US utility analysts anticipate that discussions on first-quarter 2024 earnings calls will continue to be driven by artificial intelligence (AI) and data center power demand. Analysts highlighted data centers as a key theme, expecting talks on various aspects surrounding it.
Data Centers Powering Up Utility Investor Excitement
Data centers are power-hungry and their exploding energy needs create ripple effects on the power sector. The International Energy Agency estimates that power use in data centers will increase from 200 terawatt-hours (TWh) in 2022 to 1,050 TWh in 2026, the same energy demand as Germany.

The company serving the largest data center market in the world, Dominion Energy Inc., currently focuses on building the Coastal Virginia Offshore Wind project, the nation’s largest once operational. The company has proposed delaying fossil fuel retirements and adding gas capacity due to anticipated growth in its service areas.
Dominion has also outlined a $43.2 billion capital plan for 2025–2029 following a 16-month business review.
Another analyst at Scotia Capital (USA), Andrew Weisel, noted that data centers’ robust demand for continuous power generates excitement among utility investors. However, questions remain about how customers will pay for increased capital expenditure (capex) and how companies will raise capital. These concerns arise from stubbornly high interest rates.
While Scotia Capital lowered target prices across the US utility sector due to rising interest rates, analysts expect companies to stick to their 2024 and long-term financial forecasts. Moreover, experts emphasized that utilities are generally in a good financial position and are likely to reaffirm their growth plans.
NextEra Energy Inc., the largest electric utility based on market cap, reported first-quarter 2024 adjusted earnings that surpassed expectations and reaffirmed its 6% to 8% long-term earnings per share (EPS) growth rate. The company expects adjusted EPS of $3.23 to $3.43 for 2024, followed by adjusted earnings of $3.45 to $3.70 per share for 2025 and $3.63 to $4.00 for 2026.

Analysts at BMO Capital Markets noted that the improvement in forward power prices has outpaced the movement in regional gas hub pricing. This indicates tightening conditions in the power market and validating investors’ optimistic outlook on the sector.
BMO expects Constellation, NRG Energy, and Vistra Corp. to experience a 33% increase in EPS compared to the previous year. Additionally, NextEra Energy, with nearly 60 GW of renewable generation capacity, could benefit from the increasing electricity needs of data centers.
Capitalizing on AI Boom and Surging Energy Demand
Among independent power producers, analysts anticipate a significant focus on strategies to capitalize on the growing demand for AI. This follows Talen Energy Corp.’s affiliate Cumulus Growth Holdings LLC’s sale of a hyperscale data center campus in Pennsylvania to Amazon Web Services Inc. for $650 million.
The facility boasts a capacity of up to 960 MW for data centers and will be powered by Talen’s 2,494-MW Susquehanna Nuclear power plant in Luzerne County, Pennsylvania.
Recent reports from Morgan Stanley suggest that similar deals could emerge, highlighting the potential for merchant nuclear power plants to provide on-site generation for tech companies constructing data centers in the US. The reports identify generation assets totaling nearly 22 gigawatts (GW) as well-positioned to take advantage of this trend.
The reports also projected that AI power demand causing massive growth of data centers will rise to an annual average of 70% through 2027. Thus, electric utilities, particularly the regulated ones would invest in renewable energy and storage initiatives to cope with the demand.
In fact, renewable energy developers secured contracts for at least 4,012.6 MW of capacity in the 12 months. Tech companies will use them to power US data centers partially or entirely, per S&P Global Commodity Insights data.
Lagging Behind the Quick Pace
While some utilities are racing to power data centers, some may not be quick enough to keep pace.
Rudy Garza, CEO of CPS Energy, highlights the urgency of meeting the massive power demands of these facilities, which often require hundreds of megawatts of electricity in short timeframes, unlike traditional industrial plants with longer lead times.
This immediate need for power presents a formidable challenge for utilities striving to keep pace with the relentless growth of data-driven industries.
Philip Nevels of AES Corp. echoes this sentiment, emphasizing the monumental task of accommodating the anticipated surge in capacity needs driven by AI and data centers. Nevels further acknowledges the inherent limitations in scaling up renewables fast enough to meet the escalating demand.
Meanwhile, Kevin Chandra of Austin Energy underscores the importance of collaborative planning to address the spatial distribution of data center loads effectively. Shaun Hoyte of Consolidated Edison Inc. emphasizes the critical role of redundancy and resiliency in grid planning to mitigate potential disruptions caused by the increasing concentration of data centers.
Sunny Elebua of Exelon Corp. acknowledges the benefits of load growth in advancing decarbonization efforts and optimizing grid utilization. However, Elebua also highlights the challenges posed by the retirement of baseload generation and the evolving supply stack, emphasizing the importance of ensuring resource adequacy amidst these transitions.
In navigating these complexities, utilities recognize the need for state-level support to streamline regulatory processes and facilitate the rapid deployment of energy infrastructure to meet data center demands.
In summary, the proliferation of AI and data centers is reshaping the energy landscape, presenting both opportunities and challenges for utilities worldwide. As the demand for data-driven services continues to escalate, proactive collaboration, strategic planning, and innovative solutions are essential to ensure a resilient and sustainable energy future.
The post Data Centers Power Demand Fuel U.S. Utility Q1 Earnings Discussions appeared first on Carbon Credits.
Carbon Footprint
Insetting vs Offsetting: Which Actually Counts Toward Your Scope 3 Targets
The accounting differences that decide whether your nature investment shows up in inventory, in BVCM, or nowhere at all.
The question reaches a procurement team about three weeks before the next sustainability committee meeting. Someone has read about insetting. Someone else has just signed off on an offset purchase. The CSO wants to know if the two are interchangeable. The answer is no, and the GHG Protocol Land Sector and Removals Standard is the reason why.
This article walks through what each term means at audit-grade specificity, what the standards actually say about how each gets counted, and how to decide which tool fits which target. The insetting vs offsetting question is one of the most-searched in corporate climate strategy, and one of the most poorly answered. By the end of this piece, you should be able to brief a committee on the difference without notes.
The two definitions, in plain English
Offsetting means buying carbon credits generated outside your value chain and retiring them against your residual emissions. The reduction happens somewhere else, financed by you, and the credit is the receipt.
Insetting means investing in emission reductions or removals inside your own value chain, typically with suppliers, where the reduction is directly linked to the products and services you buy. The reduction happens inside the boundary of your Scope 3 inventory, and the accounting treatment is fundamentally different.
The shorthand from the University of Oxford’s Nature-based Insetting Initiative is useful: insetting is what you do with the supply chain you have; offsetting is what you do with the supply chain you do not have.
What the GHG Protocol Land Sector Standard actually says
The GHG Protocol Land Sector and Removals Standard, finalised in 2024 after a multi-year pilot, sets the rules for how land-based emission reductions and removals enter corporate inventories. The Standard distinguishes between inventory accounting (Scope 1, 2, and 3) and project or intervention accounting (a separate methodology for crediting).
For insetting, the practical implication is that supplier-level interventions, when properly measured and attributed, can reduce your Scope 3 category 1 (purchased goods and services) emissions in your inventory. The reduction is not a credit retired against the inventory; it is a lower inventory number, period.
For offsetting, the credit is retired separately. It can be reported as a contribution toward a net-zero claim under the SBTi Beyond Value Chain Mitigation framework or as part of a VCMI Carbon Integrity claim, but it does not lower the inventory number.
A practical consequence: if your Science Based Target requires a 50% absolute reduction in Scope 3 emissions by 2030, insetting moves you toward the target. Offsetting does not. This single point of difference reshapes the procurement decision.
When insetting counts toward Scope 3 (and when it does not)
Insetting counts toward Scope 3 only when several conditions are met:
- The intervention must occur with an entity in your value chain.
- The emissions reduction or removal must be measured against a defensible baseline.
- The reduction must be attributed to your share of that supplier’s output, not double-counted with other buyers.
- It must follow the inventory accounting rules in the GHG Protocol Land Sector Standard, not the project accounting rules used to generate credits.
The most common failure mode is double counting. If your supplier sells the same reduction as a credit on the voluntary market and also reports it to you as a Scope 3 reduction, the math breaks. The Standard requires you to address this risk, typically by purchasing and retiring the supplier-issued credit as part of your inventory or by contractual provisions that prevent the supplier from selling the reduction twice.
When insetting does not count toward Scope 3: when the intervention sits with a supplier you do not buy from, when the baseline is not defensible, when the attribution is unclear, or when the documentation does not survive audit. Those cases default to Beyond Value Chain Mitigation, which is still useful but operates on a different ledger.
The procurement and supplier engagement question
Insetting is harder than offsetting. That is the unfashionable truth most buyers eventually confront. Offsetting is a transaction; insetting is a relationship.
To run an insetting program, you need supplier mapping precise enough to know which farms or facilities sit at which Scope 3 boundary. You need an engagement model that gets suppliers to participate, which usually requires multi-year commitments and shared economics. You need an MRV architecture that measures the right things and produces audit-ready documentation. And you need a contractual structure that prevents double counting and protects both sides.
The trade-off you receive in return is significant. Reductions count against your inventory rather than your residual. Supplier relationships deepen, which protects sourcing continuity. Yield and quality improvements often follow regenerative interventions, which reduces your input cost over time. And the regulatory file, under CSRD, CSDDD, EUDR, and the SBTi FLAG Guidance, is materially stronger.
Choosing the right tool for the right target
A practical decision rule. If your target is a science-based Scope 3 reduction and you operate in a FLAG sector or source FLAG commodities, insetting is the structurally correct tool. If your target is a net-zero claim that includes neutralising hard-to-abate residual emissions outside your value chain, BVCM via high-integrity offsets is the structurally correct tool. Most companies with material Scope 3 exposure need both, in different proportions, sequenced over time.
The sequencing matters. Insetting takes longer to stand up but produces a permanent reduction in the inventory. Offsetting can be transacted faster but does not change the inventory and now sits under tighter claim restrictions. Treat them as complementary tools with different jobs, not as substitutes. The Accountability Framework Initiative and the IUCN Global Standard for Nature-based Solutions both provide useful guardrails for the insetting side, with biodiversity, human rights, and benefit-sharing requirements that go beyond carbon math.
If you are mapping a Scope 3 reduction roadmap and need to scope which interventions count toward your inventory versus which sit in Beyond Value Chain Mitigation, the carbon and sustainability experts at Carbon Credit Capital can help you structure a nature-based supply chain investment program that fits your FLAG exposure, your target architecture, and your audit horizon. Schedule a consultation.
Carbon Footprint
Net zero needs nature: a carbon credit guide
Net zero is often described as a balancing act: cut what you can, account for the rest, and reach zero on the ledger. That framing is useful, but it leaves something out. It treats every tonne of carbon as interchangeable and every route to zero as equally sound, while the science tells a more specific story.
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Carbon Footprint
Deforestation in Malawi: causes and solutions
Malawi has lost a striking share of its forests over the past three decades. Woodlands that once covered well over a third of the country now cover less than a quarter, and the pressure on what remains is increasing. Behind those figures sit two practical questions: what is driving the loss, and what reverses it?
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