Entergy Corporation

Overview

Entergy is a New Orleans-based electric utility holding company serving 3.1 million customers across five operating subsidiaries in Arkansas, Louisiana, Mississippi, Texas, and the city of New Orleans. It is one of the largest nuclear operators in the United States, with five reactors at four sites producing approximately 5,400 megawatts. CEO Drew Marsh became chief executive in November 2022 and also chairs the board, succeeding Leo Denault, who led Entergy for roughly a decade. Entergy owns roughly 30,000 megawatts of total generating capacity across gas, nuclear, and a growing share of utility-scale solar, serving a region whose load profile is shaped by a large heat-sensitive residential base, a petrochemical and refining corridor along the Mississippi River, and a fast-growing wave of data center and advanced manufacturing demand.

The geographic footprint is distinctive among major U.S. utilities. Arkansas, Louisiana, Mississippi, and Texas rank among the states with the highest rates of poverty and energy burden in the country, and Entergy's customers spend a higher share of household income on electricity than customers of almost any other large U.S. utility. That shapes every capital spending decision, rate case, and affordability negotiation the company takes to its state regulators: the Arkansas, Louisiana, and Mississippi public service commissions and the Public Utility Commission of Texas. Entergy Louisiana, the largest subsidiary by revenue and capital base, uses a forward-looking formula rate plan approved by the LPSC that reduces regulatory lag and allows more timely recovery of capital investments. Entergy Arkansas is moving back to a similar forward test year approach, with a 2027 rate case filing expected to set new base rates effective January 2027.

Entergy sold all of its merchant nuclear plants in the Northeast between 2016 and 2021: Vermont Yankee closed in 2014, FitzPatrick was sold to Exelon in 2016, Pilgrim closed in 2019, and Indian Point closed in 2021, completing a years-long exit from unregulated nuclear generation outside its service territory. The remaining fleet in Arkansas, Louisiana, and Mississippi operates entirely inside the regulated utility structure, where plant costs are recovered through rates under state commission oversight rather than competing in wholesale power markets.

Business operations

Hurricanes and the cost of serving the Gulf Coast

No large U.S. utility has been tested by severe weather as repeatedly as Entergy. The Gulf Coast service territory sits in the path of Atlantic hurricane season every year, and a major landfall is measured in hundreds of thousands of customer outages, billions of dollars of infrastructure damage, and months of restoration. Hurricane Katrina in August 2005 left 1.9 million of Entergy's 2.7 million customers without power, the largest customer outage in U.S. utility history at the time, across 37,000 square miles, roughly a third of the company's service area. The storm destroyed Entergy New Orleans's financial viability: the subsidiary filed for bankruptcy in September 2005, the only investor-owned U.S. utility to enter bankruptcy from a natural disaster in the modern era, and emerged in 2007 after the city council approved rate recovery and a restructuring plan.

Hurricane Ida in August 2021 struck at Category 4 intensity with 150-mile-per-hour winds at landfall, tied for the strongest storm to hit Louisiana in recorded history, and left nearly 950,000 Entergy customers without power. Restoration cost estimates reached $2.1 billion to $2.6 billion, with Entergy Louisiana absorbing roughly $2.0 billion to $2.4 billion. An NPR investigation published shortly after Ida documented that Entergy had resisted regulators' calls to accelerate grid hardening in the New Orleans area in the years before the storm, which contributed to the severity of outages in some neighborhoods. The reporting detailed how older transmission structures along a corridor from Port Fourchon, where Ida made landfall, performed far worse than newer structures built to post-1997 design standards: more than half the structures on a seven-mile stretch of older line were destroyed, while only three of 387 newer structures on the same general path failed.

The post-Ida response was more aggressive. Entergy rebuilt the critical Mississippi River transmission crossing from Avondale to Harahan, a major link for the New Orleans metro, to withstand winds up to 175 miles per hour, and put the upgraded structure in service within a year of landfall. The company began replacing coastal distribution poles with Class 1 grade steel poles rated for sustained winds above 130 miles per hour, beyond current regulatory requirements. These investments are recoverable through rates, and Entergy pursued securitization of the Ida storm costs with state regulators to spread recovery over years rather than concentrating it in near-term bills.

The underlying tension has no clean resolution. The Gulf Coast territory is physically exposed to the most severe hurricane risk in the continental United States, and building infrastructure to withstand Category 4 and 5 storms at scale costs more than building for less extreme weather. Those costs become higher rates for customers who already pay a large share of their income for electricity. The regulatory compact in Louisiana and Arkansas has generally supported storm cost recovery through securitization and rate cases, and affordability pressure limits how much hardening can be recovered at any given time. Entergy invested approximately $9.5 billion in transmission and distribution assets meeting or exceeding then-current resiliency standards in the five years before Ida, and Ida still caused more than $2 billion in damage.

Financial performance

Entergy reported FY2025 earnings of $1.758 billion, or $3.91 per share on both an as-reported and adjusted basis, finishing in the top half of the guidance range. FY2024 adjusted EPS was $3.65; the full-year 2024 as-reported figure was $2.45 per share on GAAP net income of $1.056 billion, with the difference driven by one-time items. Projected industrial sales growth of roughly 16% annually through 2029 and approximately 3.5 gigawatts of new electric service agreements signed in 2025 drove the performance. Retail sales grew approximately 4% on a weather-adjusted basis in 2025.

For 2026, Entergy guided to EPS of $4.25 to $4.45, roughly 10% growth at the midpoint, and set a 2029 adjusted EPS target of $6.25 to $6.55. The company targets more than 8% compound annual EPS growth through 2029, with weather-adjusted retail sales growing at roughly 8% a year over the same period on an industrial growth rate near 16%. The $57 billion 2026 through 2029 capital plan, raised by more than 30% after the Meta data center commitments and other large load agreements, includes $27 billion for new generation. That build is weighted toward combined-cycle gas and utility-scale solar, with nuclear uprate and fuel cycle investments included.

Strategy & outlook

Entergy's service territory has become one of the most sought-after locations for large industrial and hyperscale data center development in the country. Available land, relatively low-cost industrial power rates, proximity to existing fiber and logistics infrastructure, and a Louisiana state government willing to move large economic development projects have drawn commitments from Meta, AWS, Google, and multiple advanced manufacturing operators. The data center pipeline of 7 to 12 gigawatts and the separate 3 to 5 gigawatts of other industrial demand amount to a demand transformation that, even at 20% to 30% realization, would require a sustained generation and transmission build unlike anything in the company's recent history.

The electric service agreement structure Entergy has built for large customers requires them to pay the direct power costs attributable to serving their facilities and to provide up-front revenue support, which is designed to keep load growth from raising costs for existing residential and small commercial customers. The formula rate plan mechanisms in Louisiana and Mississippi, which allow timely capital recovery with minimal regulatory lag, are essential to financing the $57 billion program without waiting years for traditional rate case approvals. The nuclear fleet, with IRA production tax credit support through 2032 and continuing discussion of uprates and a potential Grand Gulf Unit 2, sits where clean energy demand from data center customers meets the baseload reliability the regional grid requires.

Key considerations

Affordability is the persistent constraint on Entergy's capital program. Arkansas, Louisiana, and Mississippi rank near the bottom of all U.S. states on median household income, and Entergy's customers already carry above-average energy burden. A $57 billion capital program, even with formula rate plan recovery, means bill increases that regulators in these states are politically reluctant to approve without visible pushback. The electric service agreement structure protects existing customers from subsidizing large industrial load in principle, and the indirect effects of generation overbuild, transmission upgrades, and administrative costs still diffuse across the rate base. The tension between the investment required to modernize the grid, attract industrial growth, and harden the system against hurricanes, and the capacity of low- and moderate-income customers to absorb the resulting rates, is not temporary. It is the permanent operating environment.

Hurricane season remains a financial and operational variable with no hedge. The Gulf Coast is seeing more intense storm activity as sea surface temperatures rise, and Entergy's territory is geographically inescapable. Post-Ida investments have measurably improved the system's ability to take a major storm, and a Category 4 or 5 direct hit on the New Orleans metro or the Baton Rouge chemical corridor would still produce billions in restoration costs, months of outages in the worst-affected areas, and pressure on regulators for rapid securitization and rate recovery. The nuclear PTC cliff in 2032 is a secondary concern, since the fleet is plainly more valuable today than it was in 2020, and its expiration without renewal or replacement would reintroduce earnings uncertainty into a segment that has become a meaningful growth contributor.

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