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Stacking battery revenue: arbitrage, capacity, DSR and resilience

Commercial battery storage in the UK rarely delivers a payback on any single market. By combining price arbitrage, capacity market payments, demand‑side response and resilience services, owners can create a robust revenue stack that meets investor return thresholds. This article explains how the stack works, where it adds value and what risks need managing.

By TUS Trade Desk — Commercial Energy Consultants•Published 21 August 2026•6 min read

Stacking multiple revenue streams is the only realistic path to a commercial return on UK battery storage projects. A single market – whether energy arbitrage or capacity – rarely covers capital costs, let alone the operational expense of a 5‑10 MW system. The thesis of this piece is simple: optimise the battery's flexibility across all available markets, align dispatch with grid constraints, and use data‑driven control to capture the incremental value each service offers.

Why a single revenue stream falls short

Price arbitrage limits

Energy arbitrage exploits the spread between peak and off‑peak wholesale prices. In 2023‑24 the average UK price differential was roughly £15 MWh, enough to generate about £75 k per MW‑year of storage. Even with a 2‑year payback target, that revenue covers only a fraction of the £2‑3 million capital outlay for a 5 MW battery. Moreover, arbitrage earnings are highly volatile and erode quickly as more storage enters the market.

Capacity market alone insufficient

The Capacity Market (CM) offers a firm payment for being available during system stress. A 5 MW battery can earn roughly £30 k per MW per year under the latest auction, totalling £150 k annually. While this is a reliable cash flow, it still leaves a large gap to meet typical investor hurdle rates of 8‑10 % on a 10‑year horizon.

DSR and resilience as add‑ons

Demand‑Side Response (DSR) contracts, such as those under the Ofgem‑run Flexible Power programme, pay between £30‑£50 k per MW per year for rapid load reduction. Resilience services – including black‑start capability and network support during outages – are increasingly valued by Distribution Network Operators (DNOs) under the Enhanced Resilience Scheme (ERS). These contracts can add another £20‑£40 k per MW per year, but they are only accessible if the battery can demonstrate high availability and fast response.

Building a revenue stack

Mapping market participation

A disciplined stack begins with a matrix of eligible markets:

Service	Typical UK revenue (per MW‑year)	Key regulator / mechanism
Energy arbitrage	£75 k	Ofgem wholesale market
Capacity market	£150 k	Ofgem Capacity Market auction
DSR (flexible power)	£40 k	Ofgem Flexible Power
Resilience (ERS)	£30 k	Ofgem Enhanced Resilience Scheme
Grid services (frequency response)	£25 k	NESO Frequency Response Service

By overlaying the battery's technical profile – round‑trip efficiency, depth of discharge, and response time – with these revenue columns, the optimiser can schedule each MW‑hour to the highest‑value service that is simultaneously available.

Timing and control optimisation

The core of stacking is a real‑time optimisation engine that respects market gate‑closing times, DNO constraints (TNUoS and DUoS charges), and battery health limits. For example, a battery might discharge during a £200 MWh peak price window for arbitrage, then immediately reserve capacity for a CM event later in the week, and finally hold a small state‑of‑charge buffer for a DSR call that requires a 5‑minute response. Studies show that a well‑tuned stack can lift total annual revenue by 30‑45 % compared with arbitrage alone.

Leveraging TUS flex management expertise

TUS Group manages over 150 GWh of flex assets across the UK, beating supplier projections by 20 % in the last 12 months. Our 30‑plus supplier panel gives us access to the most competitive DSR contracts and capacity allocations. By integrating TUS’s proprietary Yolk portal – a free, data‑rich platform that has delivered an average 27 % switching saving for clients – battery owners can benchmark rates, automate contract switching and ensure they are always positioned in the highest‑value market.

When does the stack work?

Size and location of the battery

Larger batteries (≥5 MW) benefit from economies of scale in the Capacity Market and can provide multiple DSR events per day without compromising availability. Location matters: assets connected to constrained zones – for instance the North‑East or South‑West England distribution networks – can capture higher congestion‑related price spikes, boosting arbitrage spreads.

Grid constraints and ancillary services

NESO’s Frequency Response Service (FRS) and the System Services Market reward fast, high‑precision response. Batteries that can deliver sub‑second response and maintain a high state‑of‑charge reserve qualify for these ancillary payments, adding roughly £20‑£30 k per MW‑year. Additionally, participation in the Transmission Network Use of System (TNUoS) and Distribution Use of System (DUoS) schemes can be optimised to minimise charge exposure, further improving net cash flow.

Regulatory environment and contracts

The latest SECR (Streamlined Energy and Carbon Reporting) requirements encourage firms to disclose flexibility assets, making DSR contracts more attractive to corporate buyers. The Climate Change Levy (CCL) exemption for battery‑enabled demand response also improves the economics for industrial users, creating a secondary market for capacity‑selling.

Risks and mitigation

Market price volatility

Wholesale price spreads can narrow during low‑demand winters, reducing arbitrage upside. Mitigation includes locking in forward contracts for a portion of arbitrage revenue and maintaining a diversified stack so that a dip in one market is offset by stable capacity or DSR payments.

Operational availability

Resilience and DSR contracts penalise unavailability. Regular performance monitoring, predictive maintenance, and leveraging TUS’s 150 GWh flex‑management experience can keep availability above the 95 % threshold required for most ERS agreements.

Bottom line

A UK battery that only chases energy arbitrage will struggle to achieve a credible payback. By stacking arbitrage, capacity market, DSR and resilience services – and by using a data‑driven optimisation platform backed by TUS’s proven flex‑management track record – owners can lift total revenue by up to 45 %, delivering a 2‑3 year payback on many projects. The key is disciplined market mapping, real‑time control, and a partner that can navigate the complex regulatory landscape.

FAQs

Q: Can a 2 MW battery still benefit from stacking? A: Yes, but the revenue uplift is lower; focus on high‑value DSR and frequency response where the per‑MW payment is similar to larger assets.
Q: How does the Yolk portal improve revenue stacking? A: Yolk aggregates live market rates, automates contract switching and provides analytics that help keep the battery in the highest‑value service at any moment, delivering an average 27 % saving on procurement costs.
Q: What is the typical contractual horizon for capacity market and DSR? A: Capacity Market contracts run for three years, while DSR agreements are usually annual with optional roll‑over, allowing flexibility to renegotiate as market conditions evolve.