Image source: The Motley Fool.

DATE

Friday, August 7, 2026 at 9:00 a.m. ET

CALL PARTICIPANTS

• Director of Finance - Kelsie Davenport
• Senior Vice President of Regulatory and External Affairs - Lawrence Oliver
• President and Chief Executive Officer - Paul Nester

TAKEAWAYS

• Net Income (Q3) -- $558,900, or $0.05 per diluted share, representing a nominal increase from $538,412 in the third quarter of fiscal 2025.
• Net Income (9 Months) -- $14,186,255, or $1.37 per diluted share, up 5.2% from $13,484,309 in the first nine months of the previous fiscal year.
• Operating Revenue (Q3) -- $17.1 million, compared to $17.3 million in the same period last year, reflecting lower gas costs.
• Operating Margin (Q3) -- $757,000 higher than the equivalent period a year earlier, aided by higher non-gas base rates that became effective Jan. 1.
• Fiscal 2026 EPS Guidance -- $1.29 to $1.32, narrowed from the previous range following unusual weather patterns in May.
• Capital Expenditures (9 Months) -- $16.1 million, a 2% increase over the same period a year ago due to increased activity in the third quarter.
• Full-Year Capital Expenditures Forecast -- $22 million, reflecting the pull-forward of the Mountain Valley-Lafayette main extension into the current fiscal year.
• Main Extensions -- 3.5 miles of new main installed through the first nine months of fiscal 2026, slightly behind the installation pace for the same period last year.
• New Service Connections -- 464 connections through the first nine months of fiscal 2026, a decrease from the same period in the prior year.
• Service Renewals -- 322 services renewed in the first nine months of the fiscal year, representing a 40% increase year over year.
• Industrial Gas Usage -- Increased more than 25% for the third quarter, primarily driven by the company's largest industrial customer.
• Residential and Commercial Usage -- Remained flat for the third quarter, as uneven weather patterns did not generate typical gas usage despite colder temperatures.
• Refinanced Debt -- $15 million note refinanced at a 5.2% fixed interest rate for a three-year term, compared to a previous rate of 2%.
• MVP Project Investment -- $1 million invested in fiscal 2026 for the Southgate and Boost expansion projects, funded by lines of credit.
• Rate Case Settlement -- $3.85 million in stipulated incremental annual revenue, representing a decrease from the $4.3 million originally requested in the December filing.
• Customer Refunds Accrual -- $275,000 accrued as of June 30 for refunds related to interim rates charged since Jan. 1, 2026.
• Regional Investment -- $85 million foreign direct investment announced in the region, which is expected to add nearly 500 jobs to the local economy.

Need a quote from a Motley Fool analyst? Email [email protected]

RISKS

• Davenport stated, "non-gas operating and maintenance expenses are higher... primarily due to inflationary pressures on personnel costs, professional services, and IT support," which limited operating income growth.
• CEO Nester noted that Q3 performance was "offset by persistent inflation and the effect of an industrial customer ceasing operations" back in March.
• Nester reported that during Winter Storm Fern, "icing around the ground of the tank... caused the tank to just move a little bit... and cause some structural damage," forcing the LNG facility to remain out of service for safety assessments.

SUMMARY

RGC Resources, Inc. (RGCO +1.36%) reported steady results for the third quarter of fiscal 2026, with financial performance influenced by increased base rates and infrastructure investments. Management reached a regulatory settlement to increase annual revenues while navigating operational challenges at its liquefied natural gas storage facility. The company is utilizing its position in the Mountain Valley Pipeline to ensure service reliability and is focusing on expanding its regional distribution network to support new industrial and medical developments.

• CEO Nester explained that the 54-year-old LNG tank experienced "metal and structural compromise" during an extreme cold event and the company is evaluating options including "modern tank holding apparatus."
• Management reported that restoring on-system storage for peak shaving is targeted for the 2027 to 2028 winter season.
• The company established a regulatory asset for ongoing costs associated with the LNG facility event and expects "recovery in some future proceedings."
• SVP Oliver noted that despite a 3% increase in heating degree days year to date, residential and commercial volumes were down because many degree days were concentrated around a single storm event.
• CFO Davenport highlighted that the MVP mainline has been in service for over two years and currently provides "excess cash distributions on a quarterly basis."
• Management reported that the Boost project is expected to enable a 30% increase in gas transportation capacity through the MVP mainline once completed.

INDUSTRY GLOSSARY

• Dekatherm: A unit of heating value equivalent to 10 therms or 1 million British thermal units (Btu).
• Peak Shaving: The process of using stored gas supplies to supplement pipeline deliveries during periods of maximum demand, typically the coldest days of winter.
• Heating Degree Days (HDD): A measurement designed to quantify the demand for energy needed to heat a building, based on the extent to which the average daily outdoor temperature falls below 65 degrees Fahrenheit.
• Weather Normalization Adjustment (WNA): A regulatory mechanism that adjusts customer bills to offset the impact of abnormally warm or cold weather on utility revenues.
• SAVE (Steps to Advance Virginia’s Energy) Plan: A regulatory framework in Virginia that allows natural gas utilities to recover costs associated with infrastructure replacement and enhancement.
• Regulatory Asset: A cost incurred by a regulated utility that the regulator allows to be deferred and recovered from customers in future rates.
• MVP: Mountain Valley Pipeline, a 303-mile natural gas pipeline system that spans from West Virginia to Virginia.
• TCO: The Columbia Pipeline, one of the primary interstate pipelines serving the Roanoke Gas system.

Full Conference Call Transcript

Kelsie Davenport: Good morning, and thank you for joining us as we discuss RGC Resources' 2026 third quarter results. I'm Kelsie Davenport, Director of Finance of RGC Resources, Inc. I am joined this morning by Paul Nester, President and CEO of RGC Resources; and Tommy Oliver, Senior Vice President of Regulatory and External Affairs. Tim is under the weather this morning and is unfortunately unable to be with us. Before we get started, let's review a few administrative items. [Operator Instructions] The link to today's presentation is available on the Investor and Financial Information page of our website at www.rgcresources.com. [Operator Instructions] Turning to Slide 1. This presentation contains forecasts and projections.

Slide 1 has information about risks and uncertainties, including forward-looking statements that should be understood in the context of our public filings. Slide 2 contains our agenda. We will discuss our operational and financial highlights for the third quarter and first 9 months of our fiscal 2026 year. We will then review the outlook for the remainder of 2026, with time allotted for questions at the end. I will now turn the presentation over to Tommy.

Lawrence Oliver: Well, thank you, Kelsie, and good morning, everybody. Turning now to operations on slide 3. Main extensions and renewal activity has continued on a steady pace through fiscal 2026. We installed 3.5 miles of new main through the first 3, I'm sorry, through the first 9 months of the current fiscal year, a little shy of our installation in the same period of fiscal 2025. In addition, we connected 464 new services in 2026, down from the previous same period last year. We do have a healthy backlog of main extensions, which speaks well of our continued residential development across the region.

As shown on the right side of the slide, we renewed 2.7 miles of main and 322 services during the first 9 months of the 2026 fiscal year. While winter weather dampened the main mile renewal, renewed compared to the same period last year, the service renewals increased 40%. Let's transition over to slide 4. Slide 4 shows our delivered gas volumes for the quarter. Weather patterns during the third quarter resulted in some counterintuitive results, especially in May. The quarter was slightly colder than the same period a year ago, as shown on the slide, but those days occurred unevenly and, as a result, did not generate the typical gas usage you would expect from cooler weather.

It did, however, resulted in a credit to customers under the weather normalization adjustment. Overall for the quarter, residential and commercial usage was flat. Industrial usage was up more than 25%, mostly attributable to our largest industrial customer. As a reminder, under our tiered rate structure in that customer class, those incremental dekatherms are delivered at our lowest margin. Transition over to slide 5, delivered gas volumes do not tell our exact same story for fiscal 2026 year-to-date. Residential and commercial volumes were down despite heating degree days increasing by 3%. Many of those heating degree days were generated around the Winter Storm Fern event, with other portions of the year warmer than the equivalent period a year ago.

Volumes were up 1%, with the residential and commercial declines offset by industrial increases, again led by that same industrial customer just mentioned. Included within these numbers is the absence this quarter of a longtime top 10 customer who ceased operations in March. We discussed that situation more fully on the previous earnings call. Slide 6 shows CapEx for the first 9 months of fiscal 2026 compared to 2025. Overall investment was $16.1 million in the current year, up approximately 2% over the same period a year ago. As customary, we picked up the pace of capital spending in quarter 3 and made up most of the deficits that arose from weather delays in the prior quarter.

We will discuss plans for the full year later in the presentation. I'm going to now turn the presentation back over to Kelsie to review our financial results for the quarter. Kelsie?

Kelsie Davenport: Thank you, Tommy. Slide 7 shows both our third quarter and 9-month year-to-date financial results for fiscal 2026. Third quarter results were nominally ahead of the same period a year earlier. Net income was approximately $550,000, or $0.05 per diluted share, driven primarily by higher margins. The interim rates that went into effect January 1, along with the new state revenues, drove the margin increase despite the loss of the large industrial customer we've noted in previous calls and the weather Tommy just discussed. Operating expenses, as shown on the slide, are lower due to gas costs.

However, non-gas operating and maintenance expenses are higher to fiscal 2025 third quarter, primarily due to inflationary pressures on personnel costs, professional services, and IT support. The year-to-date results are also shown on slide 7. Net income was $14.2 million in the first 9 months of fiscal 2026, or $1.37 per diluted share, compared to $1.31 per diluted share in the first 9 months of fiscal 2025, a 4.6% increase. The effect of the non-gas base rate increase was noticeable in the second quarter, largely driving our year-to-date results as the additional revenues affected the volumetric component. Thus, a larger portion of the increase was recognized during the winter heating season due to the higher energy demands.

Accordingly, when delivered volumes are lower in the second half of the fiscal year, margin and net income are also lower. The items that have led to increased expenses in the quarter are also driving higher expenses in the year-to-date results. Moving to slide 8, our balance sheet remains strong. During the quarter, we refinanced a $15 million note that matures later this month and carries a 2% interest rate. It is classified as long-term debt at June 30. This forward starting note and its attendant interest rate swap is fixed for a 3-year term at 5.2%. I did want to add a few comments on the Mountain Valley Pipeline investment.

The MVP mainline has been in service for just over 2 years now and is operating safely and reliably as expected. Our share of the joint venture earnings is comparable this year to a year ago, and we continue to receive excess cash distributions on a quarterly basis. To enhance future cash flow from MVP, there are 2 projects underway, Southgate and Boost. Southgate will move gas from the end of the mainline into North Carolina, and Boost will enable a 30% increase in the amount of gas that can be transported through the mainline. Southgate is in the construction phase and progressing as expected. Boost is actively working on its permits and has placed orders for equipment.

We have invested just over $1 million in the fiscal year for these projects, with the funding coming from lines of credit that we established in September of last year. We are pleased with the progress and prospects of both projects. I will now pass the presentation to RGC's CEO, Paul Nester. Paul?

Paul Nester: Thank you, Kelsie, and good morning. Thank you for joining us for the third quarter earnings call. We're on Slide 9. We have a few items to discuss as we are close to wrapping up fiscal 2026. We're going to start on Slide 10 with an update on our LNG facility. If you were with us last quarter, and if you've read our 10-Q, we've disclosed that we did have some structural damage in the fiscal second quarter at the LNG facility. Our teams are still there working to assess that damage and to keep that facility safe. They're doing a great job. I'd like to thank them for all their fantastic work over the last 6 months.

We continue to be in touch with the State Corporation Commission on that matter as well as our insurance carrier. Certainly, when we have more information to disclose, we'll do that appropriately. We, as you can see on the slide, have been aggressively working to replace the peak shaving supply that our LNG facility provided. You may recall that facility was used by the company on the coldest winter days to supplement our interstate pipeline volume. Without the facility being available, you can see we've added gas through one of our primary interstate pipelines, the Columbia Pipeline, or referred to as TCO. We're excited about that and grateful for that.

We're going to talk about a capital project that's now underway, that's going to bring more Mountain Valley gas further into the Roanoke Gas distribution system. That project's begun as well, and we're in the process of procuring truck LNG. That's something we've done in the past, particularly before Mountain Valley was completed. Moving on to slide 11, we've kept the capital forecast for 2026 about the same as what we showed you last quarter at $22 million. We have changed some of the buckets, if you will, of that spending. We have pulled forward again this Mountain Valley-Lafayette main extension into this year.

That project was in our 5-year capital forecast, so it was something that the company fully intended to do, but we've now pulled that forward a little bit into 2026. When we start showing you our 2027 capital forecast, it's going to be a larger component of that. I would now like to ask Tommy to address the recent rate case results and some other regulatory happenings. Tommy?

Lawrence Oliver: Yes, thank you, Paul. We're on Slide 12 now. As we discussed in our most recent earnings call, Roanoke Gas filed an expedited rate case on December 2 of last year seeking approximately $4.3 million in incremental annual revenues based on our currently authorized return on equity of 9.9% and a 59% equity ratio. Rates became effective January 1, 2026, subject to refund. Happy to report that we reached a settlement with the SCC staff on July 1, 2026, that resolved all issues in the case. We did participate in the scheduled hearing on July 15, 2026.

The stipulated incremental revenue agreed to in the settlement was $3.85 million, and we began charging those lower rates that resulted from the settlement beginning August 1. We are pleased to have reached agreement and believe this was a reasonable outcome. As of June 30, we have $275,000 accrued for refunds to customers related to the rates charged beginning January 1, 2026. The ongoing cost associated with the LNG facility event was not addressed in this case, however. We continue to update the staff and work with them through the process. And we have established a regulatory asset, and we expect recovery in some future proceedings.

Paul Nester: Yes, thank you, Tommy. It's a great result, and I just want to thank Tommy and his team and the rest of the RGC team on that. That truly is a company-wide effort. It reflects the investment in the system to continue making it safe or keeping it safe and reliable, I should say. And a lot of support across the company goes into the ratemaking. And we're really pleased with this result. I think it's fair and appropriate at this point in time. We're of course always mindful, right, Tommy, of the impact on the customer and what it means to customer bills.

Lawrence Oliver: Absolutely, yes. Thank you.

Paul Nester: All right, before we open the line for questions, let's look at our 2026 forecast. We've narrowed the range from what we presented last quarter. A lot of that is the result of some of that unusual weather pattern and natural gas delivery that was associated with that in that May timeframe. So we're now showing the lower end of the range at $1.29 and the higher end at $1.32. Similar to 2025, we are projecting a small loss in the fiscal, the typical fourth quarter. Kelsie and Tommy both talked about that. The nature of the volumetric rates certainly lends itself to higher margins in the first and second quarters, less so in the third and fourth quarters.

A lot of discussion on interest rates and inflationary pressure, certainly in the last few weeks. I think most folks now believe we may have a rate increase at some point a little bit later this year. If you go back to last year at this time, there were projections of 3 to 4 rate decreases. Obviously, that's just not possible with the importance of inflationary pressure. Kelsie talked about the note that we refinanced. That was really a great effort by the team here, and I appreciate our bank partners that worked with us on that. Tommy talked about the housing starts and the residential development. The Roanoke Valley economy continues to be, I would say, net positive.

We talked about our large industrial customer that unfortunately ceased operations back in March, but otherwise, I think it's still very positive. The Google Data Center is moving forward. There continues to be investment in the medical complex here, notably the Taubman Cancer Center. Just the construction on that is phenomenal, and a few other developments around that, so we're excited about that. There was a large foreign direct investment announced in the region, end of the third quarter. That company is going to spend about $85 million and add almost 500 jobs. We're really excited about that as well. So again, as always, we just want to thank our customers, first and foremost.

Without them, we would not be here. And I'd also like to again thank our employees. We've had another quarter of working very safely, and I'm proud of their efforts in that regard. So with that, we'd like to open the line for questions.

Paul Nester: [Operator Instructions]

Unknown Analyst: Good morning, everyone.

Paul Nester: Oh, my. Good morning. So nice to have you with us.

Unknown Analyst: Looking across your slide here on the LNG update. So, I was wondering if you could give us a little more color as to maybe what the problem really, what the problem is and maybe potential solution for it. I mean, is this a situation where the tank's got to come out and be replaced or is it something else?

Paul Nester: Yes, happy to answer that question, [ Mike ]. In February, around the Winter Storm Fern event where we had really extraordinarily cold weather for an extended period of time, and of course, that cold weather enveloped most of the country, as you know. We did have some what's known as icing around the ground of the tank, and that caused the tank to just move a little bit, if you will, and cause some structural damage to the tank. Maybe one term to think of is metal fatigue, if you will. Now, we did not have any leaking or any unsafe condition as a result of that, thankfully, and we're again very grateful for that.

The tank was constructed and put in operation in 1972, so it's 54 years old. While it's approximately a 90 to 95-year asset, if you will, it's halfway through that and again had a little metal and structural compromise. So we're working through the engineers that we've retained who are tank specialists to help us ascertain what our options are, Mike, for the tank. Are we able to make repairs in some of those spots where there was some metal stress? Or we are evaluating, for example, possibly newer, more modern tank holding apparatus. As a reminder, our tank is approximately a 200,000-gallon, which also equates to approximately 220,000-dekatherm tank.

I would say has been well-sized, if not maybe a little larger than what we've needed in the Roanoke Gas system, which again is a great thing. It's been just wonderful for resilience and reliability over many, many years. So we're still evaluating what the future looks like, what our future options are for storage. For sure, we want on-system storage to help with peak shaving. We're fortunate now to have the third pipeline, Mountain Valley. And you may remember over many years ago, we always talked about if something were to happen to one component of our supply, having that additional supply source available would make the difference, and that's truly the case today.

Unknown Analyst: So you think you'll have, obviously not for this winter season, but the next winter season? If it's taken care of?

Paul Nester: That's the plan right now. We're working to having that peak shaving capability via on-system storage for the 2027-2028 winter season. Correct. That's our goal right now. Any other questions? [Operator Instructions] We'll wait just one more moment to see if there are any further questions. Okay. Hearing none, this concludes the third quarter earnings call. Again, we just want to thank each and every one of you for taking time to be with us, and we very much look forward to you listening. Look forward to being with you in December when we share the full year 2026 results.

As Kelsie and Tommy reported, we're off to just a good first 9 months and look forward to completing the fiscal year. Wishing everyone a safe and happy weekend. Thank you.