This MCC insight shows how utilities can unlock “hidden capacity” through demand-side management, reducing curtailment, easing network constraints, and making solar-heavy systems more stable. Explore the programmes, incentives, and operational changes that turn flexible demand into a planning asset.
The paper explains why DSM is becoming essential as solar penetration rises, focusing on the utility’s role in designing and operating flexibility programmes. It discusses how tariffs, incentives, and smart enablement (e.g., digital platforms and automation) can shift or shape load to match solar output, reduce peak stress, and defer network reinforcement. The note also outlines implementation considerations, customer participation, measurement/verification, and how DSM should be valued within planning and regulatory frameworks to scale reliably.
The DFS started in late 2022 and encouraged people to lower their energy use during peak times over the winter months. From November 2024, the DFS has been extended to run all year round.
Over 2.6 million homes and businesses have taken part in previous years. This has saved an estimated 7,000 MWh of electricity at peak times — enough to power the lighting in 54,000 homes for a year.
High temperatures on 20 January 2025 resulted in a new maximum operational demand record of 4,486 MW and an underlying maximum demand record of 5,385 MW. During the operational demand peak, gas was the largest contributor with 2,526 MW (56.3%), with renewables contributing 573 MW (12.9%). Approximately 126 MW of demand side response was activated through various market and contractual mechanisms.
Sources:
• Dynamic time-of-use tariffs (UK DFS, SA trials) pay consumers to move consumption to the solar “shoulder” hours. Energy Saving Trust
• Automated device orchestration (smart-hot-water, EV chargers, heat-pumps)proved scalable to >100 MW fleets in AU & UK pilots. Octopus Energy
• Aggregated flexibility markets: EWEC’s 2025 tenders will procure DR as a firmre source, creating a revenue stack for smart-building aggregators. Abu Dhabi Department of Energy
• Multi-party coordination – UK ESO must aggregate bids from 30+ suppliers within six hours for each DFS event. Octopus Ener
• Solar oversupply risk – AEMO warns SA-VIC-QLD-NSW could face blackouts from too much rooftop solar without more flexible demand or batteries. The Guardian
• Consumer trust & governance – Ofgem’s 2023 call for input emphasised ease, safeguards, and engagement to unlock mass-market DSR. Ofgem
Sources:
• Arena
• Abu Dhabi Department of Energy
• Australian Energy Market Operator
• Digital engagement – UK DFS sends “24-hour ahead” SMS/app alerts; provider participation rates exceeded 80% during early ≥£3/kWh test events NESO
• Real-time data sharing – DEWA’s Distribution Network Smart Centre integrates AMI, rooftop-PV (Shams Dubai) and EV charger data for in real time to improve dispatch visibility DEWA
• Advanced Metering Infrastructure (AMI) – With around 30 million smart meters rolling out, the UK begins full half-hourly settlement from April 2025, a cornerstone for DFS scaling. Energy Manager Magazine, Professional Energy, Ofgem
• DER Management Systems (DERMS) – Abu Dhabi Phase-2 DR will target expansion across new sectors and participants via platform-enabled automation – building toward 200 MW by 2030, potentially even up to 1 GW. Abu Dhabi Department of Energy
• Flexible Trading Platforms – AEMO’s FTAs introduce behind-the-meter “priceresponsive” connection points, allowing direct wholesale bidding. Australian Energy Market Operator
UK: Mandating market-wide half-hourly settlement, establishing foundation for flexibility services like DFS (Ofgem, 2023). Ofgem
Abu Dhabi: Demand-Side Management Regulations (2025) legally oblige large energy consumers to participate when called, under the DSM & Energy Rationalisation Strategy 2030. Abu Dhabi Department of Energy
Australia: National Electricity Rules amendment for Flexible Trading Arrangements(consultation 2025) to introduce type 8/9 metering and Secondary Settlement Points,enabling behind-the-meter flexible loads (e.g. batteries, EVs, solar) to directly trade inwholesale markets. Australian Energy Market Operator
Yes – UK DFS requires same-day bid coordination from 30+ providers (OctopusEnergy),Australia faces misaligned incentives across retailers/network operators (Arena), for Abu Dhabi the current DSM regulations do not yet outline consumer consent mechanisms ordata/privacy protections for remote dispatch, posing a risk to uptake and trust (EmiratesNews Agency)
AEMO incorporates 2 GW of responsive demand in its 2025-35 Integrated System Plan (Australian Energy Market Operator); EWEC treats DR as an “avoided capacity investment” in its long-term electricity planning (Amaeya Media); UK ESO forecasts multi-gigawatt demand-side flexibility as essential to integrating a large renewables fleet by 2030 (NESO).
• South-Australia hot-water “solar-soaking” shifted ~45% of daily hot-water load into midday solar periods, helping utilize excess PV and reduce curtailment. Arena
• UK Saving Sessions displaced nearly 2 GWh of peak demand during winter 22/23, freeing capacity for wind & solar. Current
• Abu Dhabi’s DR Phase Two targets 200 MW of DR capacity by 2030, with pilot initiatives designed to help defer infrastructure upgrades. Energy News
By monetising flexibility (DFS pay-per-kWh), automating device control (AMI + DERMS), and embedding DR targetsinto resource-adequacy planning (AEMO, EWEC). These steps reduce both curtailment and fossil-back-up needs, accelerating solar adoption.
1. Flexibility pays: Real-world programmes now compensate customers £3–£6 per kWh shifted, proving that DSM can scale economically.
2. Regulation matters: Mandatory participation rules (Abu Dhabi) or half-hourly settlement (UK) unlock the business case.
3. Technology is ready: Smart meters, dynamic tariffs and cloud DERMS canorchestrate >100 MW blocks today.
4. Solar + DSM is synergistic: Each gigawatt of responsive load can enable 1–2 GW of extra solar with minimal curtailment.
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