Start here · your learning path
Power purchase agreements, from scratch
A PPA is a long-term contract to buy electricity — and its clean-energy attributes — from a generator. This page takes you from "I know nothing about power" to understanding how a PPA works, in four steps.
1Electricity from scratch
Electricity is a secondary energy source — power plants make it by converting coal, gas, nuclear, sun, or wind into electric current. It's the product every PPA buys and sells. Four things to know before anything else:
What you actually buy: kW vs kWh
Watts measure power right now; a kilowatt-hour (kWh) measures energy used over time — running 1 kilowatt for one hour (think a 1 kW space heater for an hour). Your home bill is in kWh. Scale that up by 1,000 and you get the megawatt-hour (MWh) a PPA is priced in.
It can't be stored — so supply must match demand every second
The grid has almost no large-scale storage, so operators must generate exactly as much as is being used at every instant — calling on the cheapest plants first and pricier ones as demand climbs. If supply and demand fall out of balance, the result is blackouts. This one fact is why wholesale prices swing, why "firm" power is valuable, and why PPAs exist to lock in a price.
The journey: plant → grid → you
A power plant generates electricity; high-voltage transmission lines carry it long distances; substation transformers step the voltage down; local distribution lines deliver it to your meter — all in an instant.
Who's who
Generators make the power, a grid operator moves and balances it, a utility delivers it and bills you, regulators set the rules, and you are the load. A PPA is a contract between a generator (the seller) and a buyer.
EIA — Measuring electricity · EIA — Delivery to consumers
2How power is bought & sold
Once you know power must be balanced instantly, the market makes sense: prices reflect what it costs to meet demand at each moment and place.
Wholesale vs retail, and the ISO/RTO
Wholesale power (generators selling for resale) is regulated federally by FERC; retail (your utility bill) is state-regulated. Across much of the US an ISO/RTO runs the wholesale market and sets prices in real time. Most PPAs are wholesale.
Why prices move
Operators stack plants cheapest-first to meet demand; the last one needed sets the price. When demand spikes or the grid is congested, that price can jump enormously. The locational marginal price (LMP) at each point on the grid is exactly this number — and it's what a PPA settles against.
Baseload, peakers, and "firm" power
Baseload plants run continuously; peakers run only at demand spikes; solar and wind run only when the resource is there. A 24/7 load like a data center values firm power it can count on around the clock.
Energy vs capacity
Capacity is how much a plant could deliver at once (MW); energy is how much it actually delivers over time (MWh). Some markets pay separately for each; PPAs mostly buy energy.
The units rule: MW vs MWh. A megawatt (MW) is 1,000 kW — power. A megawatt-hour (MWh) is energy. A 100 MW solar farm hits 100 MW only at full sun; over a year its capacity factor (~25% for solar) means it makes about 219,000 MWh, not 876,000. PPAs price that energy in $/MWh.
3Why PPAs exist
Buyer
Price certainty
A long fixed price hedges against volatile wholesale markets — and, for a corporate buyer, conveys the RECs behind a clean-energy claim.
Developer
Bankability
A creditworthy buyer's long-term contract is the predictable revenue that lets a project raise debt and get built. No offtake, no project.
The grid
New supply
PPAs are now the main way new US generation gets financed — corporate buyers contracted a record ~27 GW in 2025.
Once the mechanic clicks, run the — change the strike, pick a scenario, and watch which way the cash flows.
4How a PPA works — electrons, or just money?
Almost everything you negotiate hangs off one distinction — whether the buyer takes physical delivery of power, or just settles the difference financially.
Physical PPA verified
Electrons and legal title flow from the project to the buyer's meter or account. The buyer actually takes delivery of power.
Virtual / financial PPA (VPPA) verified
No electrons reach the buyer. The deal settles purely financially as a contract-for-differences, and the renewable energy certificates transfer to the buyer. This has been the most common corporate PPA model in the US.
The VPPA settlement mechanic
A VPPA is a fixed-for-floating swap. Each month, compare the buyer's fixed strike price against the floating market price (LMP):
Market price > strike
The generator pays the buyer the difference. The buyer is made whole against high power prices.
Market price < strike
The buyer pays the generator the difference. The generator gets its fixed revenue regardless of the market.
Net effect: the buyer locks in the strike as its effective power price, and the generator locks in stable revenue to finance the project. Don't just read it — and watch the cash change direction.
Stoel Rives, "Law of Solar" · Norton Rose Fulbright
The simulator models a flat fixed strike — one of five pricing structures. The most common US corporate VPPA structure in 2024–2026 is discount-to-market: buyer pays hub LMP minus a fixed spread (e.g. hub − $8/MWh), with a floor so the developer is never exposed below a minimum. See all five in .
Basis risk — the #1 structural risk to understand Practitioner
Wholesale prices are set at thousands of nodes (where generators connect) and averaged into less-volatile regional hubs. Most corporate buyers settle the VPPA at the hub. But the generator earns its local node price — so the developer absorbs the node-to-hub gap. That gap is basis risk, and it can be brutal.
The canonical horror story
In an August 2019 ERCOT congestion event, the North hub hit roughly $9,000/MWh while the project's node sat near $1,000/MWh. A 300-MW project settling at the hub lost about $2.4M in a single hour.
The US wholesale markets — ISO/RTO by ISO/RTO Practitioner
Where a project sits decides almost everything downstream: whether there's a capacity market, which hub you settle a VPPA against, how you can hedge basis, and even whether FERC has jurisdiction. Knowing these cold is the single most asked-about topic in practitioner interviews.
| Market | Capacity vs energy | Pricing & common hubs | What it means for a PPA |
|---|---|---|---|
| ERCOT Texas |
Energy-only — no capacity market; relies on scarcity pricing | Nodal LMP; hubs North, Houston, West, South | Not FERC-jurisdictional (intrastate grid, PUCT-regulated). Huge renewable build and heavy congestion make basis famously hard to hedge; CRRs exist but rarely cover a VPPA fully. |
| PJM Mid-Atlantic / Midwest |
Capacity market (RPM / Base Residual Auction) + energy | Nodal LMP; Western Hub (AEP-Dayton) is the benchmark | FERC-jurisdictional. Capacity prices spiked in recent auctions on data-center load. Long interconnection queue; FTRs/ARRs hedge congestion. |
| CAISO California |
No central capacity market — resource adequacy set by the CPUC / state | Nodal LMP; hubs NP15, SP15, ZP26 | Solar "duck curve" drives routine midday negative prices and curtailment. CRRs hedge basis. |
| MISO Midwest / South |
Capacity (seasonal Planning Resource Auction, by zone) + energy | Nodal LMP; Indiana Hub a common reference | Large footprint spanning regulated and restructured states. FTRs hedge congestion. |
The smaller markets follow the same template: SPP (wind-heavy Plains; energy market with an emerging capacity construct), ISO-NE (Forward Capacity Market; winter gas constraints drive price spikes), and NYISO (ICAP capacity market; zonal, with Zone J / NYC the most congested). The Southeast and much of the Mountain West have no organized market — bilateral utility deals and green tariffs instead, and no clean hub to settle a VPPA against.
The price-cannibal problem (2024–2026)
As solar build accelerates, midday prices converge toward zero or go negative in CAISO (California) and ERCOT West Texas — the most solar-saturated hours. Each new MW of solar added reduces the settlement value of every existing solar VPPA. A $43/MWh flat-strike deal signed in 2021 may settle against a hub averaging $25/MWh in the 10am–3pm block by 2027. The most common structural responses: time-of-delivery (ToD) pricing that weights evening hours more heavily, and battery co-location to shift output to the 5–8pm peak. A buyer who doesn't ask about this in due diligence accepts a hedge that may stop hedging in the most solar-heavy hours. EIA — Negative wholesale prices
FERC — Electric power markets · ERCOT market structure · PJM Manual 18 (RPM) · CAISO CRRs · MISO resource adequacy
RECs — what the buyer is really paying for
A renewable energy certificate represents the environmental attributes of renewable generation — one REC per MWh delivered to the grid. In a VPPA the fixed price is the consideration for those RECs, which the seller conveys to the buyer. The buyer can then claim the clean-energy use.
EPA — Renewable Energy Certificates
Who's who — the parties behind every deal Practitioner
A utility-scale PPA involves at least six parties, each with different interests, timelines, and risk appetites. Knowing who each one is changes how you read every clause.
Seller
Developer / IPP
Originates, finances, and builds the project. The seller in the PPA; holds the interconnection queue position; takes development and construction risk.
Build
EPC Contractor
Engineers, procures, and constructs the plant under a fixed-price contract. Absorbs construction risk from the developer; delivers the project to COD.
Operate
O&M Provider
Operates and maintains the plant post-COD. Responsible for meeting the availability guarantees in the PPA; often the developer's subsidiary or a specialist firm.
Debt
Project Lender
Provides 50–70% of the project's capital as non-recourse debt. Requires a bankable PPA, lender step-in rights, and an investment-grade offtaker.
Tax equity
Tax-Equity Investor
A bank or institution that owns a project tranche to monetize the ITC or PTC. Often the largest capital source post-IRA; paid before the developer sponsor.
Buyer
Offtaker / Corporate Buyer
Signs the PPA and provides the long-term revenue that makes the project financeable. Their credit rating and term commitment are reviewed by lenders before financing closes.
Regulated markets
Utility
Delivers power in regulated markets; counterparty in utility-scale PPAs; intermediary in sleeved deals; operates the green-tariff programs where direct PPAs aren't available.
Market operator
ISO / RTO
Runs the wholesale electricity market (PJM, ERCOT, CAISO, MISO); dispatches generators every 5 minutes; posts the nodal LMP prices that VPPAs settle against.
Advisory
Broker / Advisor
Energy consultants (LevelTen, Schneider Electric), law firms (Stoel Rives, Norton Rose), and investment banks that structure tax equity, broker deals, and advise buyers on market conditions.
RMI — Risk Mitigation Guide · World Bank — PPAs & bankability
A deal from start to first settlement
All the pieces above — buyer, developer, settlement mechanic, basis risk — in one concrete story. A 100 MW ERCOT solar VPPA, agreed at $43/MWh, with three months of settlement math including one month where a congestion event nearly zeros the developer's economics.
The cast
Buyer: Azure Cloud Inc. — investment-grade tech, 500 MW renewable target
Developer: Sunridge Energy LLC — Texas IPP, 400 MW portfolio
Project: Sunridge Solar I — 100 MW AC, Pecos County, TX
ISO: ERCOT · settled at Houston Hub
Strike: $43/MWh flat · 15-year term
Target COD: December 2026
How the terms were negotiated
- Price: Developer needed $41+/MWh to service debt at 1.25× DSCR. Buyer modeled $43/MWh below their 10-year avoided-cost forecast. Agreed flat — developer skipped the escalator to close faster.
- Settlement point: Houston Hub (buyer's preference for cleaner accounting; developer absorbs the node-to-hub spread).
- Curtailment: As-generated — buyer pays only for MWhs that actually settle. Developer carries ERCOT curtailment risk.
- Credit support: Two-way CSA; each party posts a letter of credit equal to six months of expected payments (~$3.9M).
- Delay damages: $15,000/day, capped at 90 days, with supply-chain and permitting carve-outs.
Three months of settlement after COD
The swap keeps the buyer's cost locked at the strike. Month 3 shows what happens when a congestion event drives the node far below the hub — basis risk nearly wipes the developer's economics for that month.
| Month | Hub LMP | Node LMP | Strike | Volume | VPPA settlement | Dev. realized |
|---|---|---|---|---|---|---|
| Jan 2027 | $38 | $36 | $43 | 15,000 MWh | −$75,000 buyer→gen. | $41/MWh |
| Jul 2027 summer spike | $71 | $67 | $43 | 10,000 MWh | +$280,000 gen.→buyer | $39/MWh |
| Aug 2027 congestion event | $65 | $22 | $43 | 12,000 MWh | +$264,000 gen.→buyer | ~$0/MWh ⚠ |
Developer realized = (Node LMP × Volume + VPPA receipt) / Volume = Strike − (Hub LMP − Node LMP). Aug 2027: developer earns $22 × 12,000 = $264,000 at the node, then pays the buyer $264,000 via the swap — netting ~$0. The VPPA payment that protects the buyer is the same payment that zeros the developer. This is basis risk in action.
Norton Rose — VPPA risks · American Cities — basis risk
What goes wrong — four failure modes
The mechanics look clean in term sheets. These are the cases where they broke.
1. COD slip / delay damages
The project misses its commercial operation date — EPC delays, supply-chain backlogs, permitting hang-ups. The developer's per-day delay damages start accruing (e.g., $15,000/day). After hitting the cap (often 90 days of expected payments) the buyer may have walk rights. The developer's lenders are watching the milestone schedule throughout.
2. Counterparty default
If the developer goes bankrupt mid-construction (as SunEdison did in 2016), lenders invoke their step-in rights, transfer the project to a solvent entity, and the PPA may survive — or may be rejected by the bankruptcy estate. If the buyer defaults, the developer marks the remaining swap to market and demands a close-out payment; the direction of that payment depends on whether the contract is in- or out-of-the-money at default.
3. Basis-risk wipe
Already shown above: Aug 2027, hub $65, node $22, developer nets ~$0 that month. Sustained over a year it erodes debt-service coverage. Fixes: node-settled VPPA (eliminates basis), a CRR hedge (costly and imperfect), or a basis collar that caps the developer's exposure.
4. Change-in-law / IRA risk
If Congress reduces ITC/PTC after signing, a developer who priced the deal expecting full credits must absorb the loss or trigger a pricing re-opener clause — which most buyers resist. These clauses are heavily negotiated precisely because neither party controls Congressional action.
The full six-stage journey from first RFP to first settlement check — with timelines and who does what — is in .
Become a PPA originator — the role, who hires, how to break in
This tool's stated goal is to help you learn to originate PPAs. Here's what that job actually looks like and how people get into it.
A day in the life
- Lead generation: Identifying corporate buyers with renewable targets — data-center build-out announcements, sustainability commitments, RE100 pledges. Pitching projects at RE+, CEBA Summit, and CleanPower conferences.
- Pricing runs: Modeling strike prices — what strike covers project LCOE and hits target returns at the given capital stack, and where the buyer's avoided-cost benchmark sits.
- Term sheet drafting: Writing a non-binding term sheet that anchors the commercial core: price, contract quantity, settlement point, term, REC ownership, credit support structure.
- Negotiations: Driving the commercial discussion with the buyer's energy procurement team and counsel. The risk allocation matrix is your negotiating map.
- Internal approvals: Presenting deals to investment committee with a deal model, sensitivity analysis, and risk memo. Defending the strike under stress scenarios.
- Closing coordination: Working with lenders, tax-equity investors, and attorneys to clear the conditions precedent and hit Notice to Proceed.
Who hires
Developer / IPP origination
NextEra, AES, Invenergy, EDF Renewables, Pattern Energy. Title: "PPA Originator," "Business Development Manager," or "Energy Transactions Manager."
Corporate buyer energy teams
Google, Amazon, Microsoft, Meta, Apple — 8+ postings in 2025–2026 require PPA knowledge. Title: "Renewable Energy Manager," "Energy Procurement Manager," or "Renewable Energy Analyst."
Advisory & brokerage
LevelTen Energy, Schneider Electric Energy & Sustainability, CPower — advise buyers through origination and execution on a fee basis. Good entry point for someone who wants deal exposure across many buyers at once.
Law & finance
Stoel Rives, Norton Rose Fulbright, Kirkland & Ellis (energy transactional); Goldman Sachs, Lazard, Guggenheim (tax-equity and project finance). Energy attorneys often move into origination after 2–4 years of deal experience.
How to break in
- Energy finance / project finance: LCOE modeling, debt sizing, and return analysis — the quantitative core of every origination pitch.
- Utility or ISO regulatory background: Understanding dispatch, interconnection, and tariff structures builds instant credibility in technical negotiations.
- Corporate energy procurement: Time inside a buyer's energy team is rare and valued by developers — you already know what an investment committee needs to approve a 15-year VPPA.
- Energy law: A PPA is a legal contract. Transactional energy attorneys who understand the clauses — not just who wrote them — move into business development roles regularly.
- Clean energy organizations: CEBA, RMI, and Berkeley Lab publish deal data and market benchmarks; analyst roles there build the vocabulary and network.
What to study next
- Run the simulator until the cash flows feel intuitive from both perspectives — buyer and generator.
- Work through the annotated term sheets in the Drafting tab, clause by clause.
- Study the ISO your target market is in: ERCOT for Texas, PJM for Mid-Atlantic, CAISO for California.
- Read NREL's standard contracts, the EEI Master P&S, and Stoel Rives "Law of Solar."
- Track the LevelTen PPA Price Index and CEBA's annual procurement survey — the real-time market benchmarks that originators watch.
CEBA — Clean Energy Buyers Alliance · LevelTen PPA Price Index · RMI — Risk Mitigation Guide
Where to go next. Learn to draft one, clause by clause, in — including the full deal lifecycle — feel the settlement mechanic in the , and see how AI data centers are reshaping deals in . The tracks what's verified versus still being researched.
Practice
How to draft a PPA
You almost never draft a PPA from a blank page — you start from a standard form and negotiate the commercial terms onto it. Here's the process, what every PPA must define, and the principles that keep a draft bankable. Then study the worked examples below.
The drafting process
- Start from a standard form. Use the EEI Master P&S Agreement for wholesale physical deals, a SEIA model for C&I, or an ISDA confirmation for a financial VPPA. Don't reinvent boilerplate.
- Agree the commercial core in a term sheet first. Nail down price, quantity, location, term, and product before lawyers draft the full agreement.
- Define every key term precisely. Ambiguity is risk — work the checklist below.
- Allocate each risk explicitly. For price, basis, shape, volume, curtailment, credit, and change-in-law, name who bears it. The settlement location decides basis risk — the most consequential single choice.
- Keep it bankable. A creditworthy offtaker, a tenor long enough to repay debt, and lender step-in rights are what let the project get financed.
- Negotiate, execute, then clear the conditions precedent (financing, permits, interconnection) to reach the commercial operation date.
What every PPA must define
Commercial
Term · price / strike · contract quantity & shape · settlement location · REC ownership · settlement mechanics
Performance & risk
COD & delay damages · availability guarantees · curtailment · credit support · force majeure · change in law · termination & default · assignment / lender step-in · dispute resolution
EEI Master P&S Agreement · NREL standard contracts · Stoel Rives — Law of Solar
Drafting principles & deal-killers
Define your defined terms — a vague clause is an unallocated risk. Every clause assigns a risk to someone; know which. Start from the market-standard form; don't over-engineer. The usual deal-killers: the wrong settlement point (basis), a weak offtaker credit, a tenor too short to finance, and uncapped liabilities.
Pricing structures — and who bears price risk
The strike is one number, but how it moves over the term is a negotiated choice — and each choice hands the electricity-price risk to a different party. These are the five structures you'll see, ordered roughly from most to least price risk on the buyer.
| Structure | How it works | Who bears electricity-price risk |
|---|---|---|
| Fixed (flat) | One $/MWh for the whole term. The cleanest hedge and the easiest to budget. | Buyer — goes out-of-the-money if market prices fall below the strike. |
| Escalating | A fixed price that steps up a set % each year (e.g. 1–2%). | Buyer — committed to a rising price path regardless of the market. |
| Inflation-indexed | Price tracks an index such as CPI rather than a fixed schedule. | Buyer — committed to an indexed path; real cost is hedged, nominal isn't. |
| Discount-to-market + floor | Buyer pays market minus a discount, but never less than a floor price. | Producer down to the floor; buyer at risk below the floor. |
| Collar (floor + cap) | A floor and a cap bracket the price; it floats between them. | Producer within the collar; buyer at risk below the floor but caps its upside above the cap. |
Two adjustments that ride on top of any structure
Negative-price floor. Independent of the pricing structure, settle whether the Floating Price floors at $0. Without it, every below-zero LMP interval makes the generator pay the buyer the strike plus the negative price — routine pain in ERCOT, CAISO, and SPP.
Time-of-delivery (ToD) weighting. An hourly variant that prices solar lower in saturated midday hours and higher at peak — closer to 24/7 matching. Real and increasingly common, but the clause-level mechanics are still a research gap here; see the .
WBCSD — Pricing structures for corporate renewable PPAs · EIA — Negative wholesale prices
Risk allocation — who bears what Practitioner
Every clause assigns a risk to one party. These are the eight risks that shape every deal, and where buyers and sellers typically start their negotiations. Knowing this table is what Google, Amazon, and Meta interviewers test.
| Risk | Developer typically wants | Buyer typically wants | Physical PPA difference |
|---|---|---|---|
| Basis | Hub settlement — developer absorbs the node-to-hub gap rather than exposing the buyer to nodal volatility | Hub settlement too — cleaner accounting, though buyer then loses the hedge if congestion inverts | Settled at the delivery node or zone; basis risk is embedded in the delivery price, not a separate exposure |
| Price (strike vs. LMP) | Strike high enough to service project debt; escalated strike that keeps pace with inflation | Strike as low as possible; flat or modestly escalating to budget predictably | Buyer pays a fixed price per MWh; no ongoing settlement against a market index |
| Curtailment | "Deemed generation" — paid on expected output even if the grid curtails the project | Pay only for actual delivered MWhs; developer should bear curtailment caused by their own project | Same negotiation; which party instructed the curtailment (grid vs. buyer) usually determines who bears the loss |
| Credit support | One-way: only the developer posts security (cash or LC); corporate offtaker's balance sheet is the guarantee | One-way for utilities; two-way for corporate VPPAs so both parties are covered if either defaults | Utility offtake: one-way (seller posts). Corporate VPPA: usually two-way — both parties post an LC |
| Change in law (IRA) | Buyer shares the risk if ITC/PTC credits are cut after signing — developer can't re-price for a regime change | Tax risk stays with the developer; buyer will not agree to re-open pricing if Congress changes credits | Same; often split — developer bears the risk but a pricing re-opener is triggered above a threshold cut |
| Delay damages | Low per-day rate, hard cap (3 months of expected payments), and no liability for delays caused by supply-chain or permitting factors outside developer's control | High per-day rate; uncapped or high cap; broad cause list (developer bears supply-chain risk) | Same negotiation; cap size is the key deal point |
| Volume / shape | As-generated: developer delivers whatever the project produces, no volume guarantee | Minimum delivery obligation or volume firming so the hedge is reliable | Physical PPAs more often include minimum delivery; VPPAs almost always as-generated |
| Counterparty credit | Buyer's credit rating assessed upfront; parent guarantee required if buyer is a subsidiary | Developer's sponsor credit assessed; step-in rights for lenders if developer defaults | Same; the investment-grade test is the same — weak offtaker credit is a common deal-killer |
Norton Rose Fulbright — VPPA risks · RMI risk-mitigation guide · Stoel Rives — Law of Solar
Physical vs. virtual — when to use which
Physical PPA — use when
- You want actual electrons at your meter or delivery point
- You can buy retail power from a supplier of choice, or you take wholesale delivery as a load-serving entity
- You need co-located or behind-the-meter generation
- You want to fix the delivery point rather than carry a separate basis exposure
Common forms: utility offtake (20-year wholesale), sleeved PPA, behind-the-meter, community solar
Virtual / Financial PPA — use when
- The project sits in an ISO/RTO market with a liquid, published settlement hub
- You want RECs and a price hedge without taking physical delivery
- You operate loads across many regions and want a portfolio-level hedge
- You can transact a commodity swap (a financial derivative) under your treasury and accounting policies
Common forms: hub-settled CfD (most common), node-settled CfD, fixed-volume swap
The geography constraint — what actually gates each structure
A common myth is that a VPPA needs the buyer to be in a deregulated, retail-choice state. It doesn't. A VPPA is a purely financial hedge: the buyer keeps its existing retail supply and separately settles a swap against a wholesale hub. So a company headquartered in a fully regulated state routinely signs a VPPA on an ERCOT or PJM project. What a VPPA actually requires is that the project sit in an organized wholesale (ISO/RTO) market with a transparent LMP to settle against.
What does turn on the buyer's geography is a physical retail deal: buying the actual electrons for your site from a chosen supplier needs retail choice. Where there is no organized market at all (much of the Southeast, the non-CAISO West), there is no clean index to settle a VPPA against — so buyers fall back to green tariffs, utility ESAs, or sleeved deals. Note that ISO/RTO membership and retail deregulation are different things: PJM and MISO span both regulated (e.g. Virginia, Michigan) and restructured states. Geography is the first question in any procurement conversation — but ask it about the project for a VPPA and about the buyer's territory for a physical retail deal.
WBCSD — Pricing structures for corporate PPAs · EPA — Customer PPAs
Utility contract types
In regulated states buyers can't contract directly with a developer. These are the four contract structures they use instead — and which hyperscaler energy roles explicitly require knowledge of.
Standard offer / default service
The regulated utility's tariff-rate supply: no commitment, no renewable attributes, maximum spot price exposure. The baseline all other options are compared against. If you can beat it on cost or carbon, you have a deal.
Green tariff
A utility-sponsored renewable product requiring state PUC approval. Buyer pays the utility a premium; the utility procures renewable generation on the buyer's behalf. Available where retail choice doesn't exist. Google and Microsoft have used green tariffs across the Southeast and Midwest.
Energy Supply Agreement (ESA)
A bilateral supply contract with a competitive supplier in a deregulated market — sets a fixed or indexed price for electricity, often including renewable attributes. Amazon, Oracle, and Microsoft energy managers cite negotiating and executing ESAs as a core day-to-day responsibility.
Sleeved PPA
A physical PPA where the local utility acts as intermediary between developer and buyer — useful where direct contracting isn't allowed but the buyer wants a specific project's RECs and a fixed price. The utility absorbs the price-fluctuation risk.
EPA — Green Power Purchasing Guide · WBCSD — Pricing structures
Deal lifecycle — origination to operations Practitioner
A utility-scale PPA takes roughly 3–7 years from first conversation to first MWh of settlement — and longer when the interconnection queue binds (see the bottleneck note below). Here are the six stages every deal goes through, with who's involved and typical timelines. The stages overlap: a developer clears conditions precedent while construction is already underway.
-
Origination & RFP (6–18 months)
Developer identifies a site, completes resource assessment, and enters the interconnection queue. Buyer issues an RFP or evaluates an unsolicited proposal — comparing projects on price, location, and counterparty credit.
Parties: developer's origination team · buyer's procurement lead · advisor/brokerInterconnection queue — how it works
Five steps from application to grid connection: (1) Application — developer files with the ISO/TO and pays a study deposit. (2) Feasibility study — ISO screens for thermal and voltage violations (~3 months). (3) System impact study — detailed congestion and stability analysis; network upgrade costs estimated (~6 months). (4) Facilities study — engineering drawings and final cost allocation for required upgrades (~6 months). (5) LGIA / SGIA signing — developer commits to cost allocation and posts security before construction begins.
FERC Order 2023 (2023) reformed the process to cluster-based study cycles, aiming to cut queue times — but PJM and CAISO still report 4–7 year wait times for many projects. Queue position is the single biggest development risk a buyer should ask about.
Ask any developer: (1) What study phase are you in? (2) What are the estimated network upgrade costs and who bears them? (3) Do you have a signed LGIA or a date-certain path to one?
-
Term sheet (1–3 months)
Parties agree the commercial core in a non-binding term sheet: price structure, contract quantity, settlement location, term, and REC ownership. The last moment to walk away cheaply before legal fees mount.
Parties: senior deal leads on both sides -
Due diligence & negotiation (2–6 months)
Lawyers draft the full PPA from a standard form. Both sides review credit, permits, and interconnection status. The risk table — basis, curtailment, credit support, change in law — gets negotiated clause by clause.
Parties: legal counsel both sides · credit/risk teams · buyer's technical advisor -
Execution & conditions precedent (6–24 months)
PPA is signed. Developer clears the conditions precedent to reach Notice to Proceed: project financing (debt + tax equity), final permits, and a signed LGIA. Buyer clears internal approvals — investment committee, board, sometimes a PUC prudence finding.
Parties: developer + lender + tax-equity investor + permitting counsel · buyer's finance and legal teams -
Construction (12–24 months)
EPC contractor builds the plant. Developer manages milestones; lenders watch completion risk through an independent engineer. Commissioning and testing required before COD.
Parties: EPC contractor · developer's project management · lenders' independent engineer -
Operations (10–25 years)
Monthly LMP settlement begins. RECs are issued in a registry (WREGIS, PJM-GATS) and transferred to the buyer. O&M provider maintains the plant; developer's asset management team handles reporting, credit support, and end-of-term planning.
Parties: developer's asset management · O&M provider · buyer's energy management team
The bottleneck. The interconnection queue is usually the longest single variable. Projects in PJM or CAISO have waited 4–7 years for a final interconnection agreement — often longer than the legal negotiation and construction combined.
Getting to signature — who approves, and what makes it binding Practitioner
A negotiated PPA isn't a deal until the right people on both sides say yes — and the approval machine looks completely different depending on who the buyer is. This is the part of the lifecycle that stage 4 above compresses into one line.
Track A · corporate buyer
Four internal gates, usually in this order:
- Sustainability confirms the deal supports the company's clean-energy claim — RECs convey, and the accounting works under the buyer's Scope 2 method.
- Treasury / finance sizes the exposure: a VPPA is a long-dated swap, so it gets marked to market, and finance decides whether it qualifies for hedge accounting or runs through the P&L.
- Legal closes the risk table — credit support, termination, change in law — often with outside energy counsel.
- Investment committee or board gives final approval. Whoever signs must hold a delegation of authority covering a commitment of this size — a 15-year, 100 MW VPPA is a nine-figure notional obligation.
Track B · regulated utility buyer
The approval is external — the state commission, because ratepayers foot the bill:
- The utility files an advice letter or application with the state PUC describing the PPA and how it complies with procurement rules.
- A procurement review group — commission staff, ratepayer advocates, non-market participants — examines it, and in California an independent evaluator reports on whether negotiations were fair and the price cost-effective.
- The commission approves cost recovery by resolution — the prudence review. Some states issue an advance determination of prudence (or CPCN) before the utility commits.
Timing matters: commission review adds months, so utility PPAs are often executed subject to regulatory approval as a condition precedent.
What makes the signature itself binding
Standard forms handle this with representations. In the EEI master, each party represents that it holds all necessary regulatory authorizations and that execution is "duly authorized by all necessary action" — so the internal approvals above aren't just process, they're what makes that representation true. The EEI architecture splits the paperwork: a negotiated cover sheet records each side's elections (collateral thresholds, cross-default, confirmation procedure) once, and each individual trade is then executed as a short confirmation under it. Bespoke long-form PPAs merge everything into one document, which is why they take months instead of minutes to execute.
Signed ≠ unconditional. A PPA is signed years before the project exists, so conditions precedent — financing close, permits, a signed LGIA, regulatory approval — keep the executed contract from being fully effective until they're met. Two questions to ask the other side at term sheet: whose approval does this need on your side, and how long does that take? A missed answer here is how deals die after signing.
California State Auditor — CPUC oversight of utility contracts · CPUC Resolution E-4320 (example PPA approval) · EPA Guide to Action — resource planning & procurement · EEI Master Power Purchase & Sale Agreement · DLA Piper — Corporate PPAs
Annotated examples
Pick a term sheet, then select any clause for what it means, why it matters, and the glossary terms behind it. Illustrative composites — not a specific contract.
Test yourself
Six questions on the mechanics interviewers actually probe — settlement direction, basis, risk allocation, structure choice, credit support. Answer to reveal the worked reasoning.
Score: 0 / 0 ·
Generator · practice template
Draft a Virtual PPA
Fill in the commercial terms and get a full VPPA draft in seconds. Every negotiable position is marked [IN BRACKETS] so you know exactly what to fill in.
Practice template only. This generator is for learning and as a starting-point draft. Do not sign or rely on this output for a real transaction without review by a qualified energy attorney.
Interactive
VPPA settlement simulator
Set a strike price and a year of market prices, and watch the contract-for-differences settle month by month. Green is money flowing to a party; clay is money flowing out. This is an illustration of the mechanic, not market data.
| Month | LMP ($/MWh) | Strike | Diff | Volume (MWh) | Settlement |
|---|---|---|---|---|---|
| Year |
Settlement convention: each month, settlement = (LMP − strike) × volume. Positive means the generator pays the buyer; negative means the buyer pays the generator. The VPPA swap settles at the hub; the developer earns the node price for actual energy sales. Use the Basis risk slider above to see how a node-to-hub spread erodes the developer's realized price. Try setting a month's LMP negative (e.g. −$20): with no floor the generator pays the buyer the strike plus the negative price — which is why VPPAs often add a $0 price floor. LevelTen terms · Basis risk explainer
Applied · the fastest-moving corner of the market
Clever PPAs for data centers & generation
—
Structures — how the clever deals are built
Each is one answer to the same question: how do you get large, firm, often carbon-free power faster than the grid can build it? Select to expand.
Recent deals
As of mid-2026 — worked examples of the structures above, not a live deal tracker. Each links to a source.
Voices · learn more
Expert perspectives
How four people who shaped this market think about PPAs — paraphrased from their public work, each cited. Then a short path to keep learning.
Keep learning
A short, ordered path — primers first, then reports and data.
Reference
Glossary
Every term here is drawn from a verified, cited source. Search or filter by category.
—
Honest scope
Coverage & sources
This tool only teaches what the research actually verified, and it grows over time. Three passes are done: a fact-checked deep-research run, a government/national-lab pass (FERC, IRS, EPA, NREL, Berkeley Lab), and a data-center deals pass. Items still open are marked as gaps, not dressed up as fact.
Verified — primary / government sources
| Topic | Status |
|---|---|
| Physical vs. virtual PPA; CfD settlement | verified |
| RECs: definition, 1 MWh = 1 REC, conveyance | verified |
| Basis risk; node / hub / LMP mechanics | verified |
| Risk taxonomy + mitigants (price, shape, basis, volume, operational) | verified |
| Price-risk allocation by pricing structure | verified |
| Term lengths; delay damages; capacity buydowns; credit support | verified |
| EEI master; LevelTen index; EPA guide | verified |
| FERC role; market-based rates; PURPA qualifying facilities | verified |
| ISO/RTO market structure (ERCOT, PJM, CAISO, MISO; capacity vs. energy, basis hedging) | verified |
| IRA ITC/PTC, transferability → pricing; Berkeley Lab LCOE data | verified |
| Deal types: behind/front-of-meter, sleeved, community solar | verified |
| Clauses: curtailment, force majeure, change-in-law, termination | verified |
| Bankability (creditworthy offtaker + tenor; lender risk view) | verified |
| Data-center demand & deal structures (LBNL/DOE + company & trade sources) | verified |
| Load flexibility / curtailment-enabled headroom (Duke 2025) | verified |
| Annotated example term sheets (VPPA, utility physical, data-center nuclear) | verified |
| Internal approval & signing (corporate approval chain, PUC prudence review, signature authority) | verified |
Covered — secondary sources
| Topic | Status |
|---|---|
| PPA originator role: responsibilities, skills, background (from job postings) | secondary |
| Expert perspectives (Shah, Norris, Tian, Powell) — summaries of public work | paraphrased |
Still open
| Topic | Status |
|---|---|
| Clause-level: assignment / lender step-in, dispute resolution | needs research |
| Time-of-delivery / hourly pricing; 24/7 carbon-free matching | needs research |
Sources
Government & national labs
FERC — PURPA Qualifying Facilities
IRS — Elective Pay & Transferability
Berkeley Lab — Utility-Scale Solar
EPA — Customer PPAs
NREL — Wind & Solar Curtailment
Standards & practitioner guidance
EEI Master P&S Agreement
LevelTen PPA Price Index
RMI — Risk Mitigation Guide
WBCSD — Pricing Structures
World Bank — PPAs & bankability