Battery Storage Expansion and GB Power Market Tightness: What Changed This Week — 08-13 Jan 2026 The first full week of January 2026 brought extreme system stress to the GB energy market. A cold snap drove demand to its highest level in seven years, while low renewable output and tight margins sent prices soaring. Amid these challenges, battery storage continues to expand its role as a cornerstone of flexibility and grid stability. Here's what changed this week and why it matters for the future of the GB power market.

Key Developments

1. UK power demand hits seven-year high, prices surge to £1,040/MWh

On 13 January 2026, UK power demand spiked to levels not seen since 2019, as a prolonged cold snap combined with low renewable generation. National Grid ESO was forced to intervene in interconnector markets, buying back exported power at a record £1,040/MWh to maintain system balance. This extreme price volatility underscores the value of flexible capacity for battery storage operators, who can exploit price arbitrage by discharging during peaks and charging during off-peak hours. Envirotec Magazine, 13 Jan

2. National Grid ESO launches Open Balancing Platform

National Grid ESO introduced the Open Balancing Platform (OBP) this week to streamline dispatch for smaller assets, including battery storage. The platform aims to reduce costs and increase participation in balancing services. This modernisation effort could improve dispatch predictability for battery operators and reduce skip rates, enabling higher revenues from ancillary markets. National Energy System Operator, 13 Jan

3. Record 28.6 GW of battery storage approved in 2025

Data for 2025 revealed that GB approved a record 28.6 GW of new battery storage capacity, nearly doubling from 2024. This surge reflects the growing need to manage variable renewable generation, which produced a record 106 TWh last year. Developers should anticipate rising competition, but also opportunities to optimise revenue stacking across energy arbitrage, balancing services, and capacity markets. The Guardian, 30 Dec

4. Interconnector capacity reaches 8.4 GW

GB’s interconnector capacity hit a new milestone of 8.4 GW in January 2026, driven by the full restoration of the IFA link to France. Interconnectors accounted for 19% of the generation mix during peak import days, helping to stabilise domestic supply. However, higher interconnector flows also add complexity for battery operators, who must navigate cross-border price volatility to optimise arbitrage revenue. National Grid, 13 Jan

5. Shift to 30-minute state-of-charge reporting in Balancing Mechanism

National Grid ESO’s transition to 30-minute state-of-charge (SoC) reporting for battery assets within the Balancing Mechanism took effect this week. This change reduces skip rates and improves dispatch certainty, creating better revenue opportunities for battery operators. Traders should adapt bidding strategies to align with the new reporting intervals. Modo Energy, 13 Jan

6. Drax submits planning for 2 GWh battery project

On 8 January 2026, Drax announced plans for a 2 GWh battery storage system at its North Yorkshire site. If approved, this project would rank among the largest in the UK and reflects growing investor confidence in the flexibility market. Large-scale projects like this could increase competition for ancillary services but also validate the business case for battery storage. Argus Media, 8 Jan

Why This Matters This week’s developments highlight both the opportunities and challenges facing GB’s energy market as it navigates the twin pressures of decarbonisation and system reliability. The record-high prices of £1,040/MWh demonstrate the critical value of flexibility in a grid increasingly reliant on intermittent renewables. Battery storage operators are uniquely positioned to capture revenue during such spikes, but the rapid expansion of capacity—28.6 GW approved in 2025—means competition will intensify. The launch of the Open Balancing Platform is a game-changer for smaller assets, offering greater access to balancing services and reducing operational inefficiencies. Coupled with the transition to 30-minute SoC reporting, battery storage operators can expect improved revenue certainty. However, these benefits come with increased complexity, as interconnector flows and renewable variability create volatile market conditions. For developers, the approval of large-scale projects like Drax’s 2 GWh system signals strong investor confidence and a maturing market. However, the growing pipeline could compress ancillary service prices, making sophisticated revenue stacking strategies essential. Developers should prioritise sites with co-location potential to optimise connection agreements and reduce costs. Traders face a dynamic landscape, with high interconnector flows, volatile wholesale prices, and tight system margins. The ability to leverage real-time data and adjust strategies for intraday and balancing markets will be key to maximising returns. For policymakers, the week’s events underscore the need for continued regulatory support, including incentives for long-duration storage that can address seasonal challenges. Looking ahead, the integration of 8.4 GW of interconnector capacity and the ramp-up of Viking Link will alter price formation in GB and neighbouring markets. Battery operators must incorporate cross-border flows into their models to remain competitive. Additionally, as wind and solar penetration increases, the importance of hybrid solutions—combining storage with renewables—will grow.

Picking Take When markets hit £1,040/MWh, that’s not volatility—it’s a structural signal. The GB power market is screaming for flexibility, and battery storage is answering. But with 28.6 GW approved in 2025 alone, standing still isn’t an option. Developers must innovate, traders must adapt, and policymakers must accelerate. The next decade of energy will be won by those who act now. ```markdown

Battery Storage Expansion and GB Power Market Tightness: What Changed This Week — 08-13 Jan 2026