Corporate energy buyers revisiting power purchase agreements signed years ago are not simply deciding whether to renew a contract. They are trying to replace, extend, or restructure power supply in a market that bears little resemblance to the one in which the original deal was negotiated. Project economics, interconnection timelines, demand, capacity conditions, and competition for viable generation have all changed, which makes the price embedded in a legacy PPA a misleading benchmark for the next procurement decision.
For procurement and finance teams, the relevant comparison is no longer old contract versus new contract. It is the cost and risk of every option available in the 2026 market, whether an agreement is approaching expiration, entering an extension window, being restructured, or simply forcing a decision about how the next block of power should be sourced.
A Market Built on 2016 Economics
Corporate renewable procurement was already becoming a significant force by the middle of the last decade. By the end of 2016, Google said it had accumulated 2.6 gigawatts of wind and solar agreements as it worked toward matching its global electricity consumption with renewable energy, and Amazon, Microsoft, and other major companies were expanding renewable procurement alongside it. Wind dominated much of that early market: Google signed a 225-megawatt wind PPA with Invenergy in February 2016, 3M signed a separate 120-megawatt wind deal that same month, and Microsoft added 237 megawatts of wind capacity that November, part of a broader wave that also included Amazon and Dow Chemical.
The economics helped make long-term contracting attractive. Renewable costs were declining, developers needed creditworthy counterparties to support project financing, and large corporate buyers could provide the revenue certainty needed to get projects built. Many contracts were intentionally long-lived: Google's first renewable PPA, signed in 2010 for power from a 114-megawatt Iowa wind project, carried a 20-year term. That is also why there is no single 2026 PPA renewal wave; contract lengths and structures vary considerably across the market. But companies with older energy portfolios increasingly face the same problem: the economics that justified an original contract may have little to do with what replacement supply costs now, a gap that portfolio management practices haven't caught up with at many companies.
Development Constraints and Capacity Scarcity Are Colliding
The market available to buyers in 2026 operates under considerably different conditions. LevelTen Energy's Q2 2026 North American PPA Price Index draws from 266 price offers across 185 renewable projects in AESO, CAISO, ERCOT, MISO, PJM, and SPP, and buyers navigating that pipeline face interconnection delays, permitting challenges, and rising costs on top of competition for projects that can realistically reach commercial operation. Demand is accelerating at the same time, as data center development adds large blocks of new load in several of the same markets where corporate buyers are looking for renewable supply. A large creditworthy buyer willing to make a long-term commitment once offered developers something particularly valuable in bankable revenue certainty. That still has value, but in constrained markets, developers may now have more buyers competing for the same generation, a dynamic already visible in how grid congestion is reshaping contract performance for buyers who signed under looser assumptions.
Renewable PPA pricing does not move in lockstep with wholesale capacity markets, but recent results illustrate the broader scarcity emerging across the U.S. power system. PJM's 2028/2029 capacity auction cleared at its $325-per-megawatt-day price cap in July 2026, procuring roughly 6.8 gigawatts less than the grid operator's reliability requirement. That does not mean a renewable PPA should be priced against PJM capacity directly, since the two markets compensate different products and risks. It does show that buyers are operating in a system where new demand is arriving faster than dependable supply in some regions, and the developer across the table from a company revisiting an older contract may now have alternatives that were far less abundant when the original agreement was signed.
The Old Price Is an Anchoring Problem, Not a Benchmark
One of the easiest mistakes is treating the price under an existing PPA as the starting point for negotiations. The old price reflects the project economics and negotiating conditions that existed when the contract was executed. It does not establish the fair value of electricity or renewable generation in 2026. Procurement teams instead need to compare a new offer against the alternatives available now, which can include another physical or virtual PPA, utility supply, shorter-duration contracts, renewable energy certificates, or storage-backed arrangements. The relevant question is not how far the new contract has moved from the old price; it is what the company would pay, and what risks it would assume, under each replacement strategy.
Extensions and Delay Carry Their Own Costs
The same logic applies when a company is not replacing a PPA outright. An extension can appear easier because the project, counterparty, and relationship already exist, but extending an agreement means committing future procurement to an existing asset rather than testing the broader market, and that decision needs its own valuation of remaining operating life, expected generation, and any changes proposed for the extension period. Restructuring creates a different set of tradeoffs: a company may want to change contract duration, volume, or risk allocation because its load looks different than it did when the original agreement was negotiated.
Companies can also lose leverage by waiting too long to decide. LevelTen has argued that buyers should prioritize near-term procurement despite difficult conditions, since the cost of delaying can outweigh the benefit of waiting for prices to improve. That matters most when companies assume they can begin replacing supply shortly before an agreement expires: a new project can require years to navigate development, interconnection, permitting, and construction before reaching commercial operation, and a buyer that waits until the final stages of an existing contract may discover its preferred replacement cannot deliver when the old agreement ends. For procurement teams, the expiration date is not the date to begin negotiating; it is the deadline the replacement strategy has to work backward from.
Finance Has to Revalue the Whole Decision, Not Just the Renewal
The changing PPA market makes this more than a procurement exercise. Finance teams should evaluate the existing contract's remaining economics alongside current forward power expectations, replacement PPA offers, basis and congestion exposure, curtailment risk, and credit requirements, along with what the company's electricity needs will look like over the next contract period. That matters because signing another 10-, 15-, or 20-year agreement is not simply replacing renewable megawatt-hours; it is making a new long-term allocation of capital and risk. A company expecting substantial load growth may value supply certainty differently from one with stable demand, and another may decide flexibility is worth paying for rather than locking into another long-duration contract. Those are 2026 decisions, and the fundamentals procurement teams use to evaluate them should not be dictated by economics negotiated a decade ago.
The Next Contract Doesn't Have to Match the Last One
Long-term PPAs remain valuable procurement tools. They can provide price certainty, support new generation, hedge electricity exposure, and help companies meet renewable energy objectives. But the market that helped turn corporate PPAs into a mainstream procurement strategy has changed, and companies revisiting older contracts are negotiating against tighter generation conditions, longer timelines, rapidly growing demand, and more competition for viable projects. That makes legacy PPA pricing a poor benchmark for what comes next. Procurement and finance teams should treat expiration, extension, and restructuring as opportunities to re-underwrite the entire energy strategy rather than simply continue an existing contract. The contract anniversary may still be years away, but the decision about what replaces it may need to start now.
