Zambia’s Energy Plan Targets 10,000 MW, but Coal Clouds the Path

In August 2024, Zambia generated 1,019 MW of electricity. Its average demand sat at roughly 2,400 MW. On paper, the country had nearly 4,000 MW of installed capacity, more than enough to keep the lights on.

That gap between what Zambia owned and what it could actually produce is the foundation of everything that follows. It is why the government has committed to a 10,000 MW capacity target by 2031, a near-tripling of the national grid built on hydro, coal, and fast-scaling solar.

This target did not emerge from ambition alone. It was forged in a drought that exposed a structural weakness, and it is now backed by live financing deals, tangled with a coal-versus-climate tension, and tied to whether reliable power can unlock a mineral-rich economy.

Here is what the plan reveals about where Zambia is heading, and what it means for investors positioned across southern and eastern Africa.

When installed capacity means almost nothing

Zambia’s installed capacity looks reassuring until you ask what it can deliver under stress. Across 2024-2025 reporting, sources place total installed capacity between 3,811 MW (World Bank) and 4,108 MW (Energy Regulation Board), with figures from Global Legal Insights (3,871 MW) and the U.S. International Trade Administration (3,986 MW) sitting in between.

The problem is what sits underneath that number. Between 80% and 85% of installed capacity is hydropower, concentrated in a handful of large plants at Lake Kariba and Kafue Gorge. ZESCO’s hydropower capacity alone exceeds 2,900 MW.

That concentration made the 2024 collapse structurally inevitable once the rains failed. According to the International Monetary Fund (IMF), output at Lake Kariba fell by approximately 80% during the 2023-2024 drought. Global Legal Insights reported a 14.5% drop in national electricity output in early 2024.

The result was a country running on a fraction of its nameplate capacity.

The distance between those first two columns is the entire point.

Energy Minister Peter Kapala, May 2024 Average available generation had dropped to approximately 900 MW against average demand of 2,400 MW, a shortfall driven by poor hydrology.

This is the lens through which the entire 10,000 MW plan must be read. Headline megawatt targets mean little without diversification that reduces hydrological exposure. Any investor evaluating Zambia’s energy sector needs to internalise that distinction before looking at a single project figure, because nominal capacity and reliable supply are not the same variable here.

What drought-scale load shedding costs an industrial economy

The human cost was measured in hours without power. The IMF documented up to 20 hours per day of load shedding in Lusaka during the 2023-2024 drought, while Noventis recorded 12-17 hours per day across the Copperbelt.

The Copperbelt figure is where the economics bite. Copper and critical-mineral operations are electricity-intensive, and mineral processing does not tolerate interruption gracefully. Twelve to seventeen hours of daily shedding is not an inconvenience; it is a direct production constraint and a deterrent to new investment.

The IMF frames this as a systemic economic problem rather than a utility issue. For a country whose growth thesis rests on copper and battery metals, power insecurity feeds straight into investment risk assessments. That connection is why the response was structural rather than cosmetic.

The 10,000 MW plan: what it contains, and where the tensions sit

Zambia’s answer to the 2024 crisis is scale. The government targets 10,000 MW of generation capacity, cited as 2031 in ministry and budget documents and as 2030 in some presidential statements, with both timeframes appearing without clear resolution.

The near-term milestones reveal the plan’s actual character. The 2027 National Budget Green Paper specifies solar photovoltaic additions of more than 1,000 MW and coal-based generation additions of over 500 MW, both planned for 2027.

The World Bank Zambia energy transformation report, published in July 2026, provides direct governmental confirmation of the 10,000 MW target and the diversification strategy underpinning it, situating the capacity buildout within a broader economic growth and employment framework.

The generation mix breaks down across four components:

• Hydro: the existing base, still the largest single source but the one exposed to drought.
• Solar: more than 1,000 MW of planned additions for 2027, the largest near-term component.
• Coal: approximately 3,000 MW across the full plan, per President Hakainde Hichilema, with over 500 MW slated for 2027.
• Wind: a smaller element, appearing within the China-backed financing deal.

Here the strategic choice becomes live rather than resolved. The coal allocation is where energy security collides with climate finance.

The tension in two framings The International Hydropower Association (IHA) describes Zambia’s coal projects as “controversial,” warning they could worsen the drought conditions that caused the crisis in the first place. The IMF, by contrast, frames government plans to “double the capacity of thermal generation” as a direct and rational response to climate-shock vulnerability.

Both readings are legitimate, and both are correct in their own frame. Coal gives Zambia firm, dispatchable power that does not vanish when the rains fail. It also risks locking in carbon-intensive infrastructure at a moment when concessional climate finance increasingly excludes it.

The ZCCM-IH and Wonderful Group Zambia coal plant represents the most concrete near-term expression of that thermal commitment, packaging a 600 MW project into a structure that links the state mining investment vehicle directly to energy buildout financing.

What the 2027 pipeline tells you is that near-term deployment tilts toward renewables. Solar additions outpace coal additions in the immediate horizon, which means the headline 3,000 MW coal figure is a long-dated commitment rather than an imminent build.

The near-term character of the plan is more renewables-weighted than the coal number suggests. For investors, that timing distinction matters: the climate-finance friction is a future variable, while the solar opportunity is a present one. The IHA notes Zambia is separately exploring raising solar’s share toward 30% of generation, which would shift the balance further.

Capital signals: who is financing the buildout and what that reveals

A target is only as credible as the capital behind it, and Zambia has two headline deals that put real money against the plan.

Each deal illuminates a different dimension of how Zambia’s risk profile is being read. The US$1.5 billion China-backed framework, secured through the Zambia Development Agency, packages solar, wind, and coal into a single diversified bet, which signals that state-linked lenders are comfortable underwriting the full generation mix rather than cherry-picking renewables.

The Mercuria deal signals something more specific. When a commodity-linked trader enters a power financing arrangement, it tells you that energy production and commodity extraction in Zambia are being underwritten by the same capital.

The Mercuria power deal is the clearest expression of that convergence: a commodity trader underwriting energy infrastructure because the copper production thesis and the power availability thesis have become the same thesis in Zambia’s investment landscape.

That integration matters for how you frame the mining thesis. Investors tracking copper or critical minerals should treat reliable power availability as a variable inside the mining investment case, not a separate sectoral question sitting one room over.

The caution is scale. Even these headline figures fall well short of the total capital needed to reach 10,000 MW, and the U.S. International Trade Administration observes that the market’s structure and main actors remain largely unchanged. That implies the persistent obstacles are still in place. The research identifies three structural constraints on unlocking IPP financing at scale:

1. Utility creditworthiness: the reliability of the offtaker underpins every independent power project.
2. ZESCO balance sheet risk: the state utility’s financial position shapes whether new generators can be paid dependably.
3. Tariff structures: pricing that does not reflect cost undermines the bankability of new capacity.

These are the friction points that determine whether the deal flow deepens or stalls.

The macroeconomic floor that makes investment possible

The financing conversation only exists because the macroeconomic ground has firmed up. Following the completion of external debt restructuring, Zambia’s core indicators have improved markedly.

• Annual inflation fell to 6.1% in September 2026, down from 16.7% in December 2024.
• Gross international reserves climbed above US$5.5 billion, more than four months of import cover.
• The merchandise trade balance recorded a surplus of US$1.6 billion through the end of June 2026.
• The kwacha appreciated to an average of K17.81 per US dollar in 2026.

These are the preconditions for accessing concessional external borrowing, which is the government’s primary stated financing strategy. A proposed 20-year government bond is under consideration to extend the domestic yield curve and attract long-term capital.

None of this makes the buildout self-funding. Fiscal pressures persist, including climate shocks and revenue running below projections. But a stabilised fiscal environment is what lets concessional and private capital reach the IPP pipeline at all, which is why the macro layer belongs in the energy analysis rather than beside it.

Wiring the region: what cross-border transmission signals about Zambia’s long-term position

The 10,000 MW ambition is not purely a domestic sufficiency exercise. Two live interconnector projects reveal a grid-integration and infrastructure-export play running alongside it.

• Zambia-Tanzania-Kenya (ZTK) Interconnector: a 400 kV line linking Zambia to East Africa. Financial close was reached on 29 January 2025, and the Zambia section was commissioned on 11 April 2025, per the Southern African Power Pool (SAPP) Monthly Report. The implementation agreement involved the Government of Zambia, the World Bank, the European Union, and ZESCO.
• Malawi-Zambia (MAZA) Interconnector: a 192 km, 400 kV double-circuit line running from Nkhoma substation in Malawi to Chipata West in Zambia. Overall progress stood at 78% by mid-2025, with the Resettlement Action Plan for the Zambia section underway as of October 2025.

These are not administrative footnotes. Commissioning dates are milestone signals for anyone tracking southern and eastern African infrastructure.

SAPP framing Both interconnectors are key elements of Zambia’s strategy to participate in regional power trade and to buffer domestic drought-related shortages through cross-border exchanges.

That dual function is the point. Interconnection lets Zambia import power when its own hydro falters, and export surplus once new capacity comes online.

For the investment thesis, the export side changes the maths. Cross-border links give surplus generation a regional buyer base far larger than the domestic market alone, which improves the bankability of new projects by widening who can purchase the output.

The Tanzania energy link reinforces the export-platform reading of Zambia’s buildout: a power trader positioning for cross-border flow suggests that commercial arbitrage across the SAPP grid is already being structured, not simply planned, as new generation comes online.

Investors who read Zambia’s buildout as a purely domestic story are underpricing that regional optionality. The presence of an export market alters the risk-return profile of new capacity and makes the project pipeline more financeable than a domestic-only lens would suggest.

Reading Zambia’s energy plan as an investment signal for southern Africa

Pull the layers together and a three-part investment case emerges. Domestic power reliability functions as a mining-sector enabler. The regional transmission position turns Zambia into a potential energy-export platform. And the post-restructuring macroeconomic stabilisation is the access point for the long-term capital the plan requires.

Zambia’s copper production targets for 2031 are structurally dependent on the same power diversification timeline this article describes; the mining growth thesis and the energy buildout are not parallel tracks but a single compound risk where shortfalls in either variable constrain the other.

The credibility of that case does not rest on whether 10,000 MW is reached precisely by 2031. It rests on whether diversification away from hydro is real and fast enough to prevent a repeat of 2024. A second drought-scale crisis would set back both the energy plan and the broader investment thesis for Zambia’s mineral economy.

Two variables will do most of the work in determining the outcome, and one tension sits above them.

1. Renewable diversification pace versus hydrological risk: whether solar and other renewables scale quickly enough to cut the grid’s drought exposure before the next dry cycle.
2. Regulatory and tariff reform enabling IPP scale-up: whether utility creditworthiness, ZESCO’s balance sheet, and tariff structures improve enough to deepen private financing.
3. Evolution of the coal allocation relative to climate-finance conditions: whether the 3,000 MW long-horizon coal commitment holds, shrinks, or gives way to the IHA’s mooted 30% solar share.

The coal question is the most consequential unresolved tension. That 3,000 MW allocation is the pivot point between energy security and climate-finance accessibility, and investors with climate mandates should track how it evolves against the near-term solar pipeline of more than 1,000 MW for 2027.

Multilateral consensus from the IMF, World Bank, and Global Legal Insights holds that 10,000 MW is technically achievable only with rapid diversification, large financing volumes, transmission strengthening, and regulatory reform. That is not a verdict. It is a checklist, and it is the one worth watching.

This article is for informational purposes only and should not be considered financial advice. Investors should conduct their own research and consult with financial professionals before making investment decisions. Financial projections and capacity targets are subject to market conditions, climate variability, and various risk factors, and these forward-looking statements are speculative and subject to change based on policy and market developments.