South Africa's energy resilience in 2026 — what changed since 2022

South Africa's electricity sector in 2026 is unrecognisable from where South Africa's energy resilience in 2026 — what changed since 2022 was four years ago. The country went more than 200 days without load shedding in 2025.

The grid has remained stable through the first quarter of 2026. Eskom has been carved up into operationally distinct entities. A fully independent transmission system operator has been mandated to sit outside Eskom. Embedded generation under 100 MW is exempt from licensing and only requires NERSA registration. And carbon tax has moved into phase two, with the headline rate up 30.5% on 1 January.

This piece addresses africas as the core focus, drawing on Kettle's South African public-sector and corporate advisory practice.

Yet South African organisations still need a deliberate energy resilience strategy. Not because load shedding is back, but because the operating-cost structure of energy has fundamentally shifted, the regulatory perimeter around private generation has been redrawn, and the funding architecture for the transition is in active flux. Resilience in 2026 is no longer a diesel-generator problem. It is a balance-sheet, governance, and capital-allocation problem.

Kettle's view: the firms that have used the load-shedding hiatus to consolidate genuinely resilient energy architecture — embedded generation contracted, wheeling agreements signed, carbon exposure quantified, JET-aligned capital strategies in place — are the ones positioned for the next decade. The firms still operating as though the 2022 crisis was the last crisis are buying diesel they will not need and missing investments that would compound. This piece sets out the 2026 picture and the operating-model implications.

The load-shedding story has changed — what hasn't is the lesson

The 2022 South African grid was running through routine Stage 4 cuts with peaks at Stage 6, an average of multiple hours of outage per day across most metros. By late 2024 and through 2025, Eskom's Generation Recovery Plan had delivered material improvements to the available installed capacity. South Africa went 200+ days without load shedding through 2025. As of April 2026, no load shedding is scheduled, and the Eskom Summer Outlook projection has held.

What is not back is complacency. The grid's improvement has been driven by a combination of higher generation availability, lower demand (which itself reflects load lost during the worst load-shedding years), and a significant ramp-up in private embedded generation that does not draw from Eskom. The structural fragility — an ageing fleet of coal stations, deferred maintenance backlogs, transmission constraints, and a state-owned distribution layer — remains. The system is running better; the system is not yet robust.

For South African organisations, the right read is therefore not "crisis over." South Africa's energy resilience in 2026 — what changed since 2022 is: the regulatory and operational room created during the crisis is now permanently available, and the cost of not using South Africa's energy resilience in 2026 — what changed since 2022 is the cost of being a passive electricity consumer in a market that has structurally changed.

Eskom is being carved up — and the timeline is locked

The most significant structural change since 2022 is Eskom's unbundling. The National Transmission Company of South Africa (NTCSA) became operational as an Eskom subsidiary in July 2024, taking control of the transmission grid as a separate legal entity. In 2026 the Minister of Electricity and Energy approved Eskom's revised unbundling strategy, setting up the next stage of separation: a GenerationCo to house the legacy coal and nuclear fleet, an Eskom Green subsidiary for the renewable portfolio, a National Electricity Distribution Company of South Africa, and the continued operation of NTCSA as the transmission entity.

Crucially, President Ramaphosa confirmed in February 2026 that a new and independent Transmission System Operator will be established outside of Eskom. NTCSA, while operationally separate, remains Eskom-owned today; the new TSO is the long-term destination. The full unbundling is mandated to complete by 2030.

We are restructuring Eskom and establishing a fully independent state-owned transmission entity. This entity will have ownership and control of transmission assets and be responsible for operating the electricity market.

— President Cyril Ramaphosa, February 2026

What this means operationally for South African organisations: the electricity market is moving from a single-buyer model to a multi-party market in stages. The contracting parties on the demand side will increasingly need to negotiate directly with generators, with transmission services provided by an independent TSO and distribution carved off into a separate state-owned entity. Procurement teams that have spent two decades transacting with a single Eskom interface need to prepare for a more sophisticated counterparty landscape.

Embedded generation: the 100 MW rule is now operating, not theoretical

Schedule 2 of the Electricity Regulation Act was amended in August 2021 to lift the licence-exemption threshold for embedded generation from 1 MW to 100 MW. The amendment was significant in 2022 — it removed a licensing bottleneck that had constrained private generation for years. In 2026 the amendment is mature and operational.

What this means in practice: facilities with an installed capacity over 100 kW and a grid connection are required to register directly with NERSA. Facilities at or under 100 kW with a grid connection register with their relevant distributor — Eskom or the licensed municipality. Facilities at or under 100 MW that meet Grid Code requirements and have an arrangement with the relevant grid provider are guaranteed registration. The regulatory perimeter is clear; the registration pathway is mapped.

NERSA registered 16 embedded generation projects totalling 211 MW in a single recent batch, and clarified the registration framework in February 2026. Industry build-out has continued steadily: mining operations, manufacturing campuses, agricultural co-operatives, and commercial property estates have moved from feasibility studies to operational embedded plants. For South African organisations with rooftop, ground-mount, or wheeled supply options, the question is no longer whether private generation is permitted. It is whether the firm has built the operating model to make it work.

JET-IP: the funding picture in 2026

The Just Energy Transition Investment Plan (JET-IP) is the formal funding architecture South Africa has built to finance the move from coal to renewables. The International Partners Group originally committed US$8.5 billion in November 2021. By the latest accounting the total commitment from international partners stood at approximately US$12.8 billion — composed of US$329.7 million in grants (only about 4% of the original pledge), US$5.3 billion in concessional loans, US$1.5 billion in commercial loans, and US$1.3 billion in guarantees.

The composition is the story. Grant funding is structurally tiny relative to the commercial-loan and guarantee components. South African civil society organisations and labour federations have been vocal that a transition financed mainly through commercial debt does not deliver the "just" in just transition — it transfers fossil-era infrastructure cost onto South African balance sheets. The critique has been a defining tension of the JET-IP architecture since inception.

The most visible recent development was the United States' formal withdrawal from the partnership on 28 February 2025. The US cancelled the unallocated balance of its commitment — approximately US$56 million in grants and up to US$1 billion in potential commercial investment. The remaining IPG members (the European Union, the United Kingdom, Germany, France, the Netherlands, Denmark) confirmed their continued participation. South Africa's domestic counterpart, the JET Project Management Unit (JET PMU), reports the funding platform is operational and matching projects with grants — but disbursement pace has consistently lagged initial expectations.

Practical consequence for South African organisations: JET-aligned capital is real, but South Africa's energy resilience in 2026 — what changed since 2022 is not free, and accessing it requires meeting the IPG's project criteria. Concessional finance is available for projects in the renewable energy, electric vehicle, and green hydrogen value chains; commercial loans are available with implicit IPG guarantees; grants are scarce. Firms positioning for JET-aligned capital should already be running parallel applications across the relevant DFI windows and not waiting for a single consolidated funding pathway that does not currently exist.

Carbon tax phase 2 — what the rate increase means for operating costs

Carbon tax in South Africa entered phase 2 on 1 January 2026. The headline rate increased from R236 per tonne of CO2-equivalent to R308 per tonne — a 30.5% rise. The legislated trajectory takes the rate to R462 per tonne of CO2e by 2030. The basic tax-free allowance was simultaneously tightened by 10%; the offset allowance was increased by 15%, and the performance allowance for combustion emissions was increased by 5%.

For carbon-intensive operations — cement, steel, paper, basic chemicals, large-scale heavy industry, and coal-fired co-generation — the rate change is material. A facility previously paying R10 million in carbon tax sees an effective increase to roughly R13 million on the same emissions profile, before the allowance changes are netted in. For most diversified businesses the carbon tax is still a manageable line item; for the carbon-heavy sectors it is now a strategic cost requiring serious mitigation planning.

The 2026 Budget also raised the general fuel levy by 9 cents per litre for petrol and 8 cents per litre for diesel, with the carbon fuel levy increased by 5 cents per litre for petrol and 6 cents for diesel. These are the largest combined fuel-levy increases since carbon tax was introduced in 2019. They feed through to transport costs, distribution costs, and ultimately consumer prices over the next 18 months.

The energy resilience operating model in 2026

Putting the five threads together — grid stability, Eskom unbundling, embedded generation, JET-IP funding, carbon tax — the energy resilience question for South African organisations is no longer "how do I keep the lights on when load shedding hits." It is "what is the right operating model for energy procurement, generation, hedging, and disclosure over the next five to ten years." Five elements come together.

1. Embedded generation architecture. Decide whether the organisation generates on-site, wheels from a third party, or commits to a longer-term PPA. The 100 MW exemption makes all three options operationally viable; the choice is now strategic, not regulatory.
2. Counterparty diversification. Eskom is unbundling. NTCSA is the transmission counterparty. The independent TSO is on the horizon. Procurement architecture that has assumed a single counterparty for two decades needs to be redesigned for a multi-party market.
3. Carbon exposure quantification. For any carbon-intensive operation, quantify phase-2 carbon tax liability under the new rate and allowance regime. Build a five-year forward model that incorporates the R462/tCO2e endpoint.
4. JET-aligned capital planning. Identify projects in the renewable, EV, and green-hydrogen value chains that could draw on JET-IP concessional finance. Run parallel applications across the IPG windows; do not assume a single consolidated funding pathway.
5. Disclosure readiness. With ISSB IFRS S1 and S2 implementation accelerating in SA, climate-related disclosure quality is no longer optional for JSE-listed entities. Resilience information — generation mix, carbon liability, scenario analysis — flows directly into the IFRS S2 disclosure.

What Kettle is advising in 2026

For corporate clients we are working with on energy resilience, three priorities sit at the top of the engagement plan. First, lock in the embedded generation or wheeling architecture inside the next 12 months — pricing is moving in the supplier's favour as demand grows. Second, build a carbon tax forward model that integrates the phase-2 allowance changes into the financial plan, with mitigation projects sequenced against the rate trajectory to 2030. Third, position any JET-eligible projects for concessional finance through the IPG windows, with proper bankability documentation in place before the next application cycle.

For public-sector clients — municipalities, water utilities, public entities — the work is different. The 100 MW exemption applies equally to public entities, but the procurement architecture, the audit chain, and the MFMA-or-PFMA compliance load are heavier. Kettle's resilience consulting practice works alongside accounting officers to map embedded-generation projects through the procurement requirements, the generation registration, the National Treasury PPP framework where relevant, and the disclosure expectations of the Auditor-General. The energy choice is the same; the path through the framework is more demanding.

The 2022 fuel crisis taught South African organisations that energy is a strategic input, not a utility line item. The 2026 picture sharpens the same lesson: the structural changes are now mature enough to plan around, and the cost of staying passive is rising. Resilience is no longer about getting through the next stage of load shedding. South Africa's energy resilience in 2026 — what changed since 2022 is about positioning for the next decade of an electricity market that no longer looks like the one we grew up with.