Trader-Led Wheeling Is Reshaping C&I Procurement: What the Shift from Bilateral PPAs to Portfolio-Based Models Means for Your Next Energy Contract

The End of the One-to-One Deal: How Trader-Led Wheeling Is Rewriting the Rules of C&I Energy Procurement

South Africa's commercial and industrial (C&I) energy market has crossed a structural threshold. For years, the benchmark transaction was straightforward: one corporate buyer, one independent power producer (IPP), one bilateral power purchase agreement (PPA). That model served its purpose in an emerging private power market. But in 2026, it is rapidly becoming a relic of an earlier era.

A new procurement architecture is taking hold — one built around licensed energy traders, aggregated generation portfolios, and shared-risk commercial structures. For C&I energy users, the implications are significant, stretching from how contracts are structured and priced to how energy risk is managed across an organisation's entire footprint.

From Bilateral to Portfolio: What Has Changed?

The evolution has been fast. The first electricity trading licence was granted by NERSA in 2009. Since then, the pace of licence issuance has been exponential — with an estimated 23 domestic trading licences issued as of December 2025 alone. The market has moved from a handful of pioneering bilateral deals to a complex ecosystem of traders, aggregators, IPPs, and multi-site corporate offtakers.

In 2026, trader-led models are expected to become the dominant commercial model in the South African private power market, as the market moves beyond one-to-one bilateral agreements toward more aggregated, portfolio-based solutions. Under this model, licensed traders sit between independent power producers (IPPs) and end-users, coordinating supply and demand across portfolios, managing volume and balancing risk, and assuming much of the administrative and operational complexity historically carried by buyers.

Rather than trading physical electrons, these players are essentially facilitating accounting offset mechanisms — ensuring the construction and procurement of megawatts on the grid, then building a portfolio of clients or customers to buy those electrons. It is a fundamentally different commercial logic, and it changes everything about how a C&I company should approach its next energy contract.

Proof of Concept Is Already Here

The "one-to-many" generation model — where a single utility-scale solar farm wheels electricity to multiple corporate customers simultaneously — moved from theory to reality in 2025. South Africa now has proof of concept that large-scale private generation can serve a wide group of offtakers through a shared asset model, marking a structural milestone for the sector.

Landmark projects are validating the model at scale. The Naos 1 hybrid project, developed by SOLA Group near Viljoenskroon in the Free State, offers a compelling example: a 300 MW solar facility with 435 MWp of installed capacity and 660 MWh of battery storage has reached financial close and commenced construction. It is backed by long-term PPAs with Sasol and Air Liquide, and is the first utility-scale solar PV and battery project purpose-built to wheel electricity across the national grid to private end users.

In a similar vein, Yellow Door Energy signed a 20-year PPA with PowerX — South Africa's first licensed private sector electricity trader — to develop 24.5 MW of solar wheeling capacity at the Naledi Ya YDE Solar Park in Leeudoringstad, North West Province. Once commissioned, the project will supply clean energy to a portfolio of smaller offtakers via the national grid.

Why C&I Buyers Are Making the Switch

The commercial logic for C&I buyers is compelling on multiple fronts:

• Cost pressure from the grid is intensifying. NERSA has confirmed Eskom tariff increases of 8.76% from April 2026, followed by a further 8.83% in April 2027 — against the backdrop of a decade in which tariffs rose by approximately 180%. Waiting is no longer a viable strategy.
• Flexibility is replacing rigidity. Until recently, being locked into a 20-year PPA was the norm. But many businesses are now actively seeking shorter-term, more flexible contracts as the sector moves toward a merchant market model — and the trader-led structure accommodates this preference by design.
• Risk transfer is built into the model. Trader-led wheeling is gaining traction partly because C&I customers increasingly expect suppliers to share risk. Under portfolio-based models, the trader absorbs much of the volume, balancing, and administrative complexity that buyers previously had to manage themselves.
• Access without on-site infrastructure. Businesses with limited rooftop space or distributed operations across multiple sites can access utility-scale renewable generation without capital expenditure, using wheeling arrangements to aggregate supply from different plants into a single commercial structure.

The Regulatory Landscape: Maturing, but Not Yet Settled

The regulatory environment underpinning trader-led wheeling has advanced substantially, but friction remains. In November 2025, NERSA published its final draft Electricity Trading Rules and a Consultation Paper — a significant step toward formalising the market. The draft rules outline a phased opening of trading, starting with transmission and high-voltage customers, and set out licensing, reporting, metering data access, reconciliation, settlement, and supplier-switching protocols.

However, Eskom has challenged several trading licence awards by NERSA — including those of Discovery Green, GreenCo Power Services, CBI Electric Apollo, NOA Group Trading, and Green Electron Market — through court action, arguing that NERSA acted prematurely in the absence of a formal regulatory framework. This litigation has slowed momentum, leaving several licensed traders unable to participate meaningfully in the market despite holding valid licences.

Eskom's exclusion of traders from its virtual wheeling platform has drawn further criticism. The South African Wholesale Electricity Market (SAWEM), which was intended to go live in a transitional first phase in 2026, remains contingent on the completion of the Market Code and supporting regulations. The tension between legacy institutional interests and an emerging competitive market is real — and C&I buyers need to factor regulatory risk into their procurement timelines.

Financing presents another near-term constraint. More traders, more off-takers, and more complex structures are placing pressure on banks that remain geared for simpler, single-buyer deals. Reaching financial close on multi-tenant projects is already taking longer than developers would like — though as more portfolio projects come online, banks will gain access to better data and risk will become easier to price.

What This Means for Your Next Energy Contract

If your organisation is approaching a contract renewal or entering the private power market for the first time in 2026, the bilateral PPA is no longer your only option — and in many cases, it may no longer be your best option. Here is what to consider:

• Ask who is aggregating supply. Understand whether the trader you are working with holds a valid NERSA trading licence, has established offtake relationships with multiple IPPs, and has demonstrated the ability to manage portfolio balancing in practice.
• Interrogate the risk allocation. Portfolio-based models distribute risk differently from bilateral PPAs. Ensure you understand what volume risk, curtailment risk, and grid access risk you are accepting — and what the trader retains.
• Don't anchor on 20-year terms. The market is moving. Shorter-duration structures and step-in rights are increasingly available and may better suit your business's evolving ESG commitments, capex cycles, and operational footprint.
• Factor in wheeling charges and municipal readiness. Wheeling charges — including network use charges, connection costs, and municipal levies — vary significantly by network. Municipal participation and financial standing remain a constraint on virtual wheeling access in some areas.
• Act with urgency. Grid capacity is tightening. Seventy-five percent of all private renewable applications are concentrated in the Eastern, Western, and Northern Cape — regions that have officially reached zero remaining firm capacity in some connection queues. Early movers are far better positioned to secure favourable pricing and grid access.

The SolarXgen Perspective

At SolarXgen, we see trader-led wheeling not as a threat to project-based solar development, but as a complementary evolution of the market. The optimal energy strategy for most C&I clients in 2026 is a layered one: on-site solar and BESS for baseload self-supply and resilience, complemented by wheeled renewable power from portfolio-based traders for scale and flexibility. The shift from bilateral PPAs to portfolio models is accelerating — and the C&I businesses that understand this shift earliest will hold the strongest negotiating positions in an increasingly competitive procurement environment.

Bottom line: The energy contract you sign in 2026 will look structurally different from the one you signed in 2022. Trader-led wheeling is reshaping the commercial architecture of C&I procurement. Understanding the model — and the regulatory terrain around it — is now a core business competency, not a technical afterthought.