사우스웨스트 가스 홀딩스(SWX) 2026년 3분기 실적 발표 콘퍼런스콜: 가이던스 재확인

핵심 요약

• 사우스웨스트 가스 홀딩스(NYSE: SWX)는 2026년 3분기 계속영업 조정 주당순이익(EPS)이 0.20달러를 기록해 2025년 3분기의 0.06달러에서 증가했다고 발표했다.
• 연간 누적(YTD) 조정 EPS는 전년 동기 대비 18% 증가한 2.69달러에 달했다. 경영진은 이러한 실적 개선의 주요 요인으로 우호적인 규제 결과와 비용 절감 노력을 꼽았다.
• 회사는 2026년 조정 EPS 가이던스로 4.17~4.32달러를, 장기 조정 EPS 성장률 목표치로 12%~14%를 재확인했다.
• 캘리포니아주와 네바다주의 요금 인가 결정으로 연간 총 약 8,000만 달러의 추가 수익이 승인되었다. 애리조나주 규제위원회 실무진은 SWX가 수정한 요청액 9,130만 달러에 대해 5,300만~5,800만 달러를 권고했다.
• 23억 달러 규모의 그레이트베이슨 2028년 확장 프로젝트는 일일 10억 입방피트(Bcf)의 계약 수요를 확보했으며, 경영진은 2028년 4분기 상업 가동 개시 후 연간 2억 7,000만~3억 달러의 추가 마진을 창출할 것으로 예상하고 있다.
• SWX는 고객에게 지급해야 할 가스구입비조정(PGA) 잔액을 반영한 후 약 7억 달러의 가용 유동성과 약 37억 달러의 연결 순부채로 분기를 마감했다.

주요 재무 데이터

사업 및 운영 실적

사우스웨스트 가스는 개정된 캘리포니아주 요금, 꾸준한 고객 증가, 애리조나주 계통 무결성(System Integrity) 메커니즘의 수혜를 입었다. 다만 이러한 이익은 애리조나 및 네바다주의 비디커플링(non-decoupled) 고객 청구 마진 감소와 네바다주 VIER 메커니즘 관련 마진 축소로 일부 상쇄되었다.

연간 누적 운영 및 유지보수(O&M) 비용은 비교적 변동 없이 유지되었다. 경영진은 5개년 계획 기간 동안 고객당 유틸리티 O&M 비용을 변동 없이 유지하는 것을 목표로 지속 추진하고 있다.

캘리포니아주에서 최종 완료된 요금 심의안에 따라 3,200만 달러를 소폭 상회하는 연간 추가 수익, 10%의 자기자본이익률(ROE), 50%의 자기자본비율이 허용되었다. 해당 요금은 2026년 1월 1일 자로 소급 적용된다.

네바다주는 약 4,800만 달러의 연간 추가 수익을 인가하고 허용 ROE를 9.5%로 유지했으며, 실제 자기자본비율을 51.35%로 승인했다. 신규 요금은 2026년 10월 발효되었다. SWX는 요금기저에서 제외된 일부 시험연도 후(post-test-year) 설비자산에 대해 재심의를 요청한 상태다.

애리조나주의 경우 규제위원회 실무진이 5,300만~5,800만 달러의 연간 추가 수익과 9.75%의 ROE를 권고했다. SWX는 시험연도 후 설비자산 추정치, 운전자본 가정 및 기타 항목을 업데이트한 후 요청액을 기존 1억 100만 달러에서 9,130만 달러로 하향 조정했다. 청문회는 12월 7일 시작될 예정이며, 경영진은 2027년 4월 1일부터 요금이 발효될 것으로 예상하고 있다.

그레이트베이슨 확장 프로젝트

그레이트베이슨은 연말까지 연방에너지규제위원회(FERC) 인허가 신청서를 차질 없이 제출할 예정이다. 화주들은 구속력 있는 사전 계약(precedent agreements)을 체결하고 일일 1 Bcf의 계약 수요를 뒷받침하는 보증을 제출했다. FERC 승인이 완료되면 화주들은 최소 20년 만기의 운송 계약을 체결해야 한다.

경영진은 이 프로젝트에 23억 달러의 투자가 필요하며, 2028년 4분기로 예상되는 상업 가동 시점부터 연간 2억 7,000만~3억 달러의 추가 마진을 창출할 것으로 추정하고 있다. 현재 프로젝트 추정치 중 약 6억 달러 및 관련 마진은 기존 장기 가이던스에 포함되어 있지 않다.

예상 프로젝트 지출은 2026년에 약 15%, 2027년에 25%, 2028년에 60%가 배정되어 있다. SWX는 2027년 후반에 공공편익증명서(CPCN) 신청에 대한 결정이 내려질 것으로 예상한다. 회사는 일부 공급업체 구매주문서를 확보했으나, EPC(설계·조달·시공) 계약업체는 아직 선정하지 않았다.

경영진 가이던스

경영진은 2026년 설비투자 가이던스와 기존 장기 재무 지표를 재확인했다. 회사는 2월에 발표될 수정 5개년 자본, 자금조달, 요금기저 및 수익 가정에 그레이트베이슨 추정치 23억 달러 전액을 반영할 계획이다.

SWX는 2026년 잔여 기간 동안 유상증자를 진행하지 않을 것으로 예상하고 있다. 회사는 3억 4,000만 달러 규모의 시장가 신주발행(ATM) 한도를 유지할 계획이지만, 이 프로그램의 갱신이 현 계획 기간 동안 외부 자기자본 조달 수요가 크지 않을 것이라는 기존 전망을 바꾸지는 않는다고 밝혔다.

리스크 및 주요 관전 포인트

• 애리조나주는 여전히 미해결 상태로 남아 있는 주요 요금 심의 건이다. 최종 수익 인상액, 인가 ROE 및 공식 요금(formula-rate) 구조는 규제위원회의 승인을 거쳐야 한다.
• 애리조나주 실무진은 SWX가 제안한 20bp 구간 대비 50bp의 공식 요금 불감대(dead band)를 제안했다. 경영진은 이처럼 더 넓은 구간 역시 과거 시험연도 모델보다는 개선된 형태라고 보고 있다.
• 네바다주의 대체 요금 책정 규정은 여전히 마련 중인 상태다. 경영진은 연말까지 최종 규정이 나올 것으로 예상하며, 2027년 2분기 초에 신청서를 제출하여 2028년 중반경 요금 적용 효과가 나타날 것으로 기대하고 있다.
• 그레이트베이슨 확장은 FERC 및 주 정부의 승인, 공사 집행, 프로젝트 비용 지출 시기, EPC 계약업체 선정 등에 여전히 영향을 받는다.
• 기상 여건과 사용량 연동 요금 구조로 인해 네바다주 가스구입비조정(PGA) 잔액의 고객 환급 속도가 경영진의 예상보다 더뎠다.
• 경영진은 규제 자산 감가상각 정산(true-up)이 성격상 일회성에 가깝다고 설명했다.

애널리스트 질의응답(Q&A) 주요 내용

경영진은 애리조나주와 네바다주의 선거 관련 규제위원 교체가 현재의 규제 절차를 실질적으로 바꾸지는 않을 것으로 예상된다고 밝혔다. 애리조나주의 경우 유임된 위원 3명이 최근 일관성을 유지하고 있으며, 신임 위원 2명의 입장은 향후 표결을 통해 더 명확해질 전망이다.

2027년의 경우 캘리포니아주와 네바다주가 규제 마진 개선에 대해 더 명확한 가시성을 제공하고 있다. 네바다주는 2027년에 연간 기준(run-rate) 전체 기여를 할 것으로 보이며, 애리조나주는 2027년 4월 1일에 요금이 발효될 경우 일부 기간 기여할 전망이다. 애리조나주의 온기 반영 효과는 2028년에 이어질 것으로 예상된다.

FAST-41 절차에 대해 경영진은 신속한 승인을 보장하기보다는 인허가 조율, 투명성, 일정 예측 가능성을 확보하기 위한 도구라고 설명했다.

경영진은 그레이트베이슨의 예상 마진 범위가 최종 공사비, 자본 지출 시기, 건설자금이자(AFUDC) 자본화에 부분적으로 달려 있다고 말했다. 공사비가 낮아지면 마진이 하단으로 치우칠 수 있는 반면, 지출 시기와 높은 AFUDC 자본화는 상단에 영향을 미칠 수 있다.

실적 발표 콘퍼런스콜 전문 녹취록

전체 실적 발표 컨퍼런스 콜 녹취록

경영진 발표

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.

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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.