• Cabinet moved ZESA consolidation into implementation under one vertically integrated operating company
• Current supply near 1.5GW trails demand around 2GW, leaving imports to balance the system
• H1 2026 electrical energy imports reached US$84.4m, up 47% year on year

Harare- Cabinet has moved the restructuring of ZESA into implementation, consolidating generation, transmission, distribution, system planning and commercial functions under ZESA Private Limited at a time Zimbabwe is carrying a power deficit of roughly 500MW and electricity demand is heading towards 5GW by 2030.

The restructuring places previously separated parts of the electricity system under one operating command. Cabinet expects the model to improve coordination across generation dispatch, outages, maintenance, load forecasting, investment decisions and electricity consumption. Smart metering, recovery of debts owed by Government institutions, local authorities and other strategic consumers will continue under the reform programme.

The organisational change addresses one part of Zimbabwe's electricity problem. Current demand is close to 2,000MW with average domestic production near 1,500MW, with Hwange contributing slightly above 1,000MW, Kariba around 460MW and independent producers just above 50MW during stronger operating periods. That leaves approximately 500MW between underlying domestic supply and prevailing demand before allowance for reserve capacity and plant maintenance.

Independent industry reporting also places Zimbabwe's dependable capacity between 1,200MW and 1,600MW against peak demand of about 2,000MW. Installed capacity is considerably higher at around 2,962MW, demonstrating the gap between nameplate capacity and electricity that can reliably be dispatched to customers.  This distinction becomes increasingly important as Government considers reducing tariffs.

Zimbabwe has achieved a significant improvement in electricity availability during 2026. That improvement has been supported by stronger domestic generation, recovering Kariba hydrology and regional electricity purchases.

Monthly electricity import values totalled approximately US$84.4 million during the first six months of 2026, compared with US$57.3 million during the equivalent six months of 2025, that is an increase of approximately 47%. Average monthly electricity imports by value increased from about US$9.6 million to US$14.1 million.

If the first half rate persisted for twelve months, the 2026 electrical energy import bill would approach US$169 million, and the longer series is more revealing.

Zimbabwe imported approximately US$152.1 million of electrical energy in 2021, US$207.8 million in 2022, US$162.1 million in 2023, US$207.7 million in 2024 and US$117 million in 2025. Across January 2021 through June 2026, the cumulative import value reaches approximately US$931 million. That is almost US$1 billion of foreign currency spent buying electricity across five and a half years.

The import bill should be interpreted carefully. The customs value does not provide the megawatt hours purchased and therefore cannot be converted directly into an electricity import price. Regional tariffs, contract structures and the volume purchased can all affect the dollar value, yet its economic message remains clear.

Zimbabwe's domestic power system has required repeated external balancing. Imports have also helped preserve industrial production during domestic generation shortages. Cabinet itself acknowledges this mechanism. Energy Minister July Moyo said ZESA's improved financial position allows the utility to purchase electricity from regional suppliers when domestic output falls short.

The current improvement in electricity reliability therefore carries a foreign currency requirement that the restructuring programme ultimately has to reduce.

The Demand Curve Is Moving Much Faster

The current 500MW deficit is small compared with the capacity requirement emerging towards 2030. The World Bank projects Zimbabwe's peak electricity demand rising from 1,950MW in 2022 to 5,177MW by 2030, driven particularly by mining and agriculture.

That represents an increase of more than 3,200MW from the 2022 demand base. Measured against current average generation around 1,500MW, the difference between today's supply and the World Bank's 2030 demand projection is approximately 3,677MW.

Zimbabwe therefore needs the equivalent of more than two additional Hwange power stations at current dependable output over the next four years if new demand is to be supplied predominantly from domestic generation.

The increase in demand is economically desirable. New mines coming online need power, and existing mines ramping up output need even more. Beyond mining, irrigation, agro-processing, cold storage, manufacturing and urban development are all pushing consumption higher. Government is also targeting expanded household access, with the National Energy Compact aiming for universal electricity connections by 2030 alongside a substantial increase in renewable capacity. The broader plan seeks to reach more than 5,400MW of installed generation capacity by the end of the decade. That target will need closer examination.

A system with 5,432MW of installed capacity serving peak demand of 5,177MW would have a nominal capacity margin of only about 4.9% if every megawatt were available. Zimbabwe's operating history shows why nameplate capacity cannot be treated as dependable capacity.

The reliability problem sits across the whole value chain. At Hwange there is both planned and unplanned maintenance, Kariba generation fluctuates with water availability, and solar output is limited by time of day. Add transmission constraints that can strand generation, and the risk of supply shortfalls rises even when plants are producing.

The Southern African Power Pool has long set reserve requirements above 7% for hydro systems and above 10% for thermal systems. For Zimbabwe, that implies the 5.4GW capacity target is not enough on its own. The gap will have to be closed with more dependable baseload, significant storage and demand-side management, or a large contribution from captive and off-grid supply that keeps part of the 5.2GW peak demand off the national grid.

Water levels have turned in Zimbabwe’s favour in 2026. Usable storage at Lake Kariba was 44.84% on 17 August compared to 21.58% a year earlier, allowing hydropower production to recover from the severe curtailments seen during the regional drought. That has helped stabilise supply, but it should not change the strategic direction.

Kariba remains valuable because it can provide low-cost, flexible electricity when water is available. It is also vulnerable, because generation can collapse during drought. A 2030 industrial plan therefore cannot be built on the assumption of good Kariba inflows every year. With Hwange carrying the bulk of current base load, the system will need solar, storage, private thermal and regional interconnection to provide reliability around those two core assets.

Globally the power sector is moving the same way. The IEA forecasts electricity demand growth of about 3.6% annually through 2030, driven almost 80% by emerging economies, and renewable generation growth of roughly 8% per year. Zimbabwe is stepping into this cycle with a domestic demand challenge that is much more acute.

Rebundling Can Fix Coordination

There is clear operating logic to the ZESA restructure. Power generation and distribution cannot be managed separately without cost. If a plant schedules maintenance without seeing distribution demand, shortages follow. If distribution is planned without reference to new generation, transmission becomes the bottleneck. And when different entities make investment decisions, you get duplicated overheads and no one accountable for the system as a whole.

The Cabinet-approved integrated model puts generation, transmission, distribution, planning and commercial services under one structure. In principle that should lead to better dispatch and sharper capital allocation.

The trade-off is governance. Vertical integration makes it easier to hide problems if segment reporting is weak. Losses in generation can flow through the group. Distribution losses can disappear into consolidated results. Poor revenue collection can be covered by better performance in another division.

To avoid that, the new ZESA must keep centralised control but publish detailed reporting for each part of the chain: generation, transmission, distribution, commercial collection and corporate services. Only then can management and the public see where value is being created or lost across the electricity system.

The Tariff Reduction Is The Harder Decision

Cabinet has also adopted a report on the impact of a proposed electricity tariff reduction, though neither the size nor the implementation date was disclosed in the statement. Instead, Government has instructed the Energy Ministry to develop a roadmap for lowering the cost of electricity production, while keeping smart metering, debt recovery, investment mobilisation and utility restructuring as linked elements of the reform programme.

The sequencing matters. A lower tariff would improve competitiveness for Zimbabwe’s mines, manufacturers, retailers and agricultural businesses because electricity is a direct operating cost. It can also support investment and cut spending on diesel generators and alternative energy systems.

However, ZESA still needs cash for coal, maintenance, salaries, imports, transmission repairs and new investment. A tariff cut funded through revenue under-recovery would weaken the same balance sheet Government is trying to make bankable. The reduction therefore has to come from a lower underlying cost base.

There are clear sources of savings. Smart meters can reduce commercial leakage, debt collection can turn delivered power into cash, and shared-service consolidation can cut duplicated overheads. Higher plant availability spreads fixed costs over more kilowatt hours, solar reduces exposure to fuel costs during the day, and lower network losses increase the share of generated power that is actually billed. Those efficiencies are what create room for a durable tariff reduction.

One way to measure whether the ZESA restructure is working is the import bill. H1 2026 imports came to US$84.4 million, or roughly US$14 million of forex every month. The goal should be a ZESA that needs less emergency power from outside, but can still tap regional supply when prices make sense. Cross-border trade is not the problem. SAPP was created precisely so countries can buy surplus power when their own systems are tight. SAPP traded 134.4GWh in June 2026 alone.

Zimbabwe does not need to pursue zero imports. It needs sufficient reliable domestic capacity so that imports are a choice for cost optimisation, not a necessity to fill a structural gap. This becomes more important in dry years. Drought has already cut hydropower across the region, and shortages can hit several countries simultaneously. When that happens, domestic generation is no longer just about cost. It is about energy security.

The 2030 Test Is Measurable

The restructuring should ultimately be judged by whether it delivers four things that matter to the economy. The first requirement is dependable generation. Zimbabwe is currently producing around 1,500MW on average, and that level needs to rise materially and stay ahead of the demand curve if industry is to plan with confidence. The second is cost per delivered kilowatt hour. Cabinet’s proposed tariff reduction will only be sustainable if lower operating costs, higher plant utilisation and reduced losses create real economic room for it. A cheaper tariff that is funded by under-recovery will just weaken the balance sheet the state is trying to make bankable.

The third is cash conversion. Government institutions, local authorities and strategic consumers must pay for electricity already consumed. Smart metering should help narrow the gap between units delivered and revenue collected, so that more of the power produced turns into cash for reinvestment. The fourth is new capacity. Zimbabwe needs several gigawatts of additional dependable supply before 2030. Private generation projects, Hwange rehabilitation, new renewable capacity, storage and transmission investment all have to move from announcement to commissioned output.

The World Bank previously estimated that electricity shortages cost Zimbabwe around 6.1% of GDP annually, including losses from generation inefficiency, network losses and the downstream cost of unreliable supply to businesses. That places the restructuring well beyond an administrative exercise. Zimbabwe is attempting to industrialise into a demand curve that could exceed 5GW within four years. The country currently produces about 1.5GW on average and is still spending substantial foreign currency importing the balance.

Combining ZESA into one company can improve the management and planning of that system. The economic return will appear when domestic dependable capacity rises, the import requirement falls, revenue collection improves, and electricity tariffs decline because the cost of producing and delivering power has genuinely fallen. A legal merger can be completed by Cabinet. The 3.7GW of implied supply expansion toward 2030 still has to be built.

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