Power Without Borders: How Commercial Finance is Finally Unlocking Southern Africa’s Regional Grid

By Pranisha Sahadeo and Sindisiwe Mosoeu at RMB

Sub-Saharan Africa’s chronic energy deficit has long been framed as a crisis of generation.

The prevailing narrative suggests that the region simply lacks the megawatts required to fuel its industrial ambitions. Yet, a deeper diagnostic reveals that the true bottleneck is not merely a supply deficit, but the structural balkanisation of the continent’s electricity architecture. Historically, power grids have stopped rigidly at national borders, confined by isolationist infrastructure and inflexible regulatory frameworks.

Today, however, a quiet revolution is underway through various power pools on the continent, the most advanced being the Southern African Power Pool (SAPP).

Established in 1995 to link regional grids under the auspices of the Southern African Development Community (SADC), the SAPP historically functioned as a bureaucratic clearinghouse for state-owned monopolies to trade excess power via rigid, long-term bilateral agreements.

More recently, however, it has evolved to feature a dynamic, competitive day-ahead market. This platform allows members to buy and sell electricity in real-time, creating a borderless marketplace for electrons across a dozen nations, including South Africa, Mozambique, Angola, Tanzania and the DRC.

Yet, for years, this sophisticated trading pool lacked the one thing that could truly unlock its potential: independent, commercially bankable generation.

That paradigm has finally shifted.

The recent financial closure of a 100MW renewable energy solar PV plant developed by Etavi Renewables and ARCH Emerging Markets Partners represents the next frontier for the regional grid. This project is the first utility-scale renewable plant funded on a pure project finance basis and specifically structured to sell electricity directly into the SAPP’s day-ahead market on a pure merchant basis.

Facilitated by Rand Merchant Bank as the sole Initial Mandated Lead Arranger, what makes the commercial structure of this transaction a landmark for the regional economy is its radical departure from conventional risk allocation.

Traditionally, developing a large-scale Independent Power Producer (IPP) required a 20-to-25-year Power Purchase Agreement (PPA) backed by a sovereign-guaranteed national utility and/or Parent Company Guarantees.

In an era where national balance sheets are chronically strained and state utilities face severe operational headwinds, this traditional model has its limitations. By contrast, this project diversifies away from the traditional long term PPA offtake structure and carries 100% market risk, relying on the proven liquidity and spot-price dynamics of the SAPP pool. Another key feature of the SAPP market is that tariffs are denominated and settled in USD, effectively mitigating foreign exchange risk.

For a commercial banking sector that has historically suffered from acute risk aversion regarding sub-Saharan merchant power, the closure of this deal is a vital proof point.

It signals to international markets that regional energy trading is no longer the exclusive sandbox of Development Finance Institutions (DFIs) or concessional capital; it is now a bankable asset class for commercial finance. By establishing this precedent, the transaction provides a structural template that will inevitably crowd in further private capital, effectively liquidating the regional energy deficit over the next decade.

The economic implications for the SADC region are profound.

Consider the structural inefficiencies currently embedded in the subcontinent. Historically, when national utilities faced acute deficits, emergency power was often imported across borders at exorbitant, non-market rates—sometimes climbing as high as $0.40  per kilowatt-hour.

By introducing decentralized, privately funded renewable assets that trade dynamically on the day-ahead market, cheaper, cleaner power can be injected into the grid at a fraction of that cost, closer to localised renewable energy commercial baselines of roughly $0.06 per kilowatt-hour.

This introduces a healthy competitive tension into regional tariffs.

It allows power-starved jurisdictions to dynamically draw from the pool based on real-time supply and demand, liberating them from the fiscal chokehold of legacy encumbrances and punitive, long-term bilateral commitments.

Furthermore, a functional, highly liquid day-ahead market unlocks the inherent geographical advantages of the subcontinent.

Southern Africa possesses highly complementary energy profiles. Angola, for instance, boasts immense baseload hydroelectric potential, while South Africa and Botswana offer world-class, daytime solar irradiance. In isolation, intermittent solar assets present grid stability challenges. Integrated into a seamless regional grid via the SAPP, however, these resources complement one another perfectly. Botswana’s daytime solar can alleviate regional peak demand, allowing northern hydroelectric reservoirs to conserve water and deploy baseload power during the evening.

Yet, to fully realise this vision of a fluid energy exchange, the next wave of infrastructure investment must pivot aggressively toward transmission.

Unlocking generation is meaningless if the physical interconnectors between countries remain constrained. The opening of the merchant power market will inevitably act as a catalyst for a new class of transmission investments. As private capital sees a clear, profitable path to monetizing electrons across borders, the economic justification for investing in high-voltage cross-border interconnectors becomes undeniable.

This regional integration is precisely where South Africa’s own energy strategy must align.

As the continent’s most industrialised economy, South Africa cannot solve its energy crisis through an exclusively inward-looking lens. True energy security is collective. By actively participating in and supporting the expansion of the SAPP, South Africa transitions from an isolated system vulnerable to localized shocks into an anchor participant of a resilient, interconnected regional grid. Further, as the West and Eastern African Power Pools develop and the pools interconnect, the positive impact extends to the continent as a whole.

The 100MW Tati project may seem modest when measured purely against the aggregate regional deficit. But its value is not measured in megawatts; it is measured in blueprint equity.

By solving the complex structural, hedging, and tenor requirements inherent in unhedged merchant exposure, this transaction proves that the African energy market is ready for the future and so are the debt and equity markets.

As Africa’s energy leaders gather for upcoming policy summits, the focus must shift from state-funded procurement to market-led integration.

The true future of African infrastructure lies in breaking down the borders that have historically fragmented our economies.

By leveraging sophisticated commercial engineering and regional market pools, we can finally construct an energy architecture that is fluid, resilient, and undeniably self-sustaining.