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Contact Chris Moore at CM Energy Insight. Senior UK energy advisory for investors, developers, and asset owners. First conversation always free and confidential. Address Pearmain House, The Orchard, Westergate Street Westergate, Chichester PO20 3RH Email chris@cmenergyinsight.com Phone +44 7884 231 261 Social Media First Name Last Name Email Message Send Thanks for submitting! We will reply as soon as possible. Contact Please send me an email, text or fill in the contact form here.

From need statement to FID-ready investment case. CM Energy Insight provides senior advisory on renewable and flexible energy asset development across the UK and Europe. From strategic need, through siting, planning, procurement, and commodity agreements to FID-ready investment case. Asset Development Contact CMEI Most Energy Projects Don't Fail at Construction. They Fail in Development . From site identification to FID, the critical failure points are rarely technical. They are the intersections — where commodity risk meets capital structure, or where policy shifts meet offtake terms. As illustrated across this website, the UK energy market is in a period of structural transformation. Clean Power 2030 demands a deployment rate of new generation and storage capacity without precedent in peacetime. The grid connection queue has been reset. Planning reform is underway. Offtake markets are being redesigned. Capital is available — but selective. Investors are funding projects led by teams that can demonstrate they understand what has changed and why , not just what the textbook says. In this environment, the quality of project development and its VDR documentation — the decisions made between concept and Final Investment Decision — determines whether an asset gets built, gets funded, and generates the returns its sponsors expect. What Development Actually Involves in 2026 Energy asset development has never been a straight line, but the number of intersecting variables has multiplied in 2026 !. A BESS project that looked straightforward two years ago now needs to resolve gate 2 connection positioning, post-auction capacity market viability, a revenue stack that is shifting quarter by quarter, a LDES cap-and-floor interaction assessment (if duration is above four hours), location price signals, and a financing structure that satisfies lenders who have become significantly more sophisticated in their due diligence requirements!! A gas peaker project faces a different set of questions — but no simpler ones. T-1 and T-4 capacity market auctions remain open to flexible gas, but the policy trajectory is clear: REMA's wholesale market reform and the Clean Power 2030 programme will progressively marginalise unabated gas(??). A credible development case must now model the asset's economic life under zonal pricing scenarios, account for potential carbon cost trajectories, and present a coherent end-of-life or (BESS, SMR?) conversion pathway. Lenders and investors are asking these questions at the point of commitment — which means developers must have the answers before they go to market. SMR development occupies a different position on the risk curve entirely. The first (Rolls-Royce) SMR fleet at Wylfa will not reach FID until approximately 2029. Between now and then, the programme will consume significant pre-FID advisory and development resource — in owner's engineering, commercial structuring, offtake design, supply chain development, and regulatory engagement. The CM Energy Insight Development Pathway - 40 years of experience. Development advisory is not generic. The value it delivers depends entirely on whether the adviser has (repeatedly) done this before — across technologies, across market cycles, and across the full journey from concept need statement to FID. CM Energy Insight brings that track record. The core development pathway covers: Concept scoping and market positioning — establishing the commercial and political rationale, technology selection criteria, site and grid strategy, and the realistic development timeline before development capital is budgeted. Grid connection strategy and Gate 2 positioning — analysing transmission line location and queue position, connection offer risk, and the strategic options available to a project under the reformed NESO connection framework. Permitting and planning strategy — development consent sequencing for Nationally Significant Infrastructure Projects (NSIPs) and locally determined consents, including environmental impact assessment management and stakeholder engagement. Procurement and EPC strategy — competitive procurement design, contractor risk allocation, insurance design, and contract terms for a market in which equipment supply chains are stretched and cost certainty is harder to achieve than at any point in the last decade. Commodity agreements and offtake structuring — PPA term sheets, route-to-market strategy, capacity market positioning, and flexibility market access — all calibrated to the current state of the market, not a model built three years ago. The FID-ready investment case — a fully integrated project brief, financial model, credible independent market analysis, shareholder agreements, lender facility agreements, risk register, insurance design, that a serious investor, lender, or project finance bank can read without supplementary explanation. Why Boutique Development Advisory Delivers More Large advisory firms build detailed models. CM Energy Insight builds investment cases . The difference is not a matter of scale — it is a matter of accountability. When a senior practitioner leads the engagement from concept to close, the development case is internally consistent, the assumptions are defensible, and the commercial judgements are made by someone with direct and credible market experience — not delegated to an analyst in a workstream. In a market where the cost of a development error — a missed gate 2 offer, a mis-specified PPA, a planning condition that triggers a delay — can destroy project economics, the quality of the development team is not a secondary consideration. It is the primary risk. CM Energy Insight works with asset developers, asset owners, and project sponsors at every stage of the development lifecycle. To discuss your project, request a conversation. Let's Start a Conversation Whether you need a sounding board on a live deal, an interim project lead, or a fresh perspective on market strategy — the first conversation is always free and always confidential. Phone: +44 7884 231 261 Email: chris@cmenergyinsight.com LinkedIn: https://uk.linkedin.com/company/cmenergyinsight Name* Email* Company* Message* Send Message

Clean Power 2030 - Clean Power 2030: The Action Plan Unpacked 95% clean generation by 2030 is government policy. AR7 auctions, flexibility roadmaps, and non-commodity cost pressures all flow from this single target. Clean Power 2030 Contact CMEI Ambition, Architecture, and the Awkward Questions Nobody Is Asking "Clean Power 2030 lies on the very edge of what can be done." - Chris Stark, Mission Control Lead, NESO That is not the language of confident delivery. It is the language of a programme where the margin for error is essentially zero — and where the consequences of slippage will be felt not in 2030 but right now, by every developer trying to finance a project, every investor modelling a revenue stack, and every industrial consumer watching their transmission charges rise by 60% in a single year. Clean Power 2030 is the most ambitious peacetime infrastructure programme this country has attempted. It deserves serious analysis, not cheer-leading. This page provides both. What Clean Power 2030 Actually Requires - RADAR Published in December 2024, the Clean Power 2030 Action Plan sets a single headline target: by 2030, at least 95% of Great Britain's electricity must come from low-carbon sources , with no more than 5% from unabated gas. Carbon intensity must fall from 171 gCO₂e/kWh in 2023 to well below 50 gCO₂e/kWh. To get there, the Plan calls for a technology build-out that dwarfs anything the UK has previously delivered: Offshore wind: 43–50 GW (from roughly 15 GW today) Onshore wind: 27–29 GW Solar: 45–47 GW — subsequently revised upward; DESNZ confirmed a solar capacity update in April 2025 Battery storage : 23–27 GW — a sixfold increase from approximately 4.5 GW operational in 2024 Long-duration energy storage (LDES): 4–6 GW Flexibility technologies: CCUS, hydrogen-to-power, consumer-led DSR The estimated investment requirement is £40 billion per year, every year, from 2025 to 2030 — predominantly from the private sector. To put that figure in context: it is more than double the annual capital expenditure of the entire UK water sector during the current AMP8 cycle. The Policy Architecture: Five Interlocking Frameworks Clean Power 2030 is not a standalone plan. It is the load-bearing pillar in a web of interconnected policy frameworks , each of which depends on the others progressing on schedule. Miss one, and the whole structure is stressed. 1. SSEP — Strategic Spatial Energy Plan The SSEP is NESO's long-term spatial plan for GB's energy system — covering electricity and hydrogen generation, storage, and network infrastructure from 2030 to 2050. Due for publication in Autumn 2027 , it will determine where technologies should be built, not just how much. Critically, the SSEP will also inform future connection offers for the 2031–2035 period, replacing the current FES-derived capacity ranges once published. The tension: Clean Power 2030 must be substantially delivered before the SSEP is complete?! . Developers are currently making billion-pound investment decisions without the long-term spatial certainty the SSEP is designed to provide. The government acknowledges this; NESO has confirmed that SSEP recommendations will not retrospectively alter connection agreements already issued. 2. REMA / RNP — Reforming How the Market Works and its Associated Price Signals Launched in 2022, the Review of Electricity Market Arrangements (REMA) spent three years debating whether the UK should move to zonal pricing — a fundamental restructuring of the wholesale electricity market into geographically differentiated price zones. In July 2025, the government ended the debate: zonal pricing is off the table. Instead, DESNZ has adopted Reformed National Pricing (RNP) — retaining a single GB-wide wholesale price while introducing a package of reforms to sharpen locational signals through transmission charging, connection rules, and the Balancing Mechanism . Ofgem launched a Charging Transitional Arrangements Group (CTAG) in March 2026 — underlining how early-stage this work still is. The investment implication: Three years of zonal pricing uncertainty depressed investment decisions in locationally sensitive assets — offshore wind export cables, onshore storage, and (gas) peaking plant. RNP resolves the headline question but leaves the detailed transmission charging regime unresolved until at least 2027 . Meanwhile, TNUoS charges are rising by over 60% in April 2026, from approximately £5.1bn to £8.9bn in system revenue — a direct consequence of the RIIO-ET3 settlement needed to fund the very network that Clean Power 2030 requires. 3. Grid Connection Queue Reform — Gate 2 and Beyond The existing connections queue held over 800 GW of applications — four times what net zero requires. NESO's Gate 2 reform is restructuring that queue around genuine project readiness and locational need, with Phase 1 connection offers (pre-2030 projects) due by Q2 2026 and Phase 2 by Q3 2026. This reform is both necessary and painful. Most protected projects with 2026–2027 connection dates are expected to face delays, some by over a year. The connection queue is the single biggest near-term execution risk to Clean Power 2030 delivery — not the technology, not the finance, and not the planning system. Developers who misread Gate 2 will find their projects stranded at the worst possible moment. For a detailed analysis of Grid Connection Queue Reform, see CM Energy Insight's dedicated page on this topic. 4. The Advanced Nuclear Framework — SMR as the Baseload Foundation Published in February 2026, the Advanced Nuclear Framework provides the enabling policy environment for renewed private investment in advanced civil nuclear — SMRs, AMRs, and micro-modular reactors . It introduces a national pipeline of credible projects, a concierge-style support service, and a market-focused route for privately led nuclear innovation. The Framework anticipates 4 month review process, so expect positive news in Autumn 2026. The government has committed £2.5bn+ through Great British Energy – Nuclear (GBE-N) for the SMR programme, with Wylfa on Anglesey selected as the first site. The programme is targeting grid connection in the mid-2030s — meaning new nuclear contributes almost nothing to the 2030 target directly, but is critical to the post-2030 clean firm power that allows unabated gas to be phased out entirely. The honest link: Clean Power 2030 without SMR baseload is a system permanently dependent on gas peakers as winter firming capacity. The Advanced Nuclear Framework is not a 2030 initiative — it is the insurance policy that makes 2030 a viable endpoint rather than a dangerous plateau. Hedge SMR positions with gas peakers. For a detailed analysis of the UK's SMR programme, see CM Energy Insight's dedicated page on this topic. The Capacity Market in 2026: What the Auction Results Are Actually Telling Us The March 2026 capacity market results deserve more attention than they have received. The T-4 auction for 2029/30 cleared at £27.10/kW/year — a 55% fall from the £60/kW range that cleared in the two preceding years. The T-1 auction for 2026/27 cleared at just £5/kW/year — a 75% fall. Lower prices are being framed by government and NESO as good news: more capacity entered the auction than was needed, competition was healthy, and consumers will pay less. That framing is partially correct — and substantially misleading . Consider what the auction actually revealed: No new-build gas (CCGT / OCGT) secured agreements. 59% of procured T-4 capacity came from existing and refurbishing gas plant. Despite 12.4 GW of refurbishing gas entering the auction, only 1.6 GW secured three-year agreements — at £27.10/kW, which is widely considered insufficient to support either new-build or substantive refurbishment investment. BESS dominated new-build: 95% of new-build capacity (approximately 1,184 MW derated, representing ~3.8 GW installed) was battery storage. BESS is now the market's primary new-build capacity technology — but overbuild risk is growing , with over 30 GW of BESS in CM agreements by 2030 if all commissioned. Longer-duration BESS emerging: Just over 1 GW of 4-hour-plus duration cleared in T-4, reflecting falling BESS capex and growing investor appetite for LDES. The uncomfortable conclusion: The capacity market is signalling that existing gas is being retained cheaply , new gas is uninvestable at current clearing prices, and BESS is crowding out the new-build thermal that would otherwise provide firm winter capacity. A system leaning heavily on existing gas assets of uncertain longevity — and on BESS revenues that depend partly on the price volatility that gas plant itself suppresses — is not a robust long-term design. Balcony Solar and the Government's Real Energy Priorities On 24 March 2026 the government announced that plug-in "balcony solar" panels would be made legal in the UK within months. Energy Secretary Ed Miliband stated: "Global events demonstrate there's not a moment to waste in our drive for clean power... We are bringing forward the next renewables auction and announcing that plug-in solar will be available for the first time in Britain. " The announcement should be read at face value and at depth. At face value, it is a sensible liberalisation: Germany has deployed over 800,000 balcony solar units; the UK ban was an anomaly. Renters and flat-dwellers — historically locked out of the solar economy — gain access to a real energy cost reduction tool. Alongside the Warm Homes Plan's potential £13 billion grant programme for household solar, batteries and heat pumps, the retail energy transition is accelerating. At depth, the announcement reveals something important about the government's political economy of energy. The investors and developers reading this page will note that the headline policy communication in March 2026 was not about offshore wind auction timelines, not about BESS revenue certainty, and not about TNUoS reform. It was about plug-in panels for balconies. The political logic is clear — household bills are a live voter issue — but it points to a risk that institutional energy investment, which is unglamorous and slow, receives less ministerial bandwidth than consumer-facing announcements. The Three Questions Clean Power 2030 Cannot Currently Answer 1. Who provides firm winter capacity after 2030? Unabated gas is the backstop. The Plan allows 5% of annual generation from gas — but in a cold, still, dark December week, the system may need gas to provide 30–40% of instantaneous demand. The capacity market is not supporting new-build gas investment. Existing plant is ageing. SMR baseload arrives in the mid-2030s at the earliest. The gap between 2030 and reliable nuclear deployment is the central energy security risk of the next decade. 2. Can the planning system actually deliver at the required pace? Offshore wind consenting has improved. Onshore wind and large-scale solar remain contested. The SSEP does not arrive until Autumn 2027. The Nationally Significant Infrastructure Projects (NSIP) regime is being reformed — but grid-scale solar and BESS projects are still exposed to local authority challenge, judicial review, and supply chain delays that no policy framework can fully eliminate. 3. Will non-commodity costs destroy the competitiveness case? TNUoS charges rising 60% in one year. RIIO-ET3 transmission revenues climbing from £5.1bn to a projected £13.6bn by 2030/31. Nuclear RAB levies on bills. Capacity market costs. Balancing mechanism constraint payments . Clean Power 2030 is predicated on electricity becoming cheaper than gas — but the non-commodity cost trajectory is moving in the opposite direction for industrial users. This is not an argument against the energy transition; it is an argument for being very precise about who bears which costs, and when. What This Means for Energy Investors and Developers Clean Power 2030 is real, it is funded, and it is the defining framework for UK energy investment over the remainder of this decade. The question is not whether to engage with it — the question is where the risk-adjusted returns are highest , and where the policy execution risk is greatest. The strongest near-term investment cases cluster around: BESS — clear capacity market route, falling capex, revenue stack breadth, but monitor overbuild risk carefully Grid-connected flexibility — Clean Flexibility Roadmap targeting 51–66 GW by 2030; cap-and-floor for LDES now live Offshore wind infrastructure — connection reform and AR7/AR7a auctions provide forward visibility Private nuclear (post-2030) — Advanced Nuclear Framework opens privately led SMR routes for the first time, look for Autumn 26 announcements. Gas peaker M&A — existing flexible assets have capacity market value at a price that may not be available once the fleet thins further. The highest execution risks cluster around projects that depend on early SSEP certainty, on zonal or nodal pricing signals that have been deferred, or on planning consents in contested landscapes. CM Energy Insight's Role CM Energy Insight advises across the full lifecycle of energy asset development, commodity risk, and infrastructure finance — with specific experience in the exact policy junctures that Clean Power 2030 creates: grid connection strategy, BESS revenue modelling, gas peaker valuation and M&A, capacity market positioning, and capital structuring for assets navigating a rapidly changing regulatory environment. Clean Power 2030 is not a background policy document. It is the commercial operating environment. Understanding its architecture — and its fault lines — is a prerequisite for every investment decision being made in UK energy today. CM Energy Insight provides senior, independent advisory at the intersection of energy policy, project development, and institutional capital. If Clean Power 2030 intersects with your investment thesis or development programme, request a discussion. Let's Start a Conversation Whether you need a sounding board on a live deal, an interim project lead, or a fresh perspective on market strategy — the first conversation is always free and always confidential. Phone: +44 7884 231 261 Email: chris@cmenergyinsight.com LinkedIn: https://uk.linkedin.com/company/cmenergyinsight Name* Email* Company* Message* Send Message

40 years across energy asset development, commodity trading, and infrastructure finance. PowerGen, Enron, and beyond. Senior UK energy consultancy. Contact Today. Experience you can depend upon... OUR MISSION: Deploying transitional capital at the intersections where engineering meets finance, and commodity risk meets policy, at "game changing" scale to drive disruption At CM Energy Insight, we provide specialist consulting services to clients operating in the renewable energy, flexible energy and "waste to value" sectors , with a particular focus on strategic implementation, battery energy storage, emerging Advanced Modular Reactor technologies, gas reciprocating engines, hydrogen, green steel, and sustainable fuels . Our founder, Chris Moore, has over 35 years of experience leading high-impact energy projects and supporting clients in navigating complex market environments. CM Energy Insight offers clients a unique perspective on the challenges and opportunities of the energy transition. We help energy companies, investors, and governments design, develop, and implement strategies that drive sustainable growth and decarbonization. Whether you’re seeking advice on launching a renewable energy project, exploring the hydrogen economy, or investing in sustainable energy markets, CM Energy Insight has the knowledge and experience to guide you through every step. 1987 - PowerGen European Thermal Asset Development, M&A. Chris started his "utility-scale" energy project development with PowerGen plc, focussing on coal conversion, EFW, pyrolysis, flue gas cleanup, and biomass and gas-fired CHP. Early entrant into the post Berlin Wall east German marketplace, M&A of the MIBRAG coal mines and district heating plants.... 1997 - Enron European Power Origination - UK, Croatia, Hungary, Italy Chris started energy commodity trading and origination at Enron, joining in 1997 and staying to the very end. Whilst at Enron Chris developed large CCGT projects in Italy, UK, Croatia and Hungary , and was establishing Enron's European renewable energy trading platform as ROCs were traded.... 2002.. American Electric Power Establishing the Green Energy Origination and Trading Team From 2002 to 2003 Chris set up the European green products trading desk at AEP (American Electric Power) with responsibility for some of the industries first long term green contracts and pioneering the use of imported biomass to decarbonise coal power stations... 2004 -2007 Renewable Fuel Supply Ltd MBO and Founder of Dry Bulks Trader - Sold to EDF Trading From 2003 to 2007 Chris was MD of Renewable Fuel Supply Limited, a new startup that grew to become the UKs largest importer of biomass fuels for coal fired power stations, with operations in Denmark, Spain, Greece, Scotland, Wales and England. RFSL was sold to EDF Trading in 2007 2007 - MGT Power and MGT Teesside Worlds Largest Biomass Power Plant - 300MWe From 2007 to 2012 Chris was the founder and CEO of MGT Power, a development company that pioneered the concept of 300MWe CFBC biomass boilers located at ports and fed by global forestry . MGT Teeside was acquired by Macquarie in 2016 and constructed (£1bn). 2012 - Statkraft Establishing Dry Bulks Trading From 2012-2017 Chris headed up Statkrafts biomass trading and origination business, establishing new flows of biomass fuel across Scandinavian and European ports. 2018 Copenhagen Infrastructure Partners Large ticket pension fund investment Deployment of pension funds into risk-reduced project finance structures with long dated contractual structures. 2019 - 2026 - CM Energy Insight Supporting Businesses through Transactions Chris has been focussed on BESS , waste plastic chemical recycling, gigafactory development, AMR/SMR feasibility studies, gas peakers , power flex trading platforms, electrolysers , smart grids , and new build CCGT .

BESS capex is falling fast as the UK targets 27 GW by 2030. CM Energy Insight analyses the investment case, revenue stack, and what the market shift means for you. Read more. The UK BESS Boom: Are You Positioned? The UK's grid-scale battery pipeline is scaling to 23–27 GW by 2030. Duration is extending, revenues are stacking, and financial sophistication is rising fast. Battery Storage Contact CMEI UK BESS Investment in 2026: Costs, Revenue, and Scale BESS Costs Are Falling Fast — Is Your Investment Thesis Keeping Up? Battery energy storage is no longer an emerging technology. It is the backbone of the UK's Clean Power 2030 programme — and in 2026, the market is scaling faster than most financial models anticipated, driven in part by the conflence of new negative power prices from renewables versus massive power price spikes triggered by Iranian invasion. The UK is expected to deploy 1.5–2 GW of new grid-scale BESS capacity in 2026 alone, sustaining its position as Europe's leading battery storage market. Turnkey CAPEX for 2-hour systems is expected to fall below £300/kWh this year, driven by lithium iron phosphate (LFP) cell dominance and intensifying competition among Chinese and European equipment suppliers. The Clean Power 2030 Action Plan targets 23–27 GW of battery storage by 2030 — a sixfold increase from approximately 4.5 GW operating today . The investment case is strong. But the revenue picture has changed dramatically, and developers who built their models on anciliary services income are already feeling the pressure. The Revenue Stack Has Shifted — Here's What That Means The composition of BESS revenues is anything but static. Frequency services — the dominant income source as recently as 2022, accounting for roughly 80% of the typical revenue stack — have collapsed to around 20% as installed battery capacity has saturated the market. A portfolio that once earned over £110,000/MW/year from frequency products may now earn less than £30,000/MW/year from the same services . The 2026 revenue stack looks fundamentally different: Wholesale arbitrage and the Balancing Mechanism now account for close to 50% of average project revenue, up from around 8% in 2022. As renewable penetration increases and gas turbines age, intraday price spreads are expected to widen further — sustaining arbitrage returns even as battery capacity grows. Capacity Market contracts provide revenue certainty. Battery storage dominated the most recent T-4 auction, securing around 95% of new-build capacity contracted. T-4 contracts (up to 15 years) are bankable and frequently used to anchor project finance structures. Ancillary services (Dynamic Containment, Dynamic Regulation, Dynamic Moderation) remain in the stack but at compressed margins. Skip rates — where batteries are bypassed even when they are the cheapest available option — remain a structural problem the Clean Flexibility Roadmap is tasked with resolving. Flexibility Purchase Agreements (FPAs) are emerging as a bankability tool: floor-style arrangements with "balance sheet players" like EDF, Statkraft, and SSE have become standard for large-scale projects seeking project finance leverage. In 2025, over 4.5 GW of BESS capacity was contracted under FPAs in Great Britain alone. Unlevered IRRs for well-structured UK BESS projects currently range from 14–18% , with equity returns exceeding 25–30% where moderate leverage is applied and multi-market optimisation is delivered. These returns materially outperform contracted solar and offshore wind — but they demand a more sophisticated operating model. Long-Duration Storage: The Next Frontier The Ofgem cap-and-floor scheme for Long Duration Electricity Storage (LDES) introduces a new revenue underwriting mechanism for technologies capable of storing and discharging electricity for eight or more hours . Modelled on the successful interconnector cap-and-floor regime, the scheme provides a minimum revenue floor to protect investors and a cap to limit consumer exposure. The first application window opened in April 2025 and closed in June 2025. Ofgem expects to approve the first projects by Q2 2026, with preliminary cap and floor levels set at that stage. A second application window decision is expected by Q1 2026 . NESO has confirmed that LDES is slightly under capacity for 2035, meaning genuine headroom remains for credible projects — in contrast to oversaturated markets such as solar, offshore wind, and short-duration BESS. The scheme is not without controversy. Zenobē and others have raised concerns that subsidised LDES assets competing in the same balancing and ancillary markets as unsubsidised short-duration BESS could distort pricing and undermine the short-duration investment case. LCP Delta analysis suggests the scheme, if poorly designed, could jeopardise up to 20% of projected BESS build-out. This is a live policy debate — and one that developers, investors, and lenders should factor into their risk models now . What to Watch in 2026 Lithium price volatility: Lithium carbonate prices rose sharply in early 2026 after a period of sustained lows, creating new procurement risk. LFP remains dominant but developers must now manage commodity exposure in supply contracts. Duration extension: The next-generation LFP 587 Ah cell is expected to enter mainstream commercial deployment by Q3 2026 , enabling longer-duration projects with improved energy density. BESS vs. gas peakers: BESS has reached the economic and technical tipping point at which it is cost-competitive with gas peaker plants for short-duration grid services — a structural shift that changes the competitive dynamic for flexible generation investors. CM Energy Insight advises on BESS project development, revenue modelling, procurement, and investment structuring. Request a discussion to explore your next move. Let's Start a Conversation Whether you need a sounding board on a live deal, an interim project lead, or a fresh perspective on market strategy — the first conversation is always free and always confidential. Phone: +44 7884 231 261 Email: chris@cmenergyinsight.com LinkedIn: https://uk.linkedin.com/company/cmenergyinsight Name* Email* Company* Message* Send Message

UK data centre grid connection strategy, embedded generation (CCGT/OCGT/BESS), AI Growth Zone power pricing, and corporate PPA advisory. Active TSO connection mandate. Getting power to a UK data centre is now the critical path. CM Energy Insight helps data centre developers, hyperscalers, and their investors navigate every layer of the UK power access problem Data Centre Power Advisory Contact CMEI What we advise on : Grid connection strategy and queue positioning — TSO 132kV to 400kV, DNO, ICP/IDNO AI Growth Zone designation support and DSIT Connections Accelerator engagement Embedded generation development: CCGT, OCGT, gas engines, utility-scale BESS Behind-the-meter generation: private wire, Grid Code compliance, regulatory structure TSO self-build pathways (build-and-transfer / build-and-operate) under the Planning and Infrastructure Act 2025 Corporate PPA structuring and wholesale power procurement Demand connection queue reform: Ofgem TMO4+, priority connection strategy Why CM Energy Insight: Chris Moore holds an active TSO connection mandate for a UK data centre developer (gas generation, 2026). He founded IPP developers that delivered utility-scale power plants and 400kV grid connections ahead of incumbent utilities, and has 40 years of execution experience across CCGT, OCGT, gas engines, 400kV TSO connections, and 500 MWe BESS. First conversation is always free Contact Chris Moore: Phone: +44 7884 231 261 Email: chris@cmenergyinsight.com LinkedIn: https://uk.linkedin.com/company/cmenergyinsight Name* Email* Company* Message* Send Message

The Clean Flexibility Roadmap targets 51–66 GW by 2030 - a threefold increase. CM Energy Insight unpacks what this means for BESS, LDES, DSR and flexibility investors. Read more. The Roadmap to 66 GW by 2030 The UK needs 51–66 GW of clean flexibility by 2030. CM Energy Insight unpacks the Clean Flexibility Roadmap and what it means for investors. UK Flexible Markets Contact CMEI From 24 GW to 66 GW — The Flexibility Investment Opportunity of the Decade In July 2025, the government — working with Ofgem and NESO — published the Clean Flexibility Roadmap. Its central ask is extraordinary: a two- to three-fold increase in the UK's clean flexibility capacity, from approximately 24 GW in 2023 to 51–66 GW by 2030. By 2050, the Roadmap's central scenario projects flexibility capacity reaching 204 GW — an eightfold increase from today. This is not an aspiration. It is a policy commitment backed by regulatory action, market reform, and public investment — and the commercial opportunity it creates is already materialising in the market. What "Flexibility" Actually Means (And Why It Matters Now) Flexibility is the ability of the power system to match supply and demand as renewable generation output varies with weather and time of day. As the UK grid approaches 95% clean generation by 2030 (??), the variability of wind and solar output means that flexibility — the ability to store, shift, or curtail electricity rapidly — might become the critical system service. Or will it remain gas-backed? The Clean Flexibility Roadmap covers the full technology stack: Short-duration batteries (BESS): The dominant near-term technology. 23–27 GW targeted by 2030, up from approximately 5 GW today. Long Duration Electricity Storage (LDES): 4–6 GW targeted by 2030. Includes pumped hydro, compressed air, liquid air, and flow batteries. The new Ofgem cap-and-floor scheme is the primary investment mechanism. Interconnectors: Already 10 GW, rising to 12–14 GW by 2030. Provide cross-border flexibility — but are geopolitically exposed. Low Carbon Dispatchable Power: 2–7 GW targeted. Includes hydrogen-to-power and CCUS-equipped gas — technologies with significant policy and commercial uncertainty after decades of investment support. Assume gas here. Consumer-Led Flexibility (CLF): Perhaps the most underestimated opportunity. Vehicle-to-grid (V2X), smart tariffs, heat pump demand response, and industrial DSR. P483 (approved August 2025) has already unlocked access for approximately 345,000 households and small businesses previously excluded from the flexibility market. Vehicle-to-Everything (V2X): Expected to grow significantly post-2030, but commercial pilots are active now. The Policy Actions That Matter Most The Roadmap is not a wish list. It contains specific, time-bound actions with named owners. The most commercially significant are: LDES cap-and-floor scheme: First projects expected to be approved by Q2 2026, with preliminary cap and floor levels set at that stage. A second application window decision was due by Q1 2026 — watch for that announcement. Skip rate reform: NESO is tasked with addressing the systematic bypassing of battery bids in the Balancing Mechanism, even when batteries are the cheapest available option. This reform will materially improve BESS revenue capture. Market-Wide Half-Hourly Settlement (MHHS): Expected in 2026, MHHS will expose electricity suppliers to the true half-hourly cost of serving customers — creating a structural incentive for smart tariffs and consumer flexibility products at scale. Blended finance for LDES: The government committed to exploring blended finance (combining grant, debt, and equity instruments) specifically to de-risk LDES investment in technologies not yet commercially ready for the cap-and-floor scheme alone. Carbon reporting for flexibility actions: By April 2026, NESO is exploring options for large industrial consumers to report carbon savings from flexibility actions — creating a direct link between flexibility participation and ESG reporting frameworks. The Tension in the Market The flexibility agenda is not without structural tension. The LDES cap-and-floor scheme introduces subsidised competition into markets currently served by unsubsidised short-duration BESS — a conflict that Zenobē and others have publicly challenged. LCP Delta has warned that poorly designed LDES subsidy could jeopardise up to 20% of projected BESS build-out by depressing balancing and ancillary service revenues for short-duration assets. For investors, the practical implication is that the revenue stack for all flexibility assets — BESS, LDES, DSR — is subject to continuing policy risk from market design decisions that are still being made. Duration, location, technology, and commercial structure all affect exposure to this risk differently. Getting those choices right — now, before the market structures are locked in — is the difference between an asset that delivers returns and one that underperforms its investment case. Flexibility is the backbone of Clean Power 2030. CM Energy Insight helps developers, investors, and utilities position for this market. Let's Start a Conversation Whether you need a sounding board on a live deal, an interim project lead, or a fresh perspective on market strategy — the first conversation is always free and always confidential. Phone: +44 7884 231 261 Email: chris@cmenergyinsight.com LinkedIn: https://uk.linkedin.com/company/cmenergyinsight Name* Email* Company* Message* Send Message

50 GW of datacentre demand is queuing for UK grid connections. CM Energy Insight explores AI Growth Zones, power implications, and what this means for energy investors. Read more. 50 GW of Datacentre Demand Just Joined the Queue Data Centres AI Growth Zones, a 6 GW government target, and a new Connections Accelerator are redrawing the UK's power demand map. What does this mean for energy investors? Contact CMEI Datacentres, AI Growth Zones, and the UK Power Grid 50 GW of Datacentre Demand Just Hit the UK Grid Queue The AI infrastructure arms race has arrived on British shores — and it is reshaping the UK's power system at a speed that network planners, regulators, and energy investors are in awe of. Contracted demand offers on the UK grid rose from 41 GW in November 2024 to 125 GW by June 2025 , driven overwhelmingly by hyperscale datacentre projects. In February 2026, The Register reported that the total datacentre-related grid demand queued across the UK had reached 50 GW — equivalent to more than twice the UK's average electricity demand!! This is not a distant projection. It is happening now. And the implications for energy developers, investors, and network planners are profound. The Scale of the Demand Shift Oxford Economics forecasts that UK datacentre electricity consumption will grow from 5 TWh in 2023 to 26.2 TWh by 2030 — equivalent to 8.8% of total UK electricity demand. NESO estimates that datacentres could drive up to 71 TWh of additional grid demand over the next 25 years. The UK already has 477 datacentre facilities in operation, making it the world's third-largest marke t — behind only the US and Germany. That base is set to expand rapidly, with major developments planned across London and the South East, Greater Manchester, Wales, and Scotland. Scotland is emerging as a strategic location of particular significance. Its access to renewable energy from wind and hydro , combined with a lower land cost base and emerging government support structures, is attracting projects at scale. In Scotland alone, 5GW of datacentre capacity is currently in the planning system — already exceeding Scotland's entire peak winter electricity demand. AI Growth Zones: Opportunity and Complication The government's response has been to designate five AI Growth Zones (AIGZs) across England, Scotland, and Wales, with planning reform and energy access incentives designed to fast-track development. The zones offer energy price discounts — up to £24/MWh in Scotland and £16/MWh in Cumbria and the North East — as well as access to a new Connections Accelerator Service that aims to bypass the standard grid connection queue. Non datacentre demand owners should be worried - you are on your own! The North Wales AI Growth Zone is particularly notable. It is the only zone explicitly linked to a specific energy supply solution: the first Rolls-Royce SMR fleet at Wylf a. The government's framing positions Wylfa's SMRs and the AI Growth Zone as a co-located clean energy corridor — compute powered by 24/7 nuclear generation, designed for the load profile that AI workloads demand. Tension : prioritising AI datacentres for grid capacity and planning permission could displace other uses, including housing and conventional energy development. The Connections Accelerator Service effectively creates a two-tier connection system — and the criteria for "strategic" status are not yet settled. The "Bring Your Own Generation" Model The most sophisticated hyperscalers are not waiting for the grid. As detailed in CM Energy Insight's commentary on Google's $4.75 billion acquisition of Intersect Power , the dominant strategic model is now co-location: solar, battery storage, and backup generation sited alongside the datacentre, connected to the grid at the substation boundary but keeping most power flows internal. In the UK, this model is being explored through private-wire connections, behind-the-meter generation, and microgrid configurations. National Grid's Data Centre Impact Study has modelled the implications of widespread adoption. For UK energy developers, this creates a direct opportunity: battery storage projects, flexible generation, and renewable assets near planned AI Growth Zones are now being actively evaluated as potential anchor assets for co-located datacentre power supply. The commercial structure — long-term, creditworthy, high-capacity offtake from hyperscalers — could provide the revenue certainty that merchant BESS and renewables projects have historically lacked. The intersection of AI infrastructure and energy supply creates complex investment questions. CM Energy Insight provides the cross-domain advisory to navigate them. Let's Start a Conversation Whether you need a sounding board on a live deal, an interim project lead, or a fresh perspective on market strategy — the first conversation is always free and always confidential. Phone: +44 7884 231 261 Email: chris@cmenergyinsight.com LinkedIn: https://uk.linkedin.com/company/cmenergyinsight Name* Email* Company* Message* Send Message

PPA structuring, route-to-market strategy and hedging frameworks for renewable and flexible energy assets. Senior commodity advisory from CM Energy Insight. Read more. PPA structuring, option pricing, weather volatility, route-to-market strategy, and hedging frameworks for renewable and flexible assets. Commodity Trading Contact CMEI The UK Power Market Has Never Been More Complex - Or More Exposed to Getting It Wrong In a world where LNG is a diplomatic instrument and oil volatility is running at four times equity risk, long-dated commodity agreements are not just financial instruments. They are strategic assets Electricity prices in Great Britain have been the most volatile in Europe over the past three years. Day-ahead prices have ranged from negative values during periods of high renewable output and low demand to £3,000/MWh during system stress events. Balancing Mechanism actions are increasingly frequent and increasingly expensive. Non-commodity costs — network charges, BSUoS, Capacity Market levies, RO renewables obligation — now represent between 40% and 60% of the total electricity bill for an industrial consumer, and their trajectory is uncertain as RNP (ex REMA), zonal pricing, and Ofgem's network charging reviews run in parallel. For a renewable or flexible asset, the commercial strategy around power trading and revenue de-risking is not a treasury function to be added at the end of development. It is a core value driver and designer— and, if designed poorly, a core value destroyer. The Revenue Risk Is Real and Current Consider what has changed in the past twenty-four months for assets in the UK market: PPA markets have repriced. The collapse of wholesale electricity prices from post-crisis highs has compressed fixed-price PPA offers for solar and wind. Developers who locked in long-term PPAs during 2022–2023 at or near peak rates are sitting on significant value. Those seeking PPAs now face a market where offtakers — utilities, corporates, traders — are less willing to take long-term price risk, and the available products have shorter tenors, higher floors, and more restrictive curtailment clauses. And then comes Iran.... The Balancing Mechanism has become a primary revenue source for BESS. BM revenues now account for approximately 50% of the typical BESS revenue stack, up from under 8% in 2022. The implications for skip rates, optimisation strategy, dispatch logic, and operational infrastructure are material — and not all asset owners have adapted. REMA/RNP is rewriting the incentive structure for location. The Review of Electricity Market Arrangements decided that Great Britain should not move from national to zonal electricity pricing. Under a zonal model, assets in areas of network congestion — parts of Scotland, East Anglia, the South West — face materially different wholesale price exposure than those in the South East. Reformed National Pricing (RNP) proposals under the Transmission Network Use of System (TNUoS) review create further locational revenue uncertainty. An asset developed without modelling zonal pricing scenarios is carrying latent value risk. Non-commodity costs are rising and unpredictable. Capacity market levy, network charges, BSUoS — collectively representing a growing share of the total merchant exposure for co-located and behind-the-meter assets. Understanding the interaction between energy revenue and total cost of supply is essential for accurate project economics. What CM Energy Insight Delivers Commodity advisory is most valuable when it bridges the commercial and technical — when the person advising on the revenue structure also understands the engineering constraints of the asset, the market mechanics of the instruments being used, and the financial structure that the project is trying to satisfy. Our core service areas are: PPA design and negotiation — structuring the heads of terms, selecting the right contract type (fixed, floor, baseload, shape-adjusted, proxy generation), and negotiating the commercial terms that actually matter: curtailment, balancing, imbalance risk allocation, and change-of-law. Route-to-market strategy — evaluating licensed supplier, sleeved PPA, direct wire, trading optimiser, and merchant routes; building the commercial case for each option relative to the asset's technical profile. Revenue stack analysis and optimisation — constructing the forward-looking revenue model across capacity market, ancillary services, BM, wholesale arbitrage, and flexibility products; stress-testing it against current market assumptions rather than historical proxies. Hedging strategy and counterparty selection — for assets with merchant price exposure, designing a hedging programme that reflects the asset's cash flow requirements, lender covenants, and market liquidity constraints. REMA/RNP and zonal pricing preparedness — scenario analysis of the asset's commercial exposure under the various RNP options currently under consultation, informing development and investment decisions before the policy is finalised. Commodity analytics and forecasting — independent market analysis to support investment committee presentations, lender reports, and management decision-making. The Boutique Advantage in Trading Advisory Large advisory firms model commodity markets in teams. Analysts updates the price curve; a partner presents it to the board. The nuance between those two moments — the commercial judgement about what the numbers mean for this specific asset, in this specific market, at this specific moment — is where value is made or lost. CM Energy Insight's commodity advisory is delivered directly by a practitioner with direct origination, trading, design, procurement, documentation, and structuring experience across gas, power, and renewable assets. That experience is not abstracted into a methodology deck. It is applied to your commercial problem. Energy market volatility is not going away. The question is whether it works for your asset or against it. Talk to CM Energy Insight about structuring your commercial position. Let's Start a Conversation Whether you need a sounding board on a live deal, an interim project lead, or a fresh perspective on market strategy — the first conversation is always free and always confidential. Phone: +44 7884 231 261 Email: chris@cmenergyinsight.com LinkedIn: https://uk.linkedin.com/company/cmenergyinsight Name* Email* Company* Message* Send Message

Rolls-Royce SMR wins the GBN competition. CM Energy Insight analyses site selection, the Advanced Nuclear Framework, and what the SMR programme means for energy investment. Read more. Rolls-Royce, GE Vernova, Westinghouse, Holtec, X-energy, Last Energy, Blue Energy ,GBE-N, and What Comes Next CM Energy Insight analyses the implications for energy investment, site selection, and co-location. UK SMR Programme Contact CMEI Britain's Nuclear Comeback: What the SMR Programme Means for Energy Investment June 2025, following a two-year competition, Great British Energy–Nuclear (GBE-N) selected Rolls-Royce SMR as its preferred technology. In November 2025, the government confirmed Wylfa on Anglesey as the site for the UK's first small modular reactor fleet. In March 2026, the Generic Design Assessment process reached another milestone, with the Office for Nuclear Regulation expected to complete GDA Step 3 by December 2026. This is no longer a speculative programme. It is a funded, sited, technology-selected deployment with a clear — if ambitious — delivery pathway. This gives cautious investors the early signals that an opportunity may be crystalising. What Has Been Decided Technology: Rolls-Royce SMR — the only UK home-grown technology in a field that included Westinghouse, GE-Hitachi, and Holtec. Each unit is a 470 MWe pressurised water reactor, capable of powering approximately one million homes for 60+ years. Site: Wylfa, Anglesey, confirmed to host a minimum of three Rolls-Royce SMR units, with the potential to host up to eight. GBE-N purchased Wylfa (and Oldbury in Gloucestershire) for £160 million in March 2024. Funding: The government has committed over £2.5 billion to the programme in the current spending period. Owner's Engineer contract: Valued at up to £600 million, Arup was appointed to support delivery in March 2026. Construction timeline: GBE-N is expected to begin site activity in 2026. Final Investment Decision is targeted for around 2029. First power: mid-2030s — most likely 2035. The Investment and Commercial Opportunity The SMR programme creates investment and advisory opportunities at multiple levels, and the window to engage early is now open: Project development and pre-FID advisory. The period 2026–2029 is the most active phase for project definition, regulatory engagement, supply chain development, and business case modelling. Owner's engineer, independent technical adviser, legal and commercial advisory roles will be procured across this period. Co-location and offtake. The linkage of Wylfa to the North Wales AI Growth Zone is a clear signal that 24/7 nuclear generation will be marketed as a premium power supply for datacentres and energy-intensive industry. The commercial structuring of that offtake — long-term PPAs, private-wire arrangements, industrial consumer contracts — requires the kind of (CM Energy Insight) cross-domain expertise that spans engineering, trading, and project finance. Fleet economics and replication. The government's ambition is not a single project but a fleet. The Owner's Engineer appointment, the generic design assessment, and the export licensing architecture are all designed to enable rapid replication beyond Wylfa — including to Oldbury and potential further sites that GBE-N is required to identify by autumn 2026. Supply chain investment. The Rolls-Royce SMR modular, factory-built construction model is designed to create a domestic manufacturing base. Component suppliers, EPC contractors, and logistics providers positioning for the supply chain now will be better placed than those who wait for FID. What This Does Not Resolve Credibility requires acknowledging the programme's challenges. FID in 2029 assumes a successful completion of GDA (target December 2026), a resolved financing structure, a settled offtake, and planning consent — in a political environment that has historically been unreliable on nuclear timelines. The first power date of mid-2030s represents a decade-long development horizon. Capital cost uncertainty for novel modular designs, while better bounded than for large EPR plants, remains a material investment risk. Will this create the market gap that enables nimble new entrants like Last Energy to overtake? Investors and developers entering this space should do so with open eyes — and a financial model that stress-tests the schedule and the cost base. The SMR programme opens new pathways for energy investors and industrial consumers. If we can help you with an Advanced Nuclear Framework submission, or indeed other aspects of the new technology class, please contact us. Let's Start a Conversation Whether you need a sounding board on a live deal, an interim project lead, or a fresh perspective on market strategy — the first conversation is always free and always confidential. Phone: +44 7884 231 261 Email: chris@cmenergyinsight.com LinkedIn: https://uk.linkedin.com/company/cmenergyinsight Name* Email* Company* Message* Send Message

NESO's Gate 2 is reshaping the UK connections queue. 210 of 340 protected projects face delays. CM Energy Insight explains the timeline and strategic implications. Read more. Grid Queue Reform: What Gate 2 Means for Your Project With 800 GW in the connection queue and NESO's Gate 2 offers now landing, developers face harddecisions on timing, viability, and re-application. Grid Connections Contact CMEI Grid Connection Reform: What Gate 2 Means for Your Project Gate 2 Offers Are Landing — Two-Thirds of Projects Face Delays The UK's electricity network connection queue accumulated over 800 GW of applications — four times the capacity needed to deliver net zero — before NESO, Ofgem, and the government intervened with the most fundamental overhaul of the connections process in a generation. TMO4+ was the centrepiece of that reform: a process designed to filter out speculative and non-credible projects, prioritise shovel-ready schemes, and compress connection timelines to support the Clean Power 2030 target. The first Gate 2 decisions were issued in December 2025. The results were more mixed than the industry had hoped. And todays TEC register still doesn't show any Gate 2 projects What Gate 2 Actually Decides NESO's approach sorts the queue into protected projects (those with imminent connection dates, CM agreements etc) and the broader Phase 1 and Phase 2 pipeline. The headline outcomes: Protected projects (connecting in 2026–27) - only the first offers — to a small number of transmission-connected projects in Scotland — were issued in February 2026. Phase 1 offers (pre-2030 connections) are now due between mid-May and mid-September 2026 for transmission and large embedded projects, with distribution-level offers following approximately two months later. Phase 2 offers (2030–2035 connections) for transmission projects are expected between September 2026 and January 2027. Distribution projects were the biggest losers. Phase 1 capacity was almost entirely allocated to transmission-connected schemes, not distribution — a decision neither widely anticipated nor communicated, and one that has drawn significant criticism from the solar sector and smaller developers. The delays to the timeline — now running several months behind original commitments — stem from two technical issues: higher-than-anticipated project volumes requiring NESO and network companies to rerun engineering studies, and the discovery that some areas require additional construction planning work before robust offers can be issued. The Strategic Reality for Developers A survey of 800 senior UK energy sector decision-makers found that 68% view Gate 2 as an investment opportunity, and 74% are confident it will ultimately reduce connection delays. But optimism is tempered by clear-eyed concern: 46% believe the reforms will disproportionately favour larger players with the balance sheet depth and teams to navigate tighter evidencing requirements. Smaller developers face a genuine risk of being structurally disadvantaged. 80% of respondents flagged supply chain delays — particularly in transmission equipment — as a material risk to delivering accepted Gate 2 offers on schedule. Compressed energisation windows for 2026–27 assets mean that even projects that receive their Gate 2 offer on schedule face tight procurement and construction windows, with limited margin for error on EPC mobilisation. The next application window — for projects not included in Gate 2 — has no confirmed opening date. Developers with Gate 1 positions that were not carried forward are in a period of significant uncertainty. The Broader Reform Framework Gate 2 does not stand alone. It sits within a wider set of reforms that are changing the economics and risk profile of connection-dependent energy projects: Ofgem's end-to-end review is examining the full connections process from application to energisation, with implications for cost allocation, network company accountability, and the treatment of speculative demand. RIIO-3 network price controls (for Transmission and Distribution) will set the investment framework within which connection works are funded and delivered through the early 2030s. AI Growth Zones have introduced a new fast-track connection mechanism for strategic and therefore massive demand projects — effectively creating a two-tier connection process. The government's March 2026 consultation on accelerating connections for strategic demand formalises this approach, but also creates another opportunity for Investment Committees to defer decisions. Developer-built connections — (where the developer constructs the high-voltage infrastructure themselves and transfers it to the network owner) — are being explored as a mechanism to bypass bottlenecks, particularly for AI Growth Zone projects. The direction of travel is clear: connection capacity will increasingly flow to projects that are credible , technically ready, and strategically aligned with national energy priorities. Projects that do not meet this bar face longer waits, re-application risk, and the prospect of competing in a reformed queue with more rigorous evidencing requirements. Navigating the new connections landscape requires strategic clarity. Contact CM Energy Insight for independent advisory on queue positioning and project readiness. Let's Start a Conversation Whether you need a sounding board on a live deal, an interim project lead, or a fresh perspective on market strategy — the first conversation is always free and always confidential. Phone: +44 7884 231 261 Email: chris@cmenergyinsight.com LinkedIn: https://uk.linkedin.com/company/cmenergyinsight Name* Email* Company* Message* Send Message