently.
Create a cross-functional monthly close
A strong close process can be organised into six steps. First, confirm the contract population and modifications. Second, ingest metered generation, delivery, consumption, sale, price and settlement data. Third, reconcile volumes and cash to counterparty statements and the general ledger. Fourth, run the own-use monitoring and hedge-accounting controls. Fifth, post entries and investigate exceptions. Sixth, update disclosure accumulators and management reporting.
Ownership should be explicit. Procurement maintains commercial terms and supplier notices. Energy or facilities teams own consumption and operational forecasts. Treasury owns market exposure and hedge strategy. Accounting owns classification, measurement and disclosure. Legal assesses contractual changes. Technology maintains interfaces and access controls. Internal audit or a second-line function can review design and execution where the exposure is material.
The monthly pack should show population completeness, contract status, forecast-to-actual differences, surplus-sale analysis, hedge results, valuation changes, settlement exceptions and disclosure data. It should be short enough for decision-makers and detailed enough to trace every figure.
Improve future contract decisions
Implementation can also sharpen commercial discipline. Before approving a new PPA, decision-makers should see not only expected energy cost and environmental attributes but also volume shape, basis exposure, imbalance and settlement mechanics, collateral requirements, credit terms, accounting outcome, earnings variability, disclosure burden and systems cost.
That does not mean accounting should dictate procurement. It means the full finance consequence should be visible when the company chooses term, facility, market and pricing structure. Standard clauses can require timely meter data, transparent calculations, audit rights and structured settlement files. These provisions reduce recurring operational cost over a long contract life.
Scenario analysis should cover lower or higher site demand, delayed facility start, curtailment, negative-price periods, generation forecast error, counterparty disruption and changes in market rules. Management can then decide whether a contract remains valuable across plausible operating states, rather than only under a base-case power curve.
A 100-day implementation roadmap
In days 1-25, appoint an executive sponsor, confirm accounting policy, build the candidate contract population and identify 2026 reporting deadlines. Create the contract data standard and prioritise material arrangements.
In days 26-55, complete scope and own-use assessments, review hedge designations, map forecasts and actuals, and identify data gaps. Draft the disclosure structure and assign every input to an owner.
In days 56-80, configure system reports, build reconciliations, test calculations and run a parallel monthly close. Resolve contract-language and counterparty-data issues. Validate that digital reporting tags and review controls are understood.
In days 81-100, complete a dry-run disclosure, obtain audit and governance feedback, approve monitoring thresholds and embed a recurring contract review. Report to the audit committee or finance leadership on conclusions, exceptions and remediation.
The goal is not simply compliance with a narrow amendment. It is a finance capability that keeps contract purpose, physical electricity, market settlement, accounting and investor communication aligned throughout the agreement's life.
Frequently asked questions
When did the new requirements become effective?
They apply for annual reporting periods beginning on or after 1 January 2026, with earlier application permitted. The IFRS Foundation's 2026 standards update includes the nature-dependent electricity amendments among requirements effective in 2026.
Do the amendments apply to every renewable electricity contract?
No. Scope depends on exposure to variability in electricity volume caused by uncontrollable natural conditions and on the applicable accounting requirements. Companies should assess the actual terms and avoid relying on product labels.
Can a company still use own-use if it sells surplus electricity?
Potentially, but not automatically. The company must apply the amended guidance and support its conclusion with expected-usage, purchase and sale evidence. The reason for and pattern of sales matter.
What changed for hedge accounting?
For qualifying nature-dependent electricity contracts, a company may designate a variable nominal amount of forecast electricity transactions aligned with expected generation from the referenced facility, subject to the other hedge-accounting requirements.
Which teams need to be involved?
At minimum: procurement, energy or facilities, treasury, accounting, legal, tax, technology and external reporting. Sustainability teams may also be relevant, but claims and certificates should remain clearly distinguished from the IFRS 9 and IFRS 7 analysis.
Sources and Citations
• IASB: Updates to IFRS Accounting Standards for nature-dependent electricity contracts
• IFRS 9 and IFRS 7 amendments: Contracts Referencing Nature-dependent Electricity
• IFRS Accounting Taxonomy Update: Contracts Referencing Nature-dependent Electricity