Impact of Location on Energy Market Strategy

𝗛𝗼𝘄 𝗟𝗼𝘄𝗲𝗿 𝗘𝗹𝗲𝗰𝘁𝗿𝗶𝗰𝗶𝘁𝘆 𝗖𝗼𝘀𝘁𝘀 𝗣𝗿𝗼𝘃𝗶𝗱𝗲 𝗖𝗼𝗺𝗽𝗮𝗻𝗶𝗲𝘀 𝗮 𝗖𝗼𝗺𝗽𝗲𝘁𝗶𝘁𝗶𝘃𝗲 𝗘𝗱𝗴𝗲 It's reasonable to assume that securing a lower cost for any product gives you a competitive edge over rivals who are paying more for that same product. However, the advantages of lower electricity costs are not as straightforward as they might seem. This post will explore why being in a particular power market—or in states with favorable or restrictive regulatory policies—can significantly affect a company's ability to procure inexpensive power. 📌 Should All Markets Have the Same Energy Costs? In theory, if all markets possessed the same power generation mix and input costs (such as natural gas), the price of electricity should be uniform across all markets. The only variations would arise from transmission constraints and losses. If this were the case, this post would be irrelevant. 📌 The Impact of Regulatory Frameworks on Business Competitiveness 📌Favorable Regulations (e.g., ERCOT) In regions with favorable regulatory environments, power markets are structured to allow generators to compete for end-user business. These regions also have excellent behind-the-meter policies that incentivize large manufacturers to seek the lowest energy costs possible. These policies may even prompt large manufacturers to consider relocating their operations to such areas to gain a competitive edge. 📌 Restrictive Regulations (e.g., Indiana) Conversely, in regions with restrictive regulatory environments, power markets often don't permit generators to compete for end-user business. Energy costs are determined by a cost-of-service model that is counterintuitive to competition. Rates are usually set through rate cases, resulting from negotiations between the utility and the intervenors. These negotiations do not always yield the most competitive pricing, particularly when compared to states like Texas, which has a more competition-friendly environment. For instance, I've worked with manufacturers forced to pay over $85 per MWh due to restrictive regulatory frameworks, a situation that would be vastly different in a state like Texas, which has multiple pro-competition policies for electricity. 📌 Investment Decisions: Pro-Regulation vs. Restrictive Regulation Areas Investment decisions are generally made based on the potential for maximum financial return. Using actual data from a Fortune 500 steel manufacturer, I performed a simple analysis comparing the profitability of building a new manufacturing plant in a pro-competition area like ERCOT versus a region with restrictive regulations. As illustrated, a manufacturer paying $85 per MWh might be compelled to build their new plant, or even relocate an existing plant, in a power market with more favorable policies, potentially achieving rates below $25 per MWh. This decision could be worth nearly 600 basis points in financial terms. 𝗪𝗵𝗮𝘁 𝗮𝗿𝗲 𝘆𝗼𝘂𝗿 𝘁𝗵𝗼𝘂𝗴𝗵𝘁𝘀?

Zonal pricing: looking beyond the theory – Lessons from the Nordics Zonal pricing is promoted as a driver of demand and generation siting, and the Nordic markets have been cited by way of example – specifically, that zonal pricing is being used to attract more industry. Aquaicity was asked by SSE plc to look beyond the theory and see what lessons could be learnt from the Nordics. In our report (👉 https://lnkd.in/ehfSJD93), we point to evidence that suggests it would be wrong to conclude that zonal pricing is the key factor driving demand location, that the theoretical benefits appear overplayed, and that it might not work in practice. Key takeaways: 1️⃣ Abundant natural resources in northern Sweden are a key advantage that has influenced the location of energy intensive industry. 2️⃣ With emphasis on the need for a national not zonal strategy, the Swedish government’s (Regeringskansliet, Klimat- och näringslivsdepartementet) report on inward investment is clear on the need to align energy infrastructure development with industrial transformation. 3️⃣ Skogen, Kemin, Gruvorna och Stålet (SKGS) has recently highlighted the postponing of investments by industry, and a need to invest in new electricity generation and expand the electricity grid. 4️⃣ Analysis of data centre location in Norway and Sweden suggests the argument that zonal pricing would drive data centre siting appears to be overplayed. 5️⃣ Evidence that utilities in northern Norway and Sweden are scaling down generation investments due to persistent low power prices. 6️⃣ The International Energy Agency (IEA) has observed that Swedish price signals have not led to sufficient new investment in generation capacity in deficit areas. 7️⃣ The Swedish government has tasked Svenska kraftnät to assess whether there should be fewer pricing zones to create more similar power prices across the country. 8️⃣ Recognition in Norway that there are consumers who prefer stable predictable pricing, with the government proposing the option of a fixed national price. This suggests that zonal pricing isn’t necessarily for all. In GB, the geography of renewable resource and likely increase in central planning of the GB electricity system will significantly influence supply and demand side location. We also need to learn from past mistakes in the GB retail market and ensure that theory does not trump practicality. Consumer first, postcode lottery no. Delivering clean power by 2030 is challenging. The investment needs are significant and span the entire value chain. If Department for Energy Security and Net Zero, National Energy System Operator and The Labour Party are 💯 committed to delivering the Clean Power 2030 Action Plan, then there is no time to waste and this investment needs to be brought forward at pace. I struggle to see how shifting to zonal pricing would facilitate moving at the pace necessary. Theory is fine, but reality matters.

European power markets with congested networks 𝘂𝗿𝗴𝗲𝗻𝘁𝗹𝘆 𝗿𝗲𝗾𝘂𝗶𝗿𝗲 𝗹𝗼𝗰𝗮𝗹 𝗽𝗿𝗶𝗰𝗲 𝘀𝗶𝗴𝗻𝗮𝗹𝘀. However, reducing the size of pricing zones has drawbacks. As alternative, 𝗹𝗼𝗰𝗮𝗹 𝗺𝗮𝗿𝗸𝗲𝘁𝗽𝗹𝗮𝗰𝗲𝘀 could bring price signals to consumers. Local marketplaces 𝗲𝗻𝗰𝗼𝘂𝗿𝗮𝗴𝗲 𝗺𝗮𝗿𝗸𝗲𝘁 𝗶𝗻𝘁𝗲𝗴𝗿𝗮𝘁𝗶𝗼𝗻 𝗼𝗳 𝗳𝗹𝗲𝘅𝗶𝗯𝗶𝗹𝗶𝘁𝘆, building on experience from local flexibility markets and energy communities. They would be linked by a clearing algorithm that efficiently allocates available transmission capacity, 𝗯𝘂𝗶𝗹𝗱𝗶𝗻𝗴 𝗼𝗻 𝗻𝗼𝗱𝗮𝗹 𝗽𝗿𝗶𝗰𝗶𝗻𝗴 𝗲𝘅𝗽𝗲𝗿𝗶𝗲𝗻𝗰𝗲 in US, Canada, Chile, and New Zealand.   𝗪𝗵𝘆 𝗶𝘀 𝗮 𝗿𝗲𝗳𝗼𝗿𝗺 𝘂𝗿𝗴𝗲𝗻𝘁? •   To save redispatch costs, currently amounting to about 2-4 billion € for consumers in Germany per year. •   To avoid escalating congestion caused by demand flexibility responding to price in large pricing zone that does not reflect the value of electricity at the location. •   To allow transmission system operators (TSO) to provide more grid access to flexibility like batteries. •   To avoid cyber security risks caused by increasing volumes of assets centrally (re-)dispatched. 𝗛𝗼𝘄 𝗰𝗼𝘂𝗹𝗱 𝗹𝗼𝗰𝗮𝗹 𝗺𝗮𝗿𝗸𝗲𝘁𝗽𝗹𝗮𝗰𝗲𝘀 𝗼𝗳𝗳𝗲𝗿 𝗮 𝘀𝗼𝗹𝘂𝘁𝗶𝗼𝗻? •   Think of a farmer’s markets where everyone can sell their local products and meet their local needs. •   Like farmer’s markets, local marketplaces are interconnected: If the local supply is limited and transport is available, traders bring in goods from and to other marketplaces. •   Local marketplaces allow all stakeholders to be rewarded for contributing to system needs – from consumers to producers, from distribution to transmission grid owners, and from retailors and local utilities to exchanges. 𝗛𝗼𝘄 𝗺𝗶𝗴𝗵𝘁 𝗹𝗼𝗰𝗮𝗹 𝗺𝗮𝗿𝗸𝗲𝘁𝗽𝗹𝗮𝗰𝗲𝘀 𝗼𝘃𝗲𝗿𝗰𝗼𝗺𝗲 𝘁𝗵𝗲 𝗱𝗶𝘀𝗽𝘂𝘁𝗲 𝗼𝗳 “𝗹𝗮𝗿𝗴𝗲𝗿 𝘃𝗲𝗿𝘀𝘂𝘀 𝘀𝗺𝗮𝗹𝗹𝗲𝗿” 𝗽𝗿𝗶𝗰𝗶𝗻𝗴 𝘇𝗼𝗻𝗲? •   They avoid a repeated and politically challenging decision on where to draw borders of pricing zones by providing a local price signal at the scale of cities and regions. •   They avoid redispatch that remains necessary with smaller pricing zones (2-5 per country) and thus avoid the need to separate trading from balancing. Local marketplaces thus enhances liquidity and competition compared to smaller and larger pricing zones. It is important to realize: Local prices are primarily required for efficient operation, not for guiding location of demand. 𝗟𝗼𝗰𝗮𝗹 𝗲𝗹𝗲𝗰𝘁𝗿𝗶𝗰𝗶𝘁𝘆 𝗰𝗼𝘀𝘁 𝗱𝗶𝗳𝗳𝗲𝗿𝗲𝗻𝗰𝗲𝘀 𝗮𝗻𝗱 𝘁𝗵𝗲𝗿𝗲𝗳𝗼𝗿𝗲 𝗿𝗶𝘀𝗸𝘀 𝗳𝗼𝗿 𝗰𝗼𝗻𝘀𝘂𝗺𝗲𝗿𝘀 𝗰𝗮𝗻 𝗮𝗻𝗱 𝘀𝗵𝗼𝘂𝗹𝗱 𝗯𝗲 𝗵𝗲𝗱𝗴𝗲𝗱, for example using the tripartite electricity contract. This will support industry and households at any location. Enjoy the joint report with Seabron Adamson Martin Bichler Franziska Klaucke Klaus Mindrup Luis Olmos Camacho Anthony Papavasiliou Konstantin Staschus Leon Stolle Silvia L. Vitiello

https://lnkd.in/eCjUyHbn $10 billion for a data center in rural Louisiana? Yep. Meta is building a massive AI hub in Richland Parish — and Entergy is planning a $3.2B investment in new natural gas plants to power it. That’s one facility. One client. And a whole lot of impact. As someone who's spent decades in the utility and energy industries — and as a proud alum of a Louisiana-based university — this one hits close to home. It’s a clear sign: *The AI boom is no longer a future scenario — it’s here. *Grid planning and energy strategy must shift, fast. *Utilities and tech giants must collaborate differently going forward. This is also a wake-up call for data center operators: *You go where the power is — not just where the talent is. *Sustainability and local impact aren’t side notes — they’re part of your license to operate. *Energy strategy = business strategy. The heartland is becoming the new front line of the energy transition. And those of us in this space? We’ve got work to do. #AI #DataCenters #Utilities #GridPlanning #EnergyTransition #Louisiana #EnergyLeadership #PoweringTheFuture #EnergyIndustry