Skip to main content

Renewables Transition

Updated Jun 24, 2026 at 8:22pm

Research Draft High 1,128 words

The "renewables transition" is the multi-decade shift of regulated and merchant electric utilities away from coal- and gas-fired generation toward wind, solar, battery storage, and transmission. For utility investors it is less a green-policy story than a capital-deployment story: the transition is the single largest driver of the capex super-cycle that determines a regulated utility's rate base, and therefore its earnings growth. The core tension is that the same spending that grows earnings also concentrates two risks — regulatory disallowance of the cost recovery, and policy/tax-credit reversal that changes project economics mid-build.

How it works — the rate-base mechanism

A regulated utility earns a state-commission-approved return on its rate base (the depreciated value of prudently invested capital used to serve customers), not on the volume of electricity sold. Earnings, very roughly, follow:

Earnings ≈ Rate Base × Allowed Return on Equity (ROE) × Equity Ratio

So when a utility retires a coal plant and builds wind, solar, storage, and the transmission to connect them, it grows rate base — and growth in rate base, holding the allowed ROE constant, is the dominant lever on EPS. Allowed ROEs for U.S. electric utilities have commonly clustered in the ~9–10% range in recent rate cases (figure varies by jurisdiction and year; see RMI's work on utility ROE).

Two complications matter for the transition specifically:

  • Stranded-asset / undepreciated cost recovery. Retiring a coal plant early leaves unrecovered book value. Recovery comes via continued (accelerated) depreciation, a regulatory asset, or increasingly securitization — issuing low-cost ratepayer-backed bonds through a special-purpose entity, repaid by a non-bypassable customer charge. Roughly 21 states had enabling legislation as of recent reporting, and securitization has lowered the customer-bill cost of early retirements versus traditional recovery (Utility Dive, Niskanen Center).
  • Tax credits. Federal Production (PTC, §45Y) and Investment (ITC, §48E) tax credits — and the IRA's transferability and direct-pay mechanisms — materially improve project economics and are typically flowed back to customers, easing the bill impact that regulators scrutinize.

How it's used in practice

Analysts evaluating a transitioning utility focus on:

1. Rate-base / capex CAGR and the EPS guidance it underwrites. Management gives multi-year capex plans and a long-term adjusted-EPS growth target. NextEra, the largest U.S. renewables developer, has guided to an 8%+ adjusted-EPS CAGR through 2032 and reiterated 2026 adjusted EPS of roughly $3.92–$4.02 (TIKR). Sector-wide, U.S. utility capex is in a documented super-cycle — projected near $215B in 2025 (up ~19% YoY from ~$173B in 2024 per S&P Global Market Intelligence) and rising toward ~$228B in 2026 per S&P Global / Gabelli summaries (Gabelli). 2. Regulatory constructiveness. Will the commission let the utility recover and earn on this spending? A "constructive" jurisdiction with riders/trackers, forward test years, and securitization authority de-risks the plan. This is often the most important qualitative variable. 3. Funding mix. Double-digit rate-base growth typically requires "material debt and stock issuance" (Eco Fin). Heavy equity issuance dilutes EPS growth; balance-sheet strain pressures the dividend and credit rating. 4. The Integrated Resource Plan (IRP). The IRP is the commission-filed roadmap of retirements and new builds — the primary document for sizing the pipeline and its timing.

Adoption, debate & evidence

The transition is firmly underway, not speculative. Renewables supplied ~26% of U.S. generation in 2025 (wind ~11%, solar ~7%; EIA's headline was that wind and solar together set a record at ~17% of utility-scale generation, ~19% including small-scale solar), versus natural gas ~41% and coal ~17%; EIA forecasts wind+solar rising further by 2027 (EIA). Since 2010 the U.S. has retired ~100 GW of coal with ~80 GW more slated by 2030 (Gabelli).

What is genuinely contested:

  • Pace and policy durability. The One Big Beautiful Bill Act (OBBBA, July 2025) accelerated phase-outs of wind/solar credits — projects generally must begin construction before July 5, 2026 or be placed in service before Jan 1, 2028 — while preserving transferability (Sidley, Latham). This is the central live risk: the transition's economics are partly federal-policy-dependent.
  • Load growth changing the narrative. Data-center/AI demand has flipped utilities from flat-load to growth; this supports more capex of all kinds — including new gas and nuclear — so "transition" no longer means coal-for-renewables one-for-one.
  • Stranded-asset overhang. Carbon Tracker estimated (2017) ~$185B of potentially uneconomic regulated coal — a figure that frames, but is not a precise current measure of, the recovery risk (Utility Dive).
  • Climate-alignment gap. RMI notes most utility IRPs are not moving fast enough for a 1.5°C pathway — so for ESG-screened investors the "green" label is often weaker than headlines imply (RMI).

Strengths & limitations

When it works: a constructive regulator + visible multi-year IRP pipeline + manageable funding = durable, low-volatility rate-base-driven EPS and dividend growth. This is the classic regulated-utility "bond-proxy with a growth kicker."

When it fails: (1) a rate case grants a lower ROE or disallows recovery; (2) federal tax-credit changes (OBBBA) erode project returns or trigger a rush-then-cliff in development; (3) execution — interconnection queues, supply-chain and interest-rate cost overruns — blows the budget; (4) excessive equity issuance dilutes the very EPS growth the capex was meant to create.

The #1 misuse: treating renewables capex as automatically accretive. Capex only grows earnings if the regulator allows recovery at an adequate return and the company funds it without heavy dilution. A big "green pipeline" with an unconstructive commission can be value-destructive.

Sources

Disputes/soft spots flagged inline: precise allowed-ROE band (~9–10%) and the $185B stranded-asset figure are illustrative/dated, not current point measures; capex projections vary by forecaster (S&P Global vs Gabelli) and revision date.