The companies that built their energy strategy around efficiency are discovering a gap between what that strategy promised and what it has delivered. Carbon reduction targets are behind schedule. Energy cost exposure is growing despite lower consumption per unit of output. And the risk profile of their energy supply chain looks nothing like what the efficiency roadmap assumed when it was written.
This is not a story about efficiency programs failing. Most of them worked as designed. The problem is that the problem they were designed to solve has changed, and three structural shifts in the energy environment have rendered the original strategy insufficient. The organizations that understand this before H2 (July-December) capital planning begins will be in a fundamentally different position than those that don't.
What Efficiency Strategies Were Built to Address and What They Missed
Corporate efficiency programs from the 2015 to 2022 era were largely designed around three assumptions: that energy costs would remain relatively stable, that grid reliability would be adequate, and that carbon reduction through demand reduction would pace with corporate climate commitments. All three assumptions have shifted materially.
Energy costs have not remained stable. The average residential and commercial retail electricity price is projected to be approximately 4.5% higher in 2025 compared to 2024, according to Deloitte's 2026 Power and Utilities Industry Outlook. That follows two previous years of above-average increases, compounding the gap between the rate environment that efficiency project payback calculations assumed and what organizations are actually paying.
Grid reliability is under intensifying stress. The U.S. Department of Energy (DOE) projects approximately 104 GW of coal and natural gas retirements by 2030, offset by 209 GW of new capacity. But only 10% of those new additions will be firm baseload, according to Deloitte's analysis, which means the reliability gap is not being filled at pace with the capacity being retired. NERC's 2025 Long-Term Reliability Assessment flagged elevated risk in multiple regional interconnections. In the first half of 2025 alone, the U.S. experienced 15 natural disasters each causing $1 billion or more in damages, at least three of which exceeded $5 billion in losses.
And demand is growing at a rate that no efficiency roadmap anticipated. In just four years, the five-year forecast for U.S. electric power demand growth has increased by a factor of six, according to Grid Strategies' 2025 national load growth report. Of the 166 GW of forecast peak load growth, roughly 90 GW are linked to data centers alone. Peak demand is projected to grow by approximately 26% by 2035, testing grid limits that were already under strain before the AI infrastructure buildout began.
Efficiency programs reduce how much energy organizations consume. They do not address where that energy comes from, whether it will be available when it is needed, whether the grid's carbon intensity has shifted in ways that affect the math, or whether rising baseline demand from digital operations is outpacing the reductions efficiency programs deliver.
Where the Corporate Climate Commitment Gap Is Most Visible
The gap between efficiency-based commitments and actual carbon trajectories is most visible in organizations with Science Based Targets. Approximately 40% of Fortune 500 companies have near-term science-based targets, a figure that has been essentially flat for two years. That stability masks a more troubling dynamic: the Science Based Targets initiative (SBTi) removed 239 companies from its dashboard in 2024 for missing the 24-month target validation window, and overall participation in the SBTi Net Zero Standard has declined from 18% to 17% of the Fortune Global 500. Of the original 239 companies removed in March 2024, only 17 had returned with revalidated net-zero targets by late 2025.
The problem is structural, not cyclical. Efficiency programs reduce what organizations consume in the facilities and operations they directly control. They do not address the carbon content of the electricity those facilities purchase from a grid whose emissions profile is determined by generation mix, weather, and demand that are entirely outside the organization's control. In markets where coal and natural gas remain dispatch-setting generators during peak demand periods, an organization's actual carbon exposure can fluctuate significantly with market conditions regardless of how efficiently it operates.
How the 2025 Policy Environment Changed the Calculus
The passage of the 2025 reconciliation bill, widely known as the One Big Beautiful Bill Act, introduced a second layer of disruption for corporate energy strategies. The legislation rolled back many clean energy incentives that organizations had incorporated into their procurement planning, expanded foreign entity of concern restrictions, and narrowed safe-harbor provisions in ways that compressed developer timelines and increased compliance complexity. Organizations that had structured power purchase agreements (PPAs) or on-site generation projects around the prior incentive environment are now navigating a changed legal and financial landscape.
The investment pipeline reflects this disruption. In the first nine months of 2025, $6 billion across 58 renewable energy deals were announced, a 41% fall in deal value and a 45% drop in volume from the prior year, according to Deloitte's 2026 Renewable Energy Industry Outlook. Asset-level deals slowed by 89% in volume in the first eight months of 2025 compared with 2024. For corporate buyers, that contraction means less liquidity in the market for the zero-carbon supply contracts that are supposed to complement efficiency programs in an integrated energy strategy.
The Capital Reframe That High-Performing Organizations Are Making
The organizations that are closing their energy and carbon gaps are not doing less efficiency work. They are doing efficiency work within a broader energy portfolio that includes zero-carbon supply, on-site generation, storage, and demand flexibility. The capital reframe involves treating energy investment as a portfolio decision rather than a project-by-project efficiency calculation.
Portfolio thinking allows organizations to model the interaction effects between asset types: how demand response programs reduce peak exposure that efficiency retrofits can't address, how on-site generation hedges against rate increases that are eroding efficiency project paybacks, how battery storage provides resilience protection that no amount of demand reduction can offer. RMI's 2025 analysis of energy systems found that integrating efficiency with renewables and electrification (whole-systems approach) provides faster, more cost-effective, and more reliable decarbonization compared to relying on energy efficiency measures alone..
The wholesale market is moving in the same direction. S&P Global's 2026 Energy Horizons analysis documents a market shift from standard power purchase agreements toward flexibility-backed hedges, with hybrid PPAs combining multiple technologies and storage to manage risk and monetize strategically. That structural change reflects the same recognition at the market level that corporate energy strategies need to reflect at the organizational level: that efficiency reduces consumption but flexibility and diversification manage the risks that reduced consumption does not address.
What the Grid Stress Environment Means for Carbon Accounting
The reliability pressures accumulating in the U.S. grid create a specific challenge for corporate carbon accounting that efficiency strategies were not designed to handle. When grid stress events drive higher dispatch of natural gas peakers, the emissions intensity of the electricity an organization purchases rises regardless of how efficiently it uses that electricity. An organization that achieved a 15% reduction in energy intensity over three years can still be carrying more carbon exposure than its efficiency program claims if the marginal emissions of its grid supply have increased.
This is not a hypothetical concern. S&P Global's climate scientists estimate there is a 50% likelihood that global average temperatures will exceed 2.3 degrees Celsius above pre-industrial levels by 2040. The global average temperature from January to August 2025 was already 1.4 degrees Celsius above pre-industrial levels, just short of the Paris Agreement's 1.5-degree limit. The grid stress events associated with that trajectory, including extreme heat driving peak cooling demand into ranges that strain both reliability and carbon accounting, are already affecting the relationship between operational efficiency and actual emissions performance.
What C-Suite Leaders Need to Change Before H2 Planning
The conversation that needs to happen before H2 capital planning is not about whether to fund efficiency. It is about whether efficiency is the right primary strategy, or whether it is one component of a strategy that also needs to include supply procurement, resilience investment, and demand management. For organizations with public climate commitments, the answer has financial, legal, and reputational consequences. For organizations focused primarily on cost management, it has direct bottom-line implications that rising rates and grid volatility are making harder to ignore.
The practical starting point is a gap analysis that asks two questions the efficiency investment case rarely addresses:
- What % of our carbon reduction commitment requires zero-carbon supply rather than demand reduction, and what is our current procurement position against that requirement?
- What % of our energy cost exposure is addressable by efficiency versus by rate structure, demand charges, or reliability events, and are we investing in proportion to that split?
Organizations that have answered those questions are already reallocating capital toward on-site generation, storage, and procurement instruments. The ones that haven't are managing an efficiency program and calling it an energy strategy. Those are different things, and the gap between them is becoming visible in places that C-suite leaders care about: disclosed climate performance, energy cost trajectories, and the resilience of operations through the grid stress events that are increasingly part of the baseline planning assumption.
The leaders who will be in the strongest position at year-end are the ones who had this conversation before July, not in response to Q3 earnings pressure or an investor question that arrives after the H2 capital budget is already locked.
