South Africa's Grid Access Unit sits inside Eskom Distribution — the very business it undermines when it approves non-REIPPPP wheeling connections. With Q4 2026 site lock-ins approaching, C&I buyers must understand this structural conflict and escalate before signing any PPA or heads of agreement.

The GAU Conflict Is No Longer a Background Risk — It Is the Active Bottleneck

Every C&I energy buyer in South Africa currently navigating a wheeling PPA, securing a grid connection offer, or finalising site lock-in ahead of Q4 2026 is, whether they know it or not, running their project through a structural conflict of interest baked into South Africa's grid governance architecture. The Grid Access Unit (GAU) — the body that manages and facilitates grid access for independent power producers and generators — sits inside Eskom Distribution. And Eskom Distribution collects retail revenue.

The GAU sits inside the very business that collects retail revenue, so every wheeling connection it approves for a non-REIPPPP project erodes the income of the entity it reports to. This is not a theoretical concern raised in a policy paper. It is the structural reality governing every connection application your project is currently waiting on.

The Structural Incentive Problem, Explained

A further structural reform deserves serious consideration: moving the GAU out of Eskom Distribution and into the NTCSA or another independent entity. As it stands, the GAU sits inside the very business that collects retail revenue, so every wheeling connection it approves for a non-REIPPPP project erodes the income of the entity it reports to. This creates a clear conflict of interest that, combined with its lack of authority over the NTCSA resources it relies on for connection designs, breeds delay and perverse incentives.

This dual dysfunction is critical to understand. The GAU does not merely have a revenue incentive to deprioritise non-REIPPPP connections — it also lacks the internal authority to compel the NTCSA's engineering resources to design those connections promptly. The result is a double drag: perverse incentives on one side, institutional powerlessness on the other. For a C&I buyer waiting on a connection offer, both translate into the same outcome: months of unexplained delay, with no live queue register and no accountability mechanism.

Where there are projects waiting for access to the grid, Eskom should publish what that queue looks like and the order of the companies waiting for access — a live register. "You should be able to see what is going on," noted Sola Group CEO Amanda Wills. "Now it's like walking into a bank and you see a bunch of people there, but there is no queue and nobody to tell you what's going on." At this point, some companies are left with litigation, or the threat of litigation, as the only means of gaining access to the information they require.

The Growing Call to Move the GAU

The case for removing the GAU from Eskom Distribution is now being made explicitly and publicly by senior industry voices. "The solution is to take NTCSA out of Eskom Holdings so that Eskom is left with generation and distribution, and to then move the grid access unit into the transmission systems operator," said Wills. "That way there is no conflict. All they do is look after the network and manage fair and transparent access." Wills confirmed that this was indeed government's plan as it unbundled Eskom.

His chief complaint, however, was with the speed at which government was moving. That speed problem is not abstract. It has a direct cost to every project currently in the connection queue.

The political backdrop has been turbulent. In December 2025, Electricity and Energy Minister Kgosientsho Ramokgopa approved a revised structure under which NTCSA would remain a wholly owned Eskom subsidiary holding the assets. Creditors and foreign government funders objected, and Ramaphosa reversed course in his February 2026 State of the Nation Address, appointing a restructuring task team under National Treasury director-general Duncan Pieterse.

During the 2026 State of the Nation Address, President Cyril Ramaphosa announced the establishment of a dedicated task team to oversee the restructuring of Eskom to establish a fully independent, State-owned Transmission System Operator that will own and control transmission assets and be responsible for operating the electricity market. The NTCSA's own CEO, Monde Bala, has committed to this: Bala insisted that the TSO would be fully independent of the NTCSA and Eskom Holdings and would provide transparent and unbiased access to the transmission network, under the regulatory oversight of NERSA. "This will enable energy security and removes Eskom from the potential conflict of interest that may exist in relation to its dual role of being a generator and owner-operator of the transmission grid," Bala said.

The practical problem: there is a concern that these delays signal not only capacity constraints but also a reluctance within Eskom to facilitate greater access for private participants. Until the GAU moves, those concerns will remain structurally valid — regardless of what any policy statement says.

The Transmission Deployment Gap Is Compounding the Queue

Even if the GAU's conflict of interest were resolved overnight, the physical grid is falling behind. The NTCSA's 2025/2026 financial year target is 423.1km, with just over 108km completed as of October 2025. That is a delivery rate of roughly 25% against plan at the halfway point of the financial year — a transmission shortfall that directly limits how many new connections can actually be energised, regardless of how quickly applications are processed.

The grid was built for a centralised coal system, not a decentralised renewable energy market. The mismatch between the grid's legacy architecture and the C&I market's geographic distribution of demand and supply is not a temporary growing pain. It is a structural rebuild that requires a projected R440 billion to modernise and expand, against the utility's current balance sheet.

The NTCSA's own Transmission Development Plan projects that 56 GW of new generation capacity will be integrated between 2025 and 2034, which will require 14,500 km of new transmission lines, along with 210 transformers providing 113,000 MVA of capacity. The capital programme is real — Eskom's latest five-year capex plan for 2026–27 to 2030–31 totals ZAR 343 billion, with almost half (ZAR 157 billion) allocated to NTCSA alone — but capital allocations do not energise a factory in 2026.

The SAWEM Delay Is Making Wheeling Contracts Harder to Bank

Layered on top of the GAU bottleneck is the delayed launch of the South African Wholesale Electricity Market (SAWEM). The NTCSA has delayed the launch of SAWEM to the third quarter of 2026. Without the central automated clearinghouse that SAWEM was supposed to provide, municipalities are forced to manually manage these complex wheeling transactions. They must take the half-hourly meter data from the remote generation site and reconcile it against the half-hourly consumption data of the local factory, applying complex Time-of-Use tariff matrices to calculate the final billing credit.

For a C&I buyer trying to bank a wheeling PPA, this manual settlement environment is not merely inconvenient — it is a bankability risk. Lenders and equity investors need predictable, auditable settlement. The delay of the wholesale market has forced the entire industry into a holding pattern, relying on inadequate legacy systems to manage a modernising grid.

The curtailment dimension adds a further layer of PPA bankability risk. Developers, owners and investors in REIPPPP projects report that curtailment has risen sharply in 2026. According to these sources, the volume of energy curtailed in the first six months of the year was roughly an order of magnitude higher than in the whole of 2025. The same dynamics will increasingly bear on private wheeling, trading and behind-the-meter projects as the market deepens. How curtailment is governed, and who governs it, is therefore not a narrow contractual dispute between Eskom and a handful of IPPs. It is a test of whether South Africa can build a diversified electricity market that investors, financiers and generators are able to trust.

What C&I Buyers Must Do Before Q4 2026 Site Lock-In

Despite these structural headwinds, private generation is accelerating at a record pace. So far in 2026, IPPs have accounted for 100% of new generation capacity and looking at the current build pipeline, the private sector demand will have a strong influence on what power projects get built going forward. A Power Futures Lab briefing note shows a very large number of IPPs entering commercial operations phase in the first half of 2026. Seventeen IPP projects reached commercial operations date (COD), adding 1,920 MW to the grid — South Africa's largest-ever half-year addition of commercial IPP operational capacity. The market is moving. The risk is moving faster.

For any C&I buyer approaching Q4 2026 site lock-in, the following are non-negotiable escalation items before heads of agreement are signed:

GAU queue position and connection offer status: Demand written confirmation of your project's queue position, expected connection offer date, and the substation or injection point earmarked for your connection. Accept no verbal assurances. The absence of a live public register means your developer must extract this directly.
Wheeling agreement counterparty risk: Confirm whether the wheeling agreement is structured bilaterally with Eskom Distribution, via the municipality, or through a virtual structure. Each carries different curtailment exposure and settlement risk under the current pre-SAWEM environment.
PPA bankability review: Ensure your PPA contains explicit curtailment compensation language and is stress-tested against a scenario where SAWEM launches later than Q3 2026. Lenders are increasingly requiring this.
NTCSA connection design dependency: Ask your developer to confirm whether the GAU has formally engaged NTCSA's engineering team for the connection design study. This is the most common silent delay point in the current queue.
Escalation pathway: If connection offers are delayed beyond contractual milestones, establish in writing whether NERSA or the EIUG (Energy Intensive Users Group) dispute processes are available, and whether the developer has used them before.

The SolarXgen View

The GAU's structural conflict of interest is not a new grievance — it has been documented since the unit was established. What is new in 2026 is the convergence of factors that make it an active, material risk to Q4 project timelines: a transmission deployment gap running at roughly 25% of plan, a wholesale market that is still not live in automated form, curtailment volumes that have shocked REIPPPP investors, and a restructuring process that remains politically contested at the highest levels of government.

Genuine independence for the NTCSA is paramount for energy reform, as private investors in generation, storage and transmission need a neutral counterparty they can bank on. But an open, competitive electricity market cannot be achieved when the dominant generator also controls the gate to the grid.

Until the GAU moves — structurally and operationally — into an independent entity, every wheeling PPA carries a hidden regulatory risk that no tariff discount fully compensates for. C&I buyers who lock in sites in Q4 2026 without escalating these questions are not being bold. They are being uninformed.

Engage your developer, your legal team, and NERSA now. The queue is not transparent. The grid is not neutral. And Q4 2026 will not wait.