Conferencia de resultados del 3T 2026 de Southwest Gas Holdings (SWX): previsiones reafirmadas

Puntos clave

• Southwest Gas Holdings (NYSE: SWX) registró en el tercer trimestre de 2026 un BPA ajustado de las operaciones continuadas de 0,20 dólares, frente a los 0,06 dólares del tercer trimestre de 2025.
• El BPA ajustado en lo que va de año alcanzó los 2,69 dólares, lo que supone un aumento del 18% con respecto al mismo periodo del año anterior. La dirección atribuyó esta mejora principalmente a resoluciones regulatorias constructivas y a la disciplina de costes.
• La empresa reafirmó su previsión de BPA ajustado para 2026 de 4,17 a 4,32 dólares y su objetivo de crecimiento del BPA ajustado a largo plazo del 12% al 14%.
• Las resoluciones tarifarias de California y Nevada autorizaron unos ingresos anuales incrementales combinados de aproximadamente 80 millones de dólares. El personal de la comisión de Arizona recomendó entre 53 y 58 millones de dólares, frente a la solicitud actualizada de SWX de 91,3 millones de dólares.
• La ampliación para 2028 de Great Basin, con una inversión de 2.300 millones de dólares, cuenta con 1 Bcf diario de demanda contratada y la dirección prevé que genere entre 270 y 300 millones de dólares de margen anual incremental tras su entrada en servicio en el cuarto trimestre de 2028.
• SWX finalizó el trimestre con cerca de 700 millones de dólares de liquidez disponible y aproximadamente 3.700 millones de dólares de deuda neta consolidada, tras tener en cuenta los saldos del ajuste por compra de gas pagaderos a los clientes.

Datos financieros clave

Rendimiento comercial y operativo

Southwest Gas se benefició de la actualización de las tarifas en California, el crecimiento constante de clientes y el mecanismo de integridad del sistema de Arizona. Estas mejoras se vieron compensadas en parte por un menor margen facturado a los clientes sin desacoplamiento en Arizona y Nevada, así como por un menor margen asociado al mecanismo VIER de Nevada.

Los gastos de operación y mantenimiento en lo que va de año se mantuvieron relativamente estables. La dirección sigue teniendo como objetivo mantener estables los gastos de O&M por cliente de la utility a lo largo del plan a cinco años.

El proceso tarifario resuelto en California autorizó algo más de 32 millones de dólares de ingresos anuales incrementales, una rentabilidad sobre el capital propio del 10% y una ratio de capital del 50%. Las tarifas entran en vigor con carácter retroactivo al 1 de enero de 2026.

Nevada autorizó cerca de 48 millones de dólares de ingresos anuales incrementales, mantuvo el ROE permitido en el 9,5% y aprobó una ratio de capital real del 51,35%. Las tarifas entraron en vigor en octubre de 2026. SWX ha solicitado la reconsideración de ciertas instalaciones posteriores al año de prueba excluidas de la base tarifaria.

En Arizona, el personal de la comisión recomendó entre 53 y 58 millones de dólares de ingresos anuales incrementales y un ROE del 9,75%. SWX redujo su solicitud de 101 millones a 91,3 millones de dólares tras actualizar las estimaciones de instalaciones posteriores al año de prueba, los supuestos de capital circulante y otras partidas. Las audiencias están programadas para comenzar el 7 de diciembre y la dirección prevé que las tarifas entren en vigor el 1 de abril de 2027.

Ampliación de Great Basin

Great Basin sigue en camino de presentar su solicitud de certificado ante la FERC antes de finales de año. Los cargadores han firmado acuerdos de precedencia vinculantes y han aportado garantías que respaldan 1 Bcf diario de demanda contratada. Tras la aprobación de la FERC, deberán suscribir contratos de transporte con plazos mínimos de 20 años.

La dirección calcula que el proyecto requerirá una inversión de 2.300 millones de dólares y generará entre 270 y 300 millones de dólares de margen anual incremental a partir de su fecha prevista de entrada en servicio en el cuarto trimestre de 2028. Aproximadamente 600 millones de dólares de la estimación actual del proyecto —y su margen asociado— no están incluidos en las previsiones vigentes a largo plazo.

El gasto previsto del proyecto se distribuye aproximadamente en un 15% para 2026, un 25% para 2027 y un 60% para 2028. SWX espera una decisión sobre su solicitud de certificado de conveniencia y necesidad pública a finales de 2027. La compañía ha asegurado ciertos pedidos de compra con proveedores, pero aún no ha seleccionado un contratista de ingeniería, aprovisionamiento y construcción (EPC).

Previsiones de la dirección

La dirección reafirmó su previsión de gasto de capital para 2026 y las métricas financieras a largo plazo existentes. La empresa prevé incorporar la estimación completa de 2.300 millones de dólares de Great Basin en sus hipótesis actualizadas a cinco años sobre capital, financiación, base tarifaria y beneficios en febrero.

SWX no espera emitir acciones durante lo que resta de 2026. Planea mantener 340 millones de dólares de capacidad en su programa at-the-market, pero indicó que la renovación del programa no modifica su expectativa de requerir solo un volumen moderado de capital externo durante el periodo de planificación actual.

Riesgos y aspectos a vigilar

• Arizona sigue siendo el principal proceso tarifario pendiente de resolución. El incremento final de ingresos, el ROE autorizado y la estructura de tarifas por fórmula están sujetos a la aprobación de la comisión.
• El personal de la comisión de Arizona propuso una banda muerta de 50 puntos básicos para las tarifas por fórmula, frente a la banda de 20 puntos básicos planteada por SWX. Aun así, la dirección considera que la banda más amplia supone una mejora respecto al modelo histórico de año de prueba.
• Las normas alternativas de fijación de tarifas de Nevada continúan en fase de desarrollo. La dirección prevé contar con las normas definitivas a finales de año y tiene como objetivo presentar una solicitud a principios del segundo trimestre de 2027, con posibles efectos en las tarifas hacia mediados de 2028.
• La ampliación de Great Basin sigue sujeta a las autorizaciones de la FERC y a escala estatal, a la ejecución de las obras, al calendario de costes del proyecto y a la selección de un contratista de EPC.
• La devolución a los clientes de los saldos del ajuste por compra de gas de Nevada ha sido más lenta de lo previsto por la dirección debido a las condiciones meteorológicas y a las tarifas volumétricas.
• La dirección calificó el ajuste de regularización de la depreciación de activos regulatorios como de naturaleza principalmente no recurrente.

Puntos destacados de la sesión de preguntas y respuestas con analistas

La dirección afirmó que no se espera que los cambios derivados de las elecciones en Arizona y Nevada alteren de manera sustancial los procedimientos regulatorios en curso. En Arizona, los tres comisionados que continúan han mostrado coherencia recientemente, mientras que las posturas de los dos comisionados entrantes se irán aclarando en futuras votaciones.

De cara a 2027, California y Nevada ofrecen una visibilidad más clara sobre la mejora del margen regulatorio. Nevada debería aportar a ritmo anualizado completo en 2027, mientras que Arizona aportaría una contribución parcial durante el año si las tarifas entran en vigor el 1 de abril de 2027. El efecto anualizado completo de Arizona se reflejaría en 2028.

En relación con FAST-41, la dirección describió el proceso como una herramienta para la coordinación de permisos, la transparencia y la previsibilidad del cronograma, más que como una garantía de una aprobación más rápida.

La dirección señaló que el rango previsto para el margen de Great Basin depende en parte de los costes finales de construcción, el calendario del gasto de capital y la capitalización de AFUDC. Unos costes de construcción más bajos podrían situar el margen hacia la parte inferior del rango, mientras que el calendario de gasto y una mayor capitalización de AFUDC podrían influir en el extremo superior.

Transcripción completa de la conferencia de resultados

Transcripción completa de la conferencia de resultados

Comentarios de la dirección

Operator

Welcome to Southwest Gas Holdings' Third Quarter 2026 Earnings Conference Call. Today's call is being recorded and our webcast is live. A replay will be available later today and for the next 12 months on the Southwest Gas Holdings' website. [Operator Instructions].

I will now turn the call over to [ Mr. Will Batista ], Director of Investor Relations, Sustainability and Stakeholder Engagement. Please go ahead.

Unknown Executive

Thanks, Kelsey, and good morning, everyone. We appreciate you joining the call this morning. This morning, we issued and posted to Southwest Gas Holdings' website, our third quarter 2026 Earnings release and filed the associated Form 10-Q. The slides accompanying today's call are also available on Southwest Gas Holdings website. We'll refer to those slides by number throughout the call today.

Please note that on today's call, we will address certain factors that may impact 2026 earnings and discuss longer-term guidance. Information that will be discussed today contains forward-looking statements. These statements are based on management's assumptions on what the future holds but are subject to several risks and uncertainties, including uncertainties surrounding the impact of future economic conditions, regulatory approvals and capital projects. This cautionary note and a note regarding non-GAAP measures are included on Slides 2 and 3 of this presentation, in today's press release and in our filings with the Securities and Exchange Commission.

We encourage you to review each of these disclosures. These risks and uncertainties may cause actual results to differ materially from statements made today. We caution against placing undue reliance on any forward-looking statements, and we assume no obligation to update any such statements. As shown on Slide 4, on today's call, we have Justin Brown, President and CEO; and Justin Forsberg, Chief Financial Officer and Treasurer. Other members of the management team are also available to answer your questions during the Q&A portion of the call today, if necessary.

I will now turn the call over to Justin Brown.

Justin Brown

Thanks, Will. Good morning, everyone, and thank you for joining us today. Beginning on Slide 5, we delivered strong third quarter and year-to-date results while continuing to execute on our regulatory and growth priorities. Reported adjusted earnings per share from continuing operations of $0.20 compared with $0.06 in the third quarter of 2025, and year-to-date adjusted earnings per share from continuing operations of $2.69, which is up 18% from the same period last year. The improvement was primarily driven by constructive regulatory outcomes and disciplined cost management as we remain focused on delivering on our 2026 strategic priorities and key initiatives. Based on our current expectations, we are reaffirming our 2026 adjusted EPS guidance of $4.17 to $4.32 per share and our 12% to 14% long-term adjusted EPS growth target.

In Arizona and Nevada, we are working to better align cost recovery with the pace of our investments, which benefits customers and investors alike. Importantly, our plan does not depend on any single outcome as we have multiple credible paths to our objectives regardless of how individual cases may unfold. We remain focused on delivering near-term performance and long-term value that starts with safe, reliable and affordable natural gas service for our customers and extends to supporting economic development across the communities we serve, all backed by disciplined capital investment and cost management.

Turning to Slide 6. We continue to execute on our 2026 strategic priorities and remain on track to deliver on each of our key initiatives. We received final orders in both our California and Nevada rate cases, which together authorized approximately $80 million of incremental annual revenue. In Arizona, staff testimony was constructive, and I will cover it in more detail shortly. At Great Basin, we submitted our FAST 41 draft application for the 2028 expansion project, and we remain on track for the FERC certificate application by year-end and a targeted fourth quarter 2028 in-service date.

On Slide 7, at the utility, we delivered a 12-month ended return on equity of 8% and third quarter O&M expense remained relatively flat on a per customer basis, consistent with our disciplined cost management efforts across the company. We ended the quarter with nearly $700 million of available liquidity after having invested more than $800 million of capital at Southwest Gas at Great Basin so far this year. We delivered these results before realizing the full benefits of our recent regulatory outcomes in Nevada and while Arizona remains pending, underscoring the strength of our underlying business.

With new California and Nevada rates now in effect, and as we work with the parties in the Arizona Commission to bring our case to a close, we expect the associated rate relief to further improve our results as we move into 2027. We continue to see constructive outcomes as we move through our general rate case cycle in California, the final decision on cost of capital was received in August, and this completed our general rate case. The final decision authorized just over $32 million of incremental revenue, a 10% return on equity and a 50% equity ratio with rates effective back to January 1, 2026. A summary of the outcome is shown in the appendix on Slide 26.

Turning to Slide 9. In Nevada, we received a final order on October 14, authorizing nearly $48 million of incremental annual revenue, maintaining our authorized return on equity of 9.5% and an actual equity ratio of 51.35%, up from the 50% in our prior case with rates effective October of 2026. This outcome exceeds the roughly $40 million and 9.3% proposed by the other parties. While we were pleased with several elements of the outcome, we filed for reconsideration of certain post-test year plan that we believe should have been included in rate base and not deferred to a future rate proceeding. If successful, this request could further improve the overall revenue outcome in Nevada.

We also expect the commission to finalize its rules around surrounding alternative ratemaking by the end of 2026 and anticipate making a filing to implement alternative rates by early second quarter 2027. In Arizona, we received intervener testimony and notably, the commission staff recommends $53 million to $58 million of incremental annual revenue, depending on the treatment of the fair value increment, and a 9.75% return on equity. Staff also supports post test-year plant subject to in-service verification and most notably, our proposal to transition to formula rates with some modifications.

Our rebuttal testimony was filed November 2, and we updated our request to $91.3 million in annual revenue to reflect updated post-test year plant estimates and cash working capital assumptions as well as other minor adjustments and corrections to our original filing of $101 million. Additional testimony is due by the end of November, and the hearing is scheduled to begin December 7, with anticipated rates becoming effective April 1, 2027. Our formula rate proposal would provide an annual rate adjustment beginning 1 year after new base rates take effect with a 20 basis point dead band above and below the authorized return on equity and would replace several existing mechanisms. Staff supports the mechanism with some modifications to the dead band, proposing a 50 basis point dead band, and proposing some adjustments to our proposed timeline for the first filing, as well as recommending the lower end of their ROE range, while RUCO just opposes it in its entirety. And we address each of these positions in our rebuttal testimony.

Collectively, these proceedings strengthen earnings visibility, support timely recovery of prudent investment and advances our focus on reducing regulatory lag while providing rate stability for our customers. Across all 3 states, the strategy is the same: Pursue timely, constructive outcomes that align cost recovery with the pace of our investment.

Turning to Slide 11. We continue to advance our Great Basin 2028 expansion project and preparation of our FERC certificate application remains on track for filing by year-end. Recent progress includes filing key draft resource reports submitting our draft FAST 41 application, conducting field surveys and public outreach and advancing engineering and design work. Shippers have executed binding precedent agreements and posted surety supporting 1 Bcf per day of contracted demand and upon FERC approval of the certificate, they are required to execute transportation service agreements with a minimum term of 20 years.

Based on that contracted demand, we expect the project's estimated $2.3 billion investment to generate approximately $270 million to $300 million of incremental annual margin beginning at the expected fourth quarter 2028 in-service date. Because this is a cost of service project, the 1 Bcf per day already under contract is expected to fully support that margin estimate. As a reminder, $600 million of the $2.3 billion estimate along with the associated incremental margin is not reflected in our long-term guidance. We don't expect the updated estimate to materially affect our 2026 capital expenditure guidance, and we will update long-term guidance with our annual 5-year plan in February.

Importantly, the current 48-inch pipe design will serve the contracted 1 Bcf per day and can accommodate greater throughput with relatively modest additional investment depending on shipper specifications. As such, additional demand served within that current design capacity is expected to lower the rate for all shippers subscribed to the 2028 expansion project. Capital spending is expected to be approximately 15% in 2026, 25% in 2027 and 60% in 2028, as shown on the slide. We anticipate a decision on our CPCN filing in late 2027 and AFUDC is expected to be capitalized into project costs and contribute to future invested capital upon placement into service. We remain focused on executing the project safely, efficiently and in a manner that supports long-term value creation.

I will now turn the call over to Jay Fors to discuss our financial performance, expected financing plans and our guidance outlook in greater detail.

Justin Forsberg

Thank you, Justin. Turning to the EPS walk on Slide 13. The quarter-over-quarter improvement at Southwest Gas was operationally driven by improved rates as well as customer growth. Lower interest expense at the holding company also contributed to the increase. While the third quarter tends to be our lowest earnings period, the earnings growth continues to support the benefits of our simplified fully regulated natural gas business model as well as our disciplined focus on cost management, regulatory improvement and purposeful capital allocation.

On Slide 14, you'll see the key drivers of the quarter-over-quarter change in Southwest Gas's adjusted net income, comparing the third quarter of 2026 to the same period in 2025. Operating margin increased $3.8 million, driven primarily by updated rates in California as well as customer growth, which remains steady across our service territories despite a prolonged higher interest rate environment. We also saw the margin benefits from the Arizona System Integrity mechanism capital tracker. These and the other increases in recovery, return on regulatory account balances were partially offset by lower billed margin across Arizona and Nevada attributable to non-decoupled customers, as well as lower margin related to the Nevada VIER mechanism, the impact of which is offset in net interest deductions.

Our team continues to deliver disciplined cost management. Year-to-date, O&M is relatively flat, and we expect our continued focus on operational efficiency to help us achieve our goal of maintaining flat O&M expense per customer at the utility over our 5-year plan. Depreciation and amortization increased by a net $1.8 million. The increase mostly reflects a 7% increase in gas plant and service compared to the third quarter of 2025. Partially offsetting the higher depreciation expense was an adjustment related to certain regulatory assets to more closely align the return on those assets with the time period over which those costs have been deferred. The increase in plant and service is consistent with our disciplined infrastructure investment strategy focused on safety, reliability and customer growth.

Lower net interest deductions primarily related to lower amounts incurred on over collected PGA balances for Nevada, as well as recoveries associated with the Nevada VIER mechanism I mentioned earlier, offset in margin, also benefited results by $4.9 million. Although other income was flat, lower non-service pension-related income and lower interest income were nearly fully offset by higher COLI gains and an increase in AFUDC equity, driven mostly by capital investment in Great Basin's 2028 expansion project. Finally, even though adjusted earnings were higher, we had a net income tax benefit driven mostly by the lower deferred state income taxes. Overall, we remain confident that we are on track to achieve our full year outlook.

Turning to Slide 15. I'll discuss our financing plans. We are in a strong financial position utilizing strategically sourced liquidity to support future growth. We have yet to issue any equity outside of our Dividend Reinvestment Plan so far in 2026, and we continue to anticipate no equity issuances for the remainder of this year. We currently plan issuing debt at the utility this year, which we anticipate sizing as needed to support liquidity and capital allocation priorities. Our strong liquidity across the company provides us with flexibility to optimize external financing sources across the enterprise as we navigate a relatively volatile interest rate market.

Additionally, we have wide flexibility in terms of tenure as we monitor borrowing costs across the yield curve and evaluate laddering maturities against our current debt maturity profile. Recall that our 5-year plan includes a mix of leverage capacity at the holding company, utility bond issuances and modest ATM usage to finance our growing $6.3 billion capital plan, and we intend to optimize the lowest cost source of funds when prudent. Later this month, when we extend the shelf registration, you'll see us update and extend our existing at-the-market equity program while retaining its capacity at $340 million.

Maintaining ATM capacity remains a prudent financing tool and should not be interpreted as a change in our current financing expectations. We continue to only expect modest external equity needs to fund our capital plan, and we do not anticipate needing to draw meaningfully on the ATM through the end of our current planning horizon. Our highly flexible and well-capitalized balance sheet positions us well to fund future growth. Over the long term, we continue to believe we have sufficient leverage capacity at the holding company to absorb much of the anticipated equity needs of the utility that are driven by our capital plan. Supported by a meaningful cushion above our current downgrade thresholds, we retain considerable flexibility in how we finance investment while preserving our financial strength.

Briefly on Slide 16, at the end of the third quarter, consolidated net debt was approximately $3.7 billion when considering the purchase gas adjustment balances that are payable to customers. We maintained investment-grade ratings with stable outlooks across the enterprise. We continue to target consolidated S&P FFO to debt above 17% over time, as the significant margin growth from the investments we are making are expected to support even further strengthening of the balance sheet as well as potential capital reinvestment opportunities.

Finally, on Slide 17, based on current visibility, we are reaffirming our 2026 adjusted EPS guidance expectations to center around the midpoint of the range of $4.17 to $4.32. In addition, we are reaffirming 2026 capital expenditures and our long-term guidance metrics and drivers. As noted, those long-term metrics reflect $1.7 billion of Great Basin capital through 2030 and do not yet incorporate the updated $2.3 billion project estimate. We intend to include the full estimate when we roll forward our 5-year capital financing, rate base and earnings assumptions this coming February.

The successful execution of our current 5-year capital program would nearly double our system-wide rate base from today by the end of 2030. Taken together, we believe our year-to-date results, on track plan execution and the continued commercial interest in Great Basin's expansion opportunities reinforce the durability of our plan. We remain confident in our ability to deliver on our long-term financial objectives of receiving timely recovery of investments, improving earned returns and preserving balance sheet strength. The progress we have made this year reinforces our confidence in achieving our long-term objectives regardless of the timing of individual regulatory outcomes. We remain committed to prudent capital allocation and to supporting long-term value creation for stockholders.

With that, let's open the line for your questions.

Operator

[Operator Instructions] Your first question comes from Constantine from Wells Fargo.

Preguntas y respuestas

Constantine Lednev

Maybe just starting off on the Arizona ACC turnover. Do you see any impacts to the current litigated process? And would it be feasible still to get at least a partial settlement on the more straightforward elements, specifically as we look at the formula rates backdrop?

Justin Brown

Yes, Constantine, it's Justin. I think it's a good question. Obviously, the election was yesterday. I don't think they've called it, but things directionally appear to be the turnover, like you mentioned. I don't see how that would have any impact on the litigation itself that you referenced. And then I think the commission turnover, again, I think the consistent thing there is the staff and our working relationship with the staff. And so I think our prospects around settlement or working with the staff and the parties is the same regardless of elections and different things.

I mean that's the one consistent that we do know about Arizona is, they do have elections every 2 years, and we manage our business accordingly in a very measured way, and focus on our working relationship with the underlying parties like the staff and the consumer advocate.

Constantine Lednev

Excellent. Understood. And maybe shifting to the overall progress on the regulatory matters year-to-date. How are you thinking about the kind of gross margin drivers in the context of '27? California and Nevada are kind of known. Arizona is progressing? And any way to frame kind of the net ROE lag with the new rates? Anything structural kind of that you would call out that still remains?

Justin Forsberg

This is Justin Forsberg, Constantine. Thanks for the question. I think when we think about margin, obviously, we have California, Nevada behind us, and so we kind of have -- we have line of sight or clarity for the impact on 2027 in those states. Especially when you think about Nevada, just as a reminder, we plan on filing for formula rates, which will not necessarily impact 2027. It's more of a further out impact on that potential adjustment. And then I think the risk that's left is really Arizona, as we talked about just a second ago, right, we were expecting if we have a hearing in December, we're expecting a final decision sometime early next year with rates effective in our plan by April. So I think from that perspective, that's kind of how we think about margin improvements on the regulatory side for next year.

Constantine Lednev

Okay. And then just to clarify with the timing between Nevada and Arizona, those would kind of roll in '27, '28, kind of towards the full kind of margin contribution from the improvement, right?

Justin Forsberg

Yes. As far as the margin contribution, full run rate, yes, you're exactly right. Like Nevada run rate would be '27. Arizona would be a partial year, '28, and full or '27, full run rate '28, with formula rate or alternative ratemaking adjustments currently expected mid-28.

Operator

And your next question comes from Elias Jossen from JPMorgan.

Elias Jossen

Maybe sticking with Nevada, obviously we saw the governor seat flip, so just wanted to get a sense of where you guys are in the rulemaking process and how to think about, if there are any implications to consider in the state there more broadly?

Justin Brown

Eli, it's Justin Brown. We are still working through the regulations at the PUCN, and so they had issued draft regulations in May. They received feedback and comments on those. We anticipate them issuing a new draft and hopefully voting on it by year end. We don't see the governor’s race really impacting that process. We would anticipate -- that's the timeline we’re still thinking about in terms of moving forward with respect to those regulations. And as J-Ford just mentioned, the timing around how we’re thinking about a formula rate or an alternative rate-making proposal in Nevada and when that would show up in rates. We’re still targeting middle of 2028.

Elias Jossen

I know you said the ACC race isn't called, but I guess if outcomes were to hold, and the commission is clearly moving towards Democratic base, and if we think about the timeline into next April for rate finalization, what are the kind of key items for us to monitor in next year? If there’s any historical precedent for this kind of timeline with the commission. I know, again, you still have a majority of Republicans, but just at a high level, thinking about the timeline into next year?

Justin Brown

That's a good question, Eli. I think given kind of recent voting record among the existing 5, and really the 3 commissioners that are staying, I would just look for kind of continued consistency in terms of their approach on these different filings. I think you've seen that they've kind of coalesced around approach this year, and it seems like those three have been fairly consistent, and I would look for that consistency to continue into the year. I mean, obviously, when you have 2 new commissioners, we'll see kind of where they end up voting on different matters that come before them. So time will tell on that as cases come up, and we start to see kind of their votes and the rationale for their votes.

But I think the key is looking for the consistency with the 3 that are currently seated, and then just as we move into 2027, we'll be evaluating kind of directionally where the 2 new commissioners, kind of what their perspectives are, what their rationale is, and kind of where they start to place their votes.

Operator

Your next question comes from James Ward from Jefferies.

Jamieson Ward

The D&A true-up and the state tax benefit added about $0.12 this quarter. Were those in your plan when you set guidance, and if not, what's offsetting them?

Justin Forsberg

Yeah, it's a good question. I think when we sort of rewind, we do have in our plans, included in our plans, potential items when we think about it, as we do our sort of prompt year numbers. I think I'd have to really think through the magnitude of some of these opportunities that showed up. While that might be a little bit different than what we had in our plan, we do tend to, when we put our plans, we have opportunities that are in front of us that we could look at.

In terms of sort of your question on offsetting, I think we don't necessarily think that there's anything significant going the other direction. I guess other than the PGA is probably returning back to customers a little slower than what we would have anticipated, just simply given weather conditions and volumetric rates. And, so the reduction of our PGA has been a little bit slower, especially in Nevada. So that's probably something that would have been offsetting it the other direction.

Jamieson Ward

In Arizona, if the commission adopts the formula rate at the low end of staff's range, how much would you still expect to see an improvement versus authorized, pardon me, versus the actual earned returns in recent years and -- separate, but related to that, could you live with a 50 basis point dead band like [Indiscernible]?

Justin Brown

Yeah, James. I mean, I think we've talked about the dead band in the past. I mean, the policy statement provides for, I think, 20. I think the commissions and the staff's been pretty consistent on their votes around a 50. I think that's still, from our perspective, an improvement over kind of the current historical model, historical test year model, and regulatory lag that exists. So we definitely still think there's improvement there, and regarding that possible outcome, and we'll see how it goes on a go-forward basis.

Obviously, we're proposing the 20 basis point band, and then obviously, that there's circles around whatever ROE you end up getting. Whether you're authorized to, our current 984 and you have the dead band, or if they adjust the ROE to something else, that's just part of the process. No different than any rate case where they set an ROE and authorized ROE, and you're trying to manage your business to get as close to that authorized level as you can.

Operator

And your next question comes from Gabriel Moreen from Mizuho.

Gabriel Moreen

Maybe if I can ask a couple of Great Basin questions. Can you talk about the FAST 41 application and what that may or may not do for the process in terms of either accelerating it, smoothing it out. And then in terms of that 1.8 Bcf of additional customer interest, can you just talk about where you are, you think, in terms of getting some of that interest across the finish line? And I'm curious also of that 1.8 Bcf a day to what extent that's data centers or other interests like industrial or power gen, not data center related?

Justin Brown

Yes, Gabe, it's Justin. On the FAST 41 application, I would think of that as more of like a kind of a transparency and a coordination opportunity. It's a voluntary program where we'll make an application filing. We've submitted a draft application, we'll get feedback. But really, what it does is it doesn't necessarily guarantee things to be faster or it's the same review requirement. It's just more of a coordination among the different permitting agencies. And so it provides greater transparency regarding how that process will go and so greater predictability in terms of the schedule.

And so that's how we're thinking about it. Granted, there could be some efficiency improvements as a result of the coordination, but that's not a guarantee. And then with respect to the additional demand, again, that's something right now, we're really focused on the 2028 expansion and the shippers that have signed up there, and we're continuing to work with those that are looking at capacity beyond that. And we'll continue to that. We continue to receive inbound calls to this day where we get additional inquiries.

I think over time, that will settle in where once we start the process in terms of the FERC filing, maybe even construction around '28, we'll probably get greater clarity around those shippers and kind of what their anticipated time lines are, and then we'll try to call less around a date and look for an announcement sometime in the future regarding kind of what that looks like, what shippers are willing to commit to buy any precedent agreements with surety similar to what we did this last 1.5 years.

Gabriel Moreen

And I know you responded earlier to you asked questions on the Nevada governor election as it pertains to, I think, forward rates. Can you talk about it within the context of Great Basin? I don't know to what extent it matters for land acquisition rights away or stuff like that. But maybe can you just -- I know it's early days, but can you speak to that, too?

Justin Brown

Yes. I think it's early. It's something we'll obviously keep an eye on. I think when we think about the 2028 expansion, I think a lot of those things are already in motion. And I think given the local of where the shippers primarily are located. I think some of them have already received some of their permits from different state agencies. So I don't really anticipate any change in trajectory around the '28. Obviously, time will tell around the '29 to '35. And those shippers and kind of their appetite for continuing with their projects and things like that. So that's something we'll keep a close eye on as we work with them to firm up their interest.

Operator

Your next question comes from Chris Ellinghaus from Siebert Williams Shank.

Christopher Ellinghaus

J-Ford, I heard what you said about the ATM, but could you just repeat sort of what you were saying about equity following that?

Justin Brown

Yes. So I was just talking about this housekeeping that will renew the ATM when we renew extend the shelf here in a few weeks. And just wanted to help people understand keeping the size of it the same as expected at $340 million, and our expectations for equity need for equity externally haven't changed. Just trying to help people understand that it's just a housekeeping item. So essentially still when you go back to what we've said previously, still expect relatively modest equity issuances externally of the ATM during the construction timeframe of a Great Basin primarily.

Christopher Ellinghaus

Okay. Great. As far as the Great Basin margin range goes, can you give us some sense of what you're thinking the variables are within the range?

Justin Brown

Yes. I think there's a couple of things the way we think about it. Remember that it is a cost of service project, and so the margin really depending on assuming that you don't have significant change in the construction cost. Margins should be relatively similar supported by everyone who signed up today is what we're thinking about the range, we do in our construction. Estimates, we do assume some contingencies in the CapEx numbers. And so that is something that could bring the range, say, a little bit lower if costs end up coming in a little bit lower than what we've estimated in our estimates.

I think when you think about what could raise it much higher, I think it kind of depends on the timing and spending of capital, which would impact your AFUDC numbers, which would then obviously change the total cost of the project as far as rate base goes once you ultimately capitalize that interest and equity from AFUDC could have an impact on the margin. So those are kind of how we think about the range...

Justin Forsberg

Like bottom and top.

Christopher Ellinghaus

So actual spending timing would be an important factor as well.

Justin Forsberg

Yes.

Christopher Ellinghaus

The elections, I guess people have been trying to ask questions around this in various ways. But rather than thinking about the individual personnel or governors or whatever, but just the general swing how -- what happened last night. Do you think that leads to any kind of policy direction that might have any implications at all?

Justin Brown

Chris, it's Justin Brown. It's a really good question. I think when we look at our 3 states and based on the changes. I mean, obviously, time will tell, but I don't think there's anything that jumps out to us as a big risk in terms of big swings and policy changes that would affect our day-to-day business.

Operator

Your next question comes from Paul Fremont from Ladenburg.

Paul Fremont

I guess my first question is on the depreciation adjustments to the regulatory assets. Has that spread over a number of states? Is it all in one state? Where would that be?

Justin Brown

You can assume it's across our jurisdictions, just really working to line it up with the timing of -- when that -- the intent of those regulatory accounts are deferred -- the costs are deferred over.

Paul Fremont

And then I guess I would assume that in your next rate filings in, I guess, it would be all 3 jurisdictions that, that would sort of be a pass-through back to customers? Or was there an immediate sort of adjustment to revenue when you adopted the depreciation change?

Justin Forsberg

Yes. I would say it's -- you should probably think of it more as nonrecurring because we're -- essentially, as we align that with the timing of that -- of our allowed deferral. We're essentially -- it's something that you might have waited until you had a rate case outcome in the past to make a true-up adjustment on your finalization. But a higher level way to think about it, Paul, is when you have to make an assessment in the accounting world as to how -- do you believe that you're going to be able to recover the return on those assets that you were allowed to book by the regulators, right?

So from our perspective, the regulators, as we went through and assessed all of our regulatory assets in this case, we believe that we're going to get recovery from the regulators on the returns that they've already allowed us to book on certain regulatory accounts. And so that's just the true up.

Paul Fremont

And since you've already had 2 rate outcomes in Nevada and California, we would assume that it may be some period of time before you file again in those jurisdictions?

Justin Brown

Yes, Paul, it's Justin Brown. Yes, I think a lot of it will probably hinge. Like on California, we have a 5-year rate cycle. And so we are on a 5-year rate cycle absent something unique happening. And so I think you can look at it from that perspective on California. On Nevada, I think largely, it will depend on the timing of the commission issuing the regulations on the alternative rate making. If that happens, we anticipate it happening within sufficient time, but I think we have up to 6 months after our rate case decision to make a filing under those regulations per the legislation. So as long as the regulations are done and we meet that window, we would look to move to more of an alternative rate making model. And as we mentioned, looking make a filing in '27 for rates effective in '28.

If for some reason, that timing doesn't work, then we would look at probably filing another rate case at some point and around that same time line just to kind of stay current with our rates and then at that point in time, transition to an alternative rate. So a lot of it will just depend on the timing of the regulations in Nevada. And I think it's probably fair to look at Arizona the same way. Obviously, we'll get a final decision in the first -- around April of next year, and then we'll evaluate, one, whether we get approval of a formula rate proposal, but then kind of the transition timing and how we think about our rate case. Historically, in Nevada, we've been anywhere from 18 to 24 months from rate case to rate case.

In Arizona, we're kind of on a similar time line of depending on -- if you're looking at from when you file to file, it's been about 2 to 3 years, and then in Nevada, it's been like 1.5 years to 2 years. And so we usually try to keep rates as fresh as possible by making frequent filings.

Paul Fremont

And then -- given the fact that the 2 commissioners are going to be seated very late in your rate case process, I mean, is there a possibility of a delay in the schedule so that they are able to get sort of up to speed on the issues? Or would you expect the schedule to hold exactly as it is?

Justin Forsberg

Yes, it's a good question. I think if our schedule provided for a draft decision in January for a vote, I think there might be a greater risk. I think looking back over history, sometimes you would see things get moved from January to February to your point. Interestingly enough, in our last rate case, a couple of years ago or maybe 2 rate cases ago, during an election, we had a vote on our rate case in January. Since our schedule is really not January schedule, it's more of a March, April time line. I think that, that probably lessens any likelihood that there would be a delay because the new commissioners would be in their seats for a couple of months.

I think generally speaking, they're kind of expected to be ready to take on their roles and responsibilities when they're seated in January. I think if there is a minor delay, it would be anything that would come up for vote in January that might get pushed to February, but I really don't expect a trickle-down effect beyond that. At least we've never seen it historically.

Paul Fremont

Last question for me, since the 2 commissioners on the Republican side who lost played a major role in the establishment of the formula rate filings that were approved by the commission. Do you see any potential changes that might come about given the fact that they're no longer -- that they won't be any longer on the commission?

Justin Brown

Yes, Paul, I think that's a fair question. I mean, Nick and Kevin were both strong advocates. I would say, though, that they've been very effective just culturally. I mean, you can see where the commission staff has been supportive. I think the other 3 commissioners that are still there have been supportive. We touched on that earlier in terms of them coalescing around kind of different outcomes. And we'll see where whoever ends up getting seated, we'll see kind of where their perspective is on these issues.

I think in Arizona, you always have that kind of situation where -- when you have elections, you have changes. And I think you see things kind of evolve back and forth on different policy objectives. And over time, we'll see how that goes. Clearly, the -- on the formula rate issue, there's 3 commissioners that will still be there, that will have a majority next year around kind of these proposals, and they seem to have been supportive at least most recently. So time will tell. But I think from our perspective, again, we don't anticipate major swings in policy just given the current makeup and where people have been voting more recently.

Operator

Your last question comes from Ryan Levine from Citi.

Ryan Levine

Wanted to touch on Great Basin. It looks like some of the CapEx was moved slightly to be more back-end weighted from your guidance last quarter. Any color as to what drove the change and any impact to timeline?

Justin Forsberg

This is Justin Forsberg, Ryan. Yes, I think there's probably not a lot to read in there. I think when we -- as we go along and continue to refine some of the estimates, as you think about -- at this point in time, we have really mitigated the risk that might have been out there from a supply chain perspective in terms of pipe as well as the compression side of things. And so we have a lot more clarity around the timing of when we might roll pipe and take delivery on those kind of things. And then I think when we think about the construction timeline and try to align expected construction spending with what we're expecting to an EPC contractor to do. It's just some modest refinement, not anything major changing there.

Ryan Levine

And then Justin, just a follow-up on that in terms of the -- that answer, you suggested that you have more confidence around the supply chain contracts. Is there anything to note around agreements that were assigned or what portion of that cost that's now been secured over the last few months?

Justin Forsberg

No. I think we really secured or signed POs, if you will, a little bit earlier this year or over the summer, et cetera. And I think we are -- there's not a lot has changed there. We feel pretty confident on where we stand with suppliers. As you probably know, it's just important to add that we don't yet have an EPC contractor for the construction phase. We have had early meetings, like an early contractor meeting as far as education Q&A sessions with them, but we have not finished or completed an RFP there for the EPC side.

Operator

There are no further questions at this time. Mr. Batista, you may proceed your conference.

Unknown Executive

Thanks again, Kelsey, and thank you all for joining us today and for your questions. This concludes our conference call. We appreciate your interest in Southwest Gas Holdings and look forward to speaking with many of you soon.

Operator

Ladies and gentlemen, this does conclude your conference call for today. We thank you very much for your participation, and you may now disconnect. Have a great day, everyone.