Entergy New Orleans is the electric utility of a single parish, regulated by a municipal city council rather than a state commission, and the economics of that arrangement define everything an investor should expect from the stock. The 2018 settlement ordinance capped the authorized return on common equity at 9.35 percent, and it paired that cap with a narrow formula rate plan bandwidth that resets rates annually.
The balance sheet carries a loss contingency accrual of roughly $80 million tied to an unresolved FERC tariff proceeding, and the July 2026 FERC order on net operating loss carryforward ADIT may convert that accrual into either a payment obligation or a receivable for the company. The pending formula rate plan cycle, the FERC ruling, the debt ceiling mechanics, and the weather cycle are the four variables that move the equity.
The company serves more than 209,000 electric customers in Orleans Parish, all of them inside the city limits, and the New Orleans City Council is its sole retail regulator. That structure stands apart from the typical regulated utility of this size because the city council sits on both sides of the table as employer and regulator, and its staffed legal team and external advisors push back hard on every filing. The council adopted the 2018 settlement ordinance that set the 9.35 percent authorized return on equity and the electric formula rate plan, and that document is the contract that governs the business.
The formula rate plan means that base rates reset annually through a formula rather than through a contested rate case, which compresses the upside of a good year into a smaller bill increase and compresses the downside of a bad year into a smaller bill decrease. The company filed its 2025 test year evaluation in April 2026, and the evaluation produced an earned return well below the authorized level. The formula mechanics therefore require a revenue increase of roughly $16.6 million. The city council advisors have already proposed to shave $4.4 million off that figure through cost realignments and disallowances, and the dispute enters a contested phase in August 2026.
The plant is an urban distribution system built for hurricane country, and the electric net property stood at roughly $1.57 billion as of mid 2026. A regulatory asset of about $115 million sits on the balance sheet, representing costs the company expects to recover from customers over time. The moat is legal rather than technical. The city council franchise, the settlement ordinance, and the formula rate plan together lock the company into a regulated rate of return on a defined rate base, which is the same economic structure as every other regulated utility but administered by a municipal body with a stronger political incentive to hold rates down.
The gas business was a second franchise that no longer exists. In October 2023 the company signed an agreement to sell the natural gas distribution operation to a Bernhard Capital Partners affiliate for a base price of $285.5 million. The transaction closed on July 1, 2025, after the city council and the state commission granted their approvals. The mechanism of that divestiture matters for the thesis because it removed the gas rate base and the associated customer franchise from the company, leaving a single asset class and a single regulator. The consequence for shareholders is that the equity is now a pure electric distribution play with a city hall regulator, which simplifies the business but concentrates all of the political risk in one body. The proceeds were applied to pay down debt and to support the parent capital program, and the transaction removed a gas rate base that had been earning a regulated return for decades.
Second quarter 2026 revenue came in at $190.5 million, down from the year earlier level. Net income fell to $15.4 million, against $18 million a year earlier. The revenue decline is a direct function of the gas sale and of softer electric volume. The first half of 2026 produced $362.2 million in revenue. Net income for the period was $21.8 million, a modest improvement over the prior year that the formula rate plan mechanism smoothed.
The income statement tells a quieter story. Operating income of $29.5 million in the quarter covered interest expense of $9.8 million, and the remainder carried the tax line and the net income figure. The margin on a regulated base stays thin but positive. The balance sheet shows total assets of about $2.09 billion. Long-term debt stood at roughly $655 million with no current maturities, and members equity came in at $629.8 million, a modest uptick from the start of the year. The debt to capitalization ratio is therefore near 50 percent. That level sits at the top of the range the city council financing plan allows, and the council approved a new two year debt authorization in December 2025 that caps aggregate long-term debt at $1.3 billion. The capital structure is therefore conservative by regulated utility standards, and the headroom under the ceiling is the company main source of financial flexibility.
The cash flow picture is the more important number for the equity. Operating cash flow for the first half was small relative to the consolidated group because the company is a cash box subsidiary that pays dividends upstream, and the capital expenditure cycle of roughly $1.9 billion across the group in 2025 is funded at the parent. The company paid $12 million in common equity distributions to Entergy Corporation in the first half, and that upstream dividend is the primary source of cash flow to the parent shareholders. The $80.2 million loss contingency accrual on the balance sheet is the single largest liability item that is not debt or a regulatory obligation, and it exists because of the FERC proceeding described below.
The 2025 formula rate plan evaluation filed in April 2026 is the near term catalyst, and the mechanism behind it is worth stating plainly because it is the engine of the entire earnings model. The formula compares the earned return on the rate base against the authorized return each year, and any gap translates into a bill adjustment in the following cycle. The evaluation showed an earned return of 7.55 percent, well inside the bandwidth around the authorized return. The formula therefore requires a revenue increase of $16.6 million to bring the company back to the authorized return. The city council advisors issued a report in July 2026 seeking to reduce that increase by $4.4 million through cost realignments and imputed revenues. The company filed its response in August 2026. The resulting rates become effective with the first billing cycle of September 2026, and the dispute over the advisors recommendations is now the central execution risk for the next two quarters.
The FERC proceeding on net operating loss carryforward ADIT under the MSS-4 replacement tariff is the other large variable, and it has been running in the federal docket since 2021. The dispute traces to a question of how deferred tax items flowed through the wholesale replacement tariff years ago, and the stakes have compounded as the rate base grew. The June 2026 FERC order found a historical tariff violation. The order also required refunds and surcharges covering sales from 2016 through 2023. The company filed for rehearing in July 2026. The filing is explicit that each affected operating company could either receive material refunds or owe material surcharges, depending on the guidance issued. The company has recorded an $80 million loss contingency accrual against the exposure. The city council advisors have proposed a five year collection mechanism to recover any amounts owed, and the $20 million figure they cite is a rough estimate of the exposure socialized across the customer base. That proposed collection mechanism is a signal that the council expects the FERC outcome to cut against the company, and the size of the exposure is what the council is trying to socialize across the customer base.
The debt authorization cycle is a smaller but real constraint. The council approved a two year debt window in December 2025 that allows new first mortgage bonds and debt securities through 2027. The authorization is subject to the $1.3 billion aggregate cap and to the requirement that no issuance cause a retail rate change outside a formula rate plan proceeding. The company issued $40 million in first mortgage bonds in May 2026 under that authorization, and the next issuance window is open. The execution risk is not that the company cannot raise capital, but that any capital raise that pushes debt toward the ceiling reduces the flexibility for future grid investment in a hurricane season.
The largest single risk is the FERC MSS-4 ruling and the rehearing outcome. The company has a loss contingency accrual of $80.2 million on its balance sheet as of mid 2026. The city council advisors have proposed a five year collection mechanism of $20 million to socialize the potential payment across the customer base. If the FERC guidance confirms that the company owes surcharges to Entergy Louisiana and Entergy Arkansas, the $80 million accrual may prove insufficient, and the parent would absorb the difference through reduced dividends or a capital contribution. The counterargument to that bear case is that the company filed for rehearing alongside the LPSC, the City Council, and the PUCT, and all four of those parties have an interest in limiting the surcharge, which gives the rehearing a realistic chance of narrowing the exposure. The accrual is a management estimate, and the fact that the company has not provided a range of reasonably possible outcomes beyond the accrual is itself a signal that the uncertainty is high.
The second risk is the formula rate plan dispute with the city council advisors. The advisors have already proposed a $4.4 million reduction to the revenue increase of $16.6 million. The company has 25 days to resolve the dispute before the council sets a procedural schedule. If the council sides with the advisors, the effective revenue increase falls to about $12.2 million, which is a meaningful haircut to the authorized return and would push the earned return further below the 9.35 percent midpoint in the following year. The bandwidth mechanism means the company cannot claw back the difference in a later cycle, so the haircut is permanent within the formula structure.
The third risk is weather. Orleans Parish sits at the intersection of the Gulf of Mexico hurricane track and the Mississippi River floodplain, and the company has carried a $75.1 million asset recovery damaged property cost balance as of mid 2026. A major storm would spike O&M and restoration costs, and the company would recover those costs through the storm cost recovery rider, but the recovery timeline can stretch two to three years. The fourth risk is the debt ceiling. The council cap of $1.3 billion on aggregate long-term debt is about double the current $655 million balance, which leaves room, but the council has shown in past proceedings that it pushes back on any issuance that it views as not for customer needs, and the debt cap is a soft constraint that can be tightened in a future financing plan resolution.
The company is not separately listed, and the equity is held by Entergy Corporation as a wholly owned subsidiary. The valuation therefore runs through the parent multiple and the subsidiary dividend stream. Entergy Corporation trades at a multiple that reflects a mid 9 percent return on equity across the group, and the New Orleans subsidiary contributes a small but stable share of the consolidated utility earnings. The bear case assumes the FERC ruling produces a net payment of $50 million to the sellers, the council reduces the formula rate plan increase by the full $4.4 million, and the debt ceiling constrains the next capital cycle. In that scenario the subsidiary dividend shrinks by about $10 million per year on a run rate basis.
The base case assumes the rehearing narrows the FERC exposure to $25 million and the council allows $14 million of the requested increase. The company maintains its 50 percent debt to capitalization ratio in that scenario. In that scenario the subsidiary dividend holds near the $12 million first half run rate, and the equity value is supported by a stable regulated earnings stream. The base case is the one that the current multiple most closely reflects, and the spread between the bear and bull cases is the spread in the subsidiary earnings line over a two year horizon. The bull case assumes the rehearing produces a net receivable for the company and the council allows the full requested increase. The company completes a $200 million bond issuance in 2027 to fund grid hardening. In that scenario the subsidiary earnings expand by roughly $15 million per year, and the dividend grows with it.
The multiple framework is a regulated utility multiple applied to a subsidiary earnings stream, and the appropriate multiple is the parent multiple adjusted for the subsidiary specific risks. The parent trades at a price to earnings ratio that embeds a cost of equity in the mid 8 percent range, and the New Orleans subsidiary earns a lower authorized return than the group average because of the city council regulator. The appropriate valuation therefore applies a discount to the parent multiple for the regulatory haircut and the FERC overhang, and the discount is largest in the bear case and smallest in the bull case.
Entergy New Orleans is a regulated electric distribution utility with a single parish customer base, a city council regulator that has a demonstrated record of pushing down rate increases, and a pending FERC ruling that could move the earnings line by a double digit million dollar amount in either direction. The 9.35 percent authorized return is a modest but reasonable number for a hurricane exposed urban grid, and the formula rate plan mechanism compresses the variability of that return into a narrow band. The gas divestiture simplified the business and removed a second franchise, which is a positive for focus but a negative for diversification.
The equity is a low beta, regulated utility holding that contributes a small and stable share to the parent earnings. The bear case is the FERC ruling cutting against the company and the council reducing the formula increase, which together would shrink the subsidiary dividend by a meaningful amount. The bull case is the rehearing producing a net receivable and the council allowing the full increase, which would expand the dividend and support a higher multiple. The base case is somewhere in between, and it is the case that the current parent multiple is most likely pricing. The decision to hold or avoid the parent equity turns on whether the investor believes the FERC rehearing cuts against the company or in its favor, and that is a question that the filings leave open. The investment decision for the parent equity is not driven by the New Orleans subsidiary, but the subsidiary is a visible and quantifiable component of the group, and the FERC ruling is the single most important variable to watch in the next two quarters.