City Power's 1 October 2026 financial ring-fencing and trading licence activation — against a backdrop of a R19.1-billion overdraft and a R44.25-billion infrastructure backlog — fundamentally reprices every wheeling tariff model, BESS dispatch stack, and PPA counterparty risk assessment for C&I sites across Sandton, Midrand, and Soweto in Q4 2026.

The Johannesburg Electricity Wildcard: What City Power's 1 October 2026 Trading Licence Activation Means for Every C&I Offtaker in Sandton, Midrand, and Soweto

For CFOs and property managers operating commercial and industrial (C&I) assets behind City Power's distribution network, the first of October 2026 was not merely an administrative milestone. It was the moment a financially distressed distributor — one carrying a R19.1-billion internal overdraft and a R44.25-billion infrastructure backlog — formally activated a new identity: active electricity trader. That identity shift has direct, repricing consequences for every wheeling tariff model, every behind-the-meter battery energy storage system (BESS) dispatch stack, and every power purchase agreement (PPA) counterparty assessment you are currently running across Johannesburg-embedded sites.

This is not abstract regulatory theory. The numbers on your Q4 2026 energy invoices are already encoding this new reality. Here is what you need to understand — and what you need to do before year-end.

The Financial Context: A Utility in Structural Distress

From 2019 onward, a persistent and widening gap has opened up between City Power's expenditure and revenue. By 2025, the deficit amounted to R4.3 billion, excluding capital grants and contributions — and City Power's net internal overdraft with the City had reached approximately R19.1 billion by 31 March 2026.

Of the 13 entities delivering services in the city, City Power towers above the rest, with revenue of R22.3 billion and expenditure of R26.6 billion in the latest financial year, without counting capital grants and contributions from elsewhere. That structural deficit is not cyclical; it is chronic.

Electricity Minister Kgosientsho Ramokgopa described the problem starkly: "For every R100 of bulk purchases, City Power can only reticulate about R70. They've already lost R30, even before they can collect. So, you can see that's a race to the bottom."

The utility was also owed about R13.3 billion by customers at the end of June 2026. Its infrastructure backlog is said to be at R44.25 billion, and planned maintenance and capital expenditure has repeatedly fallen below target. Much of the 19,000 km of cabling City Power oversees is in decay, and it reported more than 2 million forced interruptions in just eight months — some customers went weeks without power.

The 1 October Ringfencing: Structural Reform or Revenue Arithmetic?

From 1 October 2026, City Power is officially "ringfenced," according to a letter to customers dated 21 September 2026 from the utility's acting CEO, Charles Tlouane. The substance sits in one sentence: "70% of electricity revenue collected on behalf of City Power will be transferred to City Power within 48 hours of collection, while the City of Johannesburg will retain the remaining 30%."

For CFOs, this arrangement demands immediate scrutiny. The letter does not say what becomes of City Power's internal overdraft with the City, which reportedly stood at about R19.1 billion on 31 March 2026. Billing and collection were pulled into the City, electricity revenue was swept into the municipal pool, and City Power was handed back whatever the City decided it could spare. The new 70-30 split formalises this arrangement but does not resolve the structural deficit that underpins it.

Some R5.25 billion of City Power's debt to Eskom was reportedly settled in August 2026, but there has been no official statement on where the money came from. A further R1.86 billion was due at the end of August, and the City has been mum on the source of these funds, leading to speculation that this came from the Ministry of Finance.

For any C&I offtaker evaluating City Power as either a grid counterparty or a wheeling facilitator, the creditworthiness question is now inseparable from the tariff question.

The Trading Licence Dimension: From Distributor to Active Trader

City Power's responsibilities include buying electricity from power producers and supplying it to the public, and installing and maintaining the electrical infrastructure in the City of Johannesburg. But the activation of its trading licence role — originally granted by NERSA in December 2001 and now being operationalised within the new NERSA market reform framework — means City Power is no longer simply a pass-through distributor. It is now a licensed market participant capable of procuring, aggregating, and on-selling electricity bilaterally.

One of NERSA's most significant current initiatives is the development of Trading Rules, which will govern participation, transactions, and compliance within South Africa's future competitive electricity market. These rules were in their second round of public consultation, with NERSA expecting to finalise them by September 30, 2026.

NERSA published its revised draft Trading Rules for the bilateral trading market (Version 01, dated 12 April 2026) together with a consultation paper — but renewable energy entrepreneur Frank Spencer warned that the proposed rules impose volume caps, broad non-bypassable charges, and structural barriers that will constrain generators and traders alike for years.

These rules arrive in the context of Eskom's court challenge to the five trading licences granted by NERSA in 2025 — a challenge that was stayed, not withdrawn, in February 2026 pending finalisation of the regulatory framework. City Power's own trading activation therefore occurs in a legally contested, structurally unresolved regulatory environment — a critical risk factor for any C&I buyer signing a 10–20 year PPA that assumes stable wheeling access through the City Power grid.

Wheeling Tariff Design: The Four Variables That Have Changed

The City of Johannesburg Council has approved wheeling tariffs to enable third-party energy trading over the City Power grid, with customers billed for full consumption and third-party supply discounted at WEPS rates. City Power bills Johannesburg businesses on one of three tariffs, and every rate line rose 9.01% on 1 July 2026.

Four variables have materially shifted the wheeling tariff calculus for Sandton, Midrand, and Soweto-embedded C&I sites in Q4 2026:

Non-bypassable charges: Under the evolving NERSA framework, customers receive an invoice from the network service provider for total metered consumption at the full applicable tariff, while generators or traders issue a separate invoice for wheeled energy delivered — and use-of-system charges, administrative fees, and fixed network charges remain payable in full to the NSP. This dual-invoice structure means the "wheeling discount" is narrower than many 2024-era PPA models assumed.
Tariff escalation trajectory: That is an average of around 11 to 12% a year, compounded, on the lines a Johannesburg business actually pays. Any PPA model using a lower escalator assumption is now underpricing Eskom-parity risk.
Market pricing benchmarks: As of early 2026, indicative all-in tariffs for solar-only wheeled PPAs are typically R1.15–R1.45 per kWh (all-in delivered), rising to R1.35–R1.75 per kWh for hybrid solar-plus-storage structures, with materially higher availability.
Trader compliance overhead: Under the new NERSA rules, traders must submit semi-annual and annual reports to NERSA providing information on PPAs, supply arrangements, counterparties, and energy volumes — compliance costs that will be passed through to offtakers in future contract pricing.

Behind-the-Meter BESS Dispatch Economics: The City Power Premium Recalculation

For CFOs and property managers who have deployed — or are evaluating — behind-the-meter battery energy storage at Johannesburg C&I sites, the City Power trading activation resets the arbitrage model in two important ways.

First, City Power's new trader status means it can, in principle, signal time-of-use pricing with greater granularity to incentivise — or discourage — grid export and self-dispatch behaviours. For BESS assets optimised to arbitrage the spread between City Power's off-peak and peak tariff windows, any tariff redesign that compresses peak premiums or introduces new non-bypassable fixed charges directly degrades the dispatch economics modelled at financial close.

Second, the infrastructure reality behind the trading licence must be priced in. City Power's sweeping overdraft account increased from roughly R15.7 billion at the start of the financial year to about R20.3 billion by the end of September — meaning the grid that BESS dispatch strategies depend on for reliable import and export settlement is operated by a utility whose capital maintenance budget has been chronically underfunded. For C&I buyers, a PPA that lacks an associated BESS component increasingly means exposure to evening peak Eskom pricing — the very hours when tariffs bite hardest. But the BESS itself must be sized to handle grid unavailability scenarios that have become statistically more frequent across the City Power network.

PPA Counterparty Risk: The Three Questions Every CFO Must Ask

The shift from pure distributor to active electricity trader means City Power is now a potential counterparty — not just a grid operator — in Johannesburg-area wheeling transactions. That status change requires a fresh counterparty risk assessment. Three questions every CFO must resolve before Q1 2027:

Revenue ring-fencing enforceability: The 70-30 arrangement announced from 1 October 2026 is a Council resolution, not a legislative guarantee. The CDE noted that electricity revenue was being transferred into the City's consolidated revenue pool instead of being ring-fenced for City Power — a practice the new arrangement is designed to end, but whose enforcement mechanism remains opaque.
Eskom supply continuity: A further R2.3 billion in historic debt remains, along with a current account of R1.86 billion that fell due at the end of August 2026. City Power's ability to maintain bulk supply from Eskom — the upstream source for all wheeled energy delivered over its network — is directly tied to debt resolution that remains publicly unverified in its funding source.
Regulatory ambiguity pass-through: Local government representative groups have expressed real concern over the potential impact of an unregulated traders' market on municipal revenue and have requested that NERSA suspend the processing of trading licence applications until such time as the Trading Rules are formalised. Any PPA signed before the final Trading Rules are gazetted carries residual price-revision risk if new non-bypassable charges are introduced that alter the delivered economics.

Practical Recommendations for CFOs and Property Managers

The City Power trading licence activation is not a reason to pause energy procurement decisions — the tariff escalation trajectory and infrastructure risk of inaction are more expensive than action under uncertainty. But it is a reason to reprice your assumptions before locking in new commitments.

Audit all in-flight PPA models for non-bypassable charge assumptions. Any wheeling PPA modelled before Q3 2026 likely underestimates use-of-system charges under the evolving NERSA framework. Rebuild your all-in delivered cost from current tariff schedules.
Structure BESS contracts with City Power tariff-redesign optionality. Include provisions allowing dispatch strategy adjustment if City Power introduces new peak tariff definitions or time-of-use windows as part of its trader role activation.
Require credit-linked step-in rights in any wheeling PPA that routes through the City Power network. With a R19.1-billion overdraft and unresolved upstream Eskom debt, City Power's financial trajectory must be treated as a PPA performance risk, not merely a background macro factor.
Prioritise behind-the-meter generation for Soweto-embedded sites. The infrastructure decay risk in historically underinvested network zones is highest, making grid-independence through on-site solar-plus-BESS the most defensible energy strategy for C&I assets in those areas.
Engage a specialist energy legal adviser on Trading Rules finalisation. NERSA's Trading Rules are expected to be finalised in final form before year-end. Any contract executed before gazette should contain a material adverse change clause tied to regulatory pricing changes.

The SolarXgen View

City Power's transformation from pure distributor to active electricity trader is structurally significant — but it arrives wrapped in a financial distress profile that cannot be separated from the regulatory opportunity. The R19.1-billion overdraft overhang, the unresolved infrastructure backlog, and the contested NERSA Trading Rules framework mean the City Power trading licence is both an enabling instrument and a risk multiplier for every C&I site behind its network. The right response is not to wait for resolution — it is to build contractual, technical, and financial structures that perform across multiple City Power credit scenarios. That is exactly what a well-designed solar-plus-BESS behind-the-meter strategy, combined with a robustly drafted wheeling PPA, is designed to deliver.