African infrastructure finance treats the USD-denominated power purchase agreements (PPAs) as a structural hedge against local currency risk. On the developer’s books it works as designed: revenue, debt service, and equity returns sit in dollars, and transaction FX exposure is zero. The contract does not stand alone, however. The utility offtaker sits between the contract and the cash, collecting end-user revenue in local currency and converting it into the dollars the PPA requires. When the currency weakens, the utility’s capacity to convert and remit weakens with it, and the exposure the hedge appears to eliminate reappears as arrears, delayed settlement, or restructuring.

The mechanism is visible in the market. Ghana’s IPPs remain owed $1.1 billion as of January 2026 after a $1.47 billion government settlement in 2025. Nigeria’s naira lost roughly 70 percent of its value in 2023-24 under an IMF-aligned liberalisation, and NBET’s Q3 2025 market settlement performance fell to 38 percent. Egypt’s pound broke its managed peg in March 2024 under Extended Fund Facility conditionality. In each case the affected IPPs were being paid under dollar-denominated contracts. Our FX Stress Test Model runs a standardised 50 MW solar template through six African markets and three devaluation scenarios to quantify where this becomes covenant risk, and what investors should screen for when headline tariff stops being a reliable signal.

Executive Summary

1. USD PPAs shift FX stress to the utility rather than removing it from the project. The dollar contract eliminates transaction FX exposure. It does not address economic exposure, which runs through the offtaker’s local-currency cash flow and reappears in the project as payment timing risk.
2. In African markets, that stress surfaces as delayed payment, settlement underperformance, or arrears.Ghana’s $1.1 billion in outstanding IPP arrears and Nigeria’s Q3 2025 NBET settlement drop to 38 percent are observable instances of the same mechanism.
3. When the channel is modelled explicitly, most sampled markets breach covenant or equity thresholds under realistic devaluation. Five of six markets fall below the 1.20× DSCR covenant, below the 12 percent equity hurdle, or both, under a 50 percent cumulative devaluation over three years, a shock less severe than Nigeria’s actual 2023-24 naira movement. The ranking depends materially on the offtaker collection haircut under stress, disclosed in the assumptions.
4. Egypt is the exception because its counterparty resilience is stronger. EETC’s implicit Ministry of Electricity support and Egypt’s post-EFF external position preserve dollar payment capacity even after the managed peg broke. The structural lesson is that counterparty resilience, not tariff level, determines whether a USD PPA behaves as a hedge in practice.

The Stress Matrix: Six Markets, Three Devaluation Scenarios

 

We classify outcomes in three bands. Clears means the project meets both the 12 percent USD equity hurdle and the 1.20× DSCR covenant. Marginal means the project stays solvent but breaches one threshold. Distressed means IRR turns negative or DSCR falls below 1.0×, severe enough to prompt restructuring in comparable real cases.

Only Egypt clears every scenario. Rwanda and Kenya clear at base and slide to Marginal under stress. Ghana and Nigeria are Marginal at base and Distressed under either stress path. South Africa is Distressed across all three because its rand-denominated tariff cannot service 70/30 project finance at realistic USD capex.

The ranking does not track headline tariff. Egypt’s $0.080/kWh is the lowest verified rate in the sample and delivers the strongest resilience; Kenya’s $0.12/kWh is among the highest and shows the largest compression. The binding variable is offtaker capacity to deliver on the dollar obligation, not the dollar price of the power.

Country reads

We distinguish below between verified tariff evidence and placeholder inputs. Readers should weight conclusions for Nigeria and Rwanda accordingly.

Egypt. 21.9 percent capacity factor at Benban; $0.85/W capex; $0.080/kWh USD tariff from Voltalia and ACWA Power disclosures. EETC sits above SSA utilities on credit quality through implicit Ministry of Electricity support. Investment Law 2017’s seven-year 30 percent tax deduction is not modelled and would add two to four IRR points.

Kenya. At the $0.12/kWh rate under which Malindi Solar and the 2017 PPA cohort operate on 20-year contracts, base IRR is 26.6 percent and falls to 6.4 percent under severe stress, the largest single-market compression in the sample. The driver is the KPLC severe-scenario collection haircut of 55 percent.

Ghana. Marginal at base (1.24× DSCR on $0.081/kWh from the PURC 2024 Q1 gazette), Distressed under both stress paths. The empirical counterpart is visible: $1.1 billion in outstanding ECG arrears after the 2025 settlement.

South Africa. The contrast case in the sample. South Africa is here not because it illustrates the offtaker channel but because it shows what the direct FX channel looks like when the utility is not the transmission mechanism. REIPPP BW7’s ZAR 46.1 cents/kWh weighted tariff cannot service 70/30 project finance at $1.00/W capex. The gap narrows in real BW7 deals clearing lower capex, tracking-based capacity factors, and Section 12B accelerated depreciation.

Nigeria. No operational utility-scale solar IPP in Nigeria publishes a PPA tariff. The $0.075/kWh in the model is the revised NBET rate accepted by two of fourteen 2016 IPPs; none reached commercial operation. Read the Nigeria row as the model’s best available reference, not a cleared benchmark.

Rwanda. REG’s $0.142/kWh Strategic Plan figure is Rwanda’s average generation tariff across the full mix, not a solar PPA. We substituted $0.10/kWh as a regional midpoint from the verified SSA range. Rwanda’s 2021 Investment Law preferential CIT and seven-year tax holiday are not modelled.

The Offtaker Channel

Currency weakness reaches an African solar IPP through two mechanically different routes. The direct route applies only to South Africa: local-currency revenue converts to fewer dollars as the currency weakens, and IRR and DSCR compress in proportion to the FX move.

For the other five markets the route is indirect. The PPA is dollar-denominated, transaction FX exposure on the IPP’s books is zero, and on paper the developer is insulated. The offtaker is a national utility collecting end-user revenue in local currency. As the currency weakens, the dollar-equivalent value of those collections falls and the utility’s capacity to convert and remit deteriorates. The exposure emerges as arrears rather than as an accounting FX loss, which is what makes the channel invisible to standard project finance models.

The compression profile isolates the offtaker variable empirically. Kenya and Nigeria hold the two largest compressions in the sample, twenty and fourteen IRR points, despite base-case economics that differ by a factor of five. Both share a high-risk offtaker classification and a 55 percent severe-scenario collection haircut. Egypt and Rwanda, medium-risk with a 75 percent haircut, compress by roughly half as much. The variable driving dispersion is the offtaker parameter, not the tariff or the capex.

The Contract Is in Dollars. The Payment Chain Is Not.

The IPP books dollars. The utility collects local currency and converts it. When the currency weakens, what fails is the conversion, not the contract.

This is the distinction between transaction and economic exposure. A USD PPA hedges the first cleanly and leaves the second in place, because the counterparty performing the hedge is correlated with the hedged event. In a deep capital market, a developer would close the gap with long-dated currency forwards or cross-currency swaps. For our six currencies, those instruments do not clear at tenor: TCX’s African book sits at roughly $2 billion against a much larger stated need, and long-dated forwards on the cedi, naira, kwacha, and birr are not actively quoted. The USD PPA fills the space as the second-best available instrument, and second-best means the exposure is still in the system.

Stress Scenarios Drawn From Recent History

Each reference event calibrating the stress scenarios was macro-policy-driven. Ghana’s 2022 cedi move anchored the pre-restructuring IMF ECF inflection with a cocoa and gold export squeeze. Nigeria’s 2023-24 naira path was a policy-driven liberalisation under IMF Article IV. Egypt’s March 2024 step followed EFF conditionality and a Gulf balance-of-payments reset. Five of six sampled markets are currently in or have recently exited an IMF programme.

The Moderate scenario (30 percent over three years) is less severe than what four of these markets experienced in a single year; the Severe scenario (50 percent) is less severe than Nigeria’s 2023-24 cumulative move. These are historical observations applied to a forward-looking question.

Key Model Assumptions

• Project: 50 MW DC utility-scale solar PV, 20-year PPA
• Capital structure: 70 percent debt, 30 percent equity
• Debt terms:5 percent USD senior debt (AfDB Fixed Spread Loan benchmark), 15-year tenor, 1-year grace
• Capex: $1.00/W for SSA markets (IRENA Africa 2024 average $1.093/W), $0.85/W for Egypt, $1.00/W for South Africa (REIPPP BW7 derived)
• O&M: $10/kW/year (proxy between IRENA global $6.2 and LBNL US $22-24)
• Thresholds: 12 percent equity IRR hurdle (USD, real), 1.20× minimum DSCR covenant
• Scenarios: Base (flat FX); Moderate (-30% over 3 years, Ghana 2022); Severe (-50% over 3 years, Nigeria 2023-24)
• Offtaker collection haircuts under stress: Low 100%, Medium 90/75%, High 80/55% (Moderate/Severe)

Where the Numbers Are Softest

Two tariff inputs are placeholders rather than verified market prices: Nigeria’s $0.075/kWh and Rwanda’s $0.10/kWh. Tax holidays and accelerated depreciation in Rwanda, Egypt, South Africa, and Nigeria are unmodelled and would add two to five IRR points to the affected markets without changing the ranking.

The Offtaker, Not the Tariff: What Investors Should Screen For

If headline tariff is the wrong screening variable, what should investors use instead? The answer is a small set of offtaker-level variables that collectively determine whether a USD PPA behaves as a hedge in practice:

• Settlement discipline. Does the utility’s actual payment performance track the contracted schedule over a multi-year window, including through macro stress?
• Tariff adjustment mechanics. Is there a contractual or regulatory pass-through to end-user tariffs, and has it functioned under past FX stress, rather than only on paper?
• Government support arrangements. What formal backstops exist (Put-Call Option Agreements, sovereign guarantees, World Bank Partial Risk Guarantees), and have they been tested?
• Liquidity and guarantee structure. Are funded reserve accounts, letter-of-credit facilities, or MIGA/ATI cover in place, and at what coverage ratio?
• History of arrears clearance. When the utility has fallen behind, has it cleared through full payment, restructuring, or default?
• Cost recovery at the utility level. Does the utility’s end-user tariff actually cover its cost stack, including the dollar PPAs it signs with IPPs?

For lenders, the 1.20× DSCR covenant priced at financial close can fall below 1.0× under stressed collection and should be modelled against stressed rather than contractual cash flow. For DFIs lending hard currency against a USD PPA, the exposure is utility credit risk rather than project structural risk, and should be priced accordingly.

The gap behind these pricing errors is institutional. Long-dated FX hedging infrastructure for African currencies remains thin, and a DFI-pooled currency facility, a sovereign FX guarantee programme, or a regional central-bank instrument would close it. None is yet built at scale.

The Bottom Line

The USD PPA does not fail technically; it works as designed on the project’s books. It fails because African power markets do not stop at the project SPV. The utility sits between the contract and the cash, and when the currency weakens, the utility’s ability to honour the dollar contract weakens with it. The risk the hedge appears to eliminate reappears one step downstream as payment risk.

This extends a question opened in our March DisCo Commercial Performance analysis. The mechanism is the same in pan-African form; the geography is wider. Whether the next generation of African infrastructure deals can be financed at scale without closing the FX hedging gap is the structural question behind this asset class, and the subject of the next piece in this series.