Hello, and welcome to the ATO Q2 2021 Conference Call and Webcast. At this time, all participants are in a listen-only mode. A question-and-answer session will follow the formal presentation. As a reminder, this conference is being recorded. It's now my pleasure to turn the call over to Dan Meziere, Vice President Investor Relations and Treasurer. Please go ahead, sir.

Thank you, Kevin. Good morning, everyone, and thank you for joining us today. With me this morning are Kevin Akers, President and Chief Executive Officer; and Chris Forsythe, Senior Vice President and Chief Financial Officer. Our earnings release and conference call slide presentation, which we will reference in our prepared remarks are available at atmosenergy.com under the Investor Relations tab. Today's presentation also includes references to non-GAAP financial measures. You should refer to the information contained in the slides accompanying today's presentation for definitional information and reconciliations of non-GAAP measures to the closest GAAP financial measure. As we review these financial results and discuss future expectations, please keep in mind that some of our discussion might contain forward-looking statements within the meaning of the Securities Act and the Securities Exchange Act. Our forward-looking statements and projections could differ materially from actual results. The factors that could cause such material differences are outlined on slide 29 and more fully described in our SEC filings. With that, I will turn the call over to our President and CEO, Kevin Akers. Kevin?

Thank you, Dan, and good morning, everyone. We appreciate you joining us today and your continued interest in Atmos Energy. During this quarter, we continued to successfully execute our proven investment strategy of operating safely and reliably while we modernize our natural gas distribution, transmission, and storage systems. This strategy, along with the exceptional dedication and effort of all 4,700 employees at Atmos Energy, continues to benefit our customers in the form of safe and reliable natural gas service. This was clear during Winter Storm Uri as the modernization of our systems, especially over the last 10 years, provided the reliability necessary to meet the human needs requirements of our customers. I want to take this opportunity to highlight and thank our gas supply and gas control teams, and the many operations, transmission, and underground storage employees that dedicated countless hours to keeping natural gas safely flowing during Winter Storm Uri. The winter storm certainly highlighted the importance that reliable natural gas systems, diversified supply portfolios, system versatility, along with underground storage capacity bring to delivering safe and reliable natural gas service. As an example of system modernization and reliability, I want to highlight our third Atmos pipeline storage salt-dome project. This project, nearing 50% completion, will provide an additional five to six Bcf of cavern storage capacity when in full service late 2022 or early 2023. This new cavern will provide us the continued capability to meet the growing demand in the Dallas–Fort Worth metroplex, as well as allow us to safely perform the required regulatory compliance work while meeting the current needs of our customers. Additionally, APT has started our Line S-2 replacement project that will create an enhanced supply hub to the east of the growing Dallas–Fort Worth metroplex and bring additional supply in from the Haynesville and Cotton Valley shale plays. We anticipate this 36-inch, 90-mile project to be completed in three phases, with the final phase being complete in 2023. The storm once again highlighted the strength of our balance sheet. After incurring unprecedented gas costs during the storm, we were able to quickly finance these purchases with the issuance of $2.2 billion in long-term debt for an all-in debt cost of 83.4 basis points. This financing is structured to provide us flexibility as we work with our regulators to recover these costs. In Kansas and Texas, where we incurred most of our extraordinary gas costs, new legislation was introduced to minimize the impact on the customer bill by extending the recovery periods for these unprecedented costs through securitization. The legislation in Kansas was signed into law on April 9 and allows utilities to file for permission from commission to securitize these costs for a period of up to 32 years. In Texas, the legislature is considering a statewide securitization program. Under this program, natural gas utilities would have the opportunity to apply to the Railroad Commission to have their extraordinary costs securitized by the Texas Public Financing Authority and to use the net proceeds to pay off the debt they incurred to finance these natural gas purchases. This legislation has been passed by the house and is currently being considered in the Senate. In our remaining states, we anticipate recovering gas costs through our normal purchase gas cost mechanisms over a 12 to 18-month time frame. I am very proud of all 4,700 Atmos Energy employees in the work they do every day to provide safe and reliable natural gas service to our 1,400 communities and 3.2 million customers. Their dedication and commitment have Atmos Energy well positioned for success in the second half of the fiscal year. I will now turn the call over to Chris for an update on our financial performance. Chris?

Thank you, Kevin, and good morning, everyone. Last night, we reported fiscal 2021 second quarter net income of $297 million, or $2.30 per share, compared to $240 million, or $1.95 per share in the prior year quarter. Year-to-date earnings were $514 million, or $4.01 per share, compared with earnings of $418 million, or $3.42 per share in the prior year period. Our second quarter and year-to-date performance largely reflects positive rate outcomes driven by safety and reliability spending, customer growth in our distribution segment, lower O&M spending, and a reduction in our annual effective tax rate. During the second quarter, APT began refunding $107 million in excess deferred tax liabilities to its customers over a three-year period. Additionally, in Tennessee, we began refunding $17 million in excess deferred taxes over a three-year period. As a reminder, these refunds result in a reduction to revenue and a corresponding reduction in income tax expense, resulting in no material impact on our net income. Since these excess deferred taxes were approved during the second quarter, we adjusted our annual effective tax rate to reflect the lower tax expense that we will realize this fiscal year. The application of this lower annual effective tax rate to our results for the six months ended March 31 resulted in an $0.11 benefit during the second quarter. However, we can only recognize the associated reduction in revenue as it is built over the last six months of the fiscal year. Therefore, this $0.11 benefit will be fully offset during the third and fourth quarters as we build those lower revenues. Consolidated operating income increased about 17% to $681 million during the six months ended March 31. Slides four and five summarize the key performance drivers for each of our operating segments. Rate increases in both of our operating segments, driven by increased safety and reliability capital spending, totaled $130 million. Customer growth in our distribution segment contributed an incremental $11 million, as we continue to benefit from strong population growth in several of our service areas. For the 12 months ended March 31, we experienced 1.87% net customer growth in our North Texas distribution business and 1.61% net growth across our eight-state footprint. We experienced an $8 million decline in service order revenues in our distribution segment, primarily due to the temporary suspension of collection activities. Additionally, our provision for bad debt expense increased almost $9 million in our distribution segment compared to the same period last year. This combined $17 million decrease represented the most significant impact on our financial performance through the economic downturn caused by the pandemic. Our commercial sales volumes have turned significantly better than our expectations since the start of the fiscal year. After a 15% period-over-period decrease in sales volumes during the first quarter, commercial sales volumes increased 16% in the second quarter compared to the same period last year and were about 2% higher year-over-year. While some of this increase is attributed to the significantly colder weather experienced during the second quarter, commercial sales volumes have trended less than 5% below the two-year weather-normalized average, with much of that decrease being experienced during the first fiscal quarter. Throughout the second quarter, we have noted steady improvement as economic activity has started to pick up. Consolidated O&M expense, excluding bad debt expense, decreased $14 million. O&M in our distribution segment was about $6 million lower than the prior year, primarily reflecting lower travel costs. O&M in our pipeline and storage segment was approximately $8 million lower than the prior year, primarily due to the completion of some nonrecurring well integrity work during the prior year period and conservative O&M management, as we evaluated how our revenues would materialize over the first six months of the fiscal year. Consolidated capital spending decreased 15% to $846 million, with 87% of our spending directed towards safety and reliability spending. The decrease largely reflects the timing of spending in our distribution segment. We remain on track to spend $2 billion to $2.2 billion in capital expenditures this fiscal year to further enhance the safety and reliability of our distribution and transmission network while reducing methane emissions. We continue to execute our well-established regulatory strategy focused on annual filing mechanisms, which mitigate the incremental impact to customer bills while reducing lag. To date, we have implemented $110 million in annualized regulatory outcomes, and we currently have about $145 million in progress. Slides 27 and 28 summarize the key attributes for these outcomes. Slide 17 summarizes our planned activities for the remainder of the fiscal year. Due to the historic nature of Winter Storm Uri, we experienced unforeseeable and unprecedented market pricing for gas costs, which resulted in aggregated natural gas purchases during the month of February of approximately $2.3 billion. To help pay for these costs, we completed $2.2 billion of long-term debt financing in March. As a reminder, gas costs are a pass-through cost and recoverable in all of our jurisdictions. However, in Kansas and Texas, due to the size of the costs incurred, our regulators issued orders authorizing natural gas utilities to record regulatory assets to account for the extraordinary costs associated with the storm. As of March 31, we have recorded a $2.1 billion regulatory asset, with approximately $2 billion recorded in Texas and approximately $77 million recorded in Kansas. As Kevin mentioned, we have the ability to securitize these costs in Kansas, and we are carefully monitoring the proposed statewide securitization legislation in Texas. We also executed forward sales arrangements under our ATM for approximately 2.5 million shares for $239 million, and we settled forward agreements on 4.5 million shares for approximately $461 million of net proceeds. As of March 31, we have approximately $116 million in net proceeds available under existing forward sale agreements, and we have about $313 million available for issuance under the ATM program. We intend to satisfy our remaining fiscal 2021 equity needs through our ATM program. As a result of this financing activity, our equity capitalization, excluding the $2.2 billion of storm-related financing issued during the second quarter, was 60.4% as of March 31, and we finished the quarter with approximately $3.5 billion of liquidity. Details of our financing activities and our financial profile can be found on slides 7 to 10. Yesterday, we reaffirmed our fiscal 2021 earnings per share guidance in the range of $4.90 to $5.10 per diluted share. As a reminder, approximately 70% of our distribution revenues are earned through the first six months of the fiscal year. Substantially, all of our pipeline storage and other segment revenues are earned under a straight fixed variable rate design. Now that the winter heating season is over, we have more clarity around our revenues for the remainder of the fiscal year, and we believe fiscal 2021 earnings per share will be at the upper end of our guidance range. We anticipate our sales volumes to be consistent with what we typically experience during the second half of the fiscal year. We also anticipate that our service order revenues will frank consistently with the first six months of the fiscal year. We've also reflected in this guidance the decrease in revenue over the last six months in the fiscal year as we refund excess deferred taxes to our customers, and we have updated our income tax expense guidance range to reflect the impact of these refunds. Finally, we anticipate that O&M will increase modestly during the second half of the fiscal year and be in line with our original O&M guidance range. We continue to meet all of our compliance requirements, and we will begin to address some of the system maintenance work we were able to safely delay during the first half of the fiscal year. Slides 11 and 12 provide additional details around our guidance. Thank you for your time today. I will now turn it back over to Kevin for his closing remarks.

Thank you, Chris. I appreciate that financial update. As you heard, we continue to be focused on the long-term sustainability of Atmos Energy and remain on track to meet our fiscal 2021 targets. As we look to the second half of the year, we will continue to execute on our strategy that supports our vision to be the safest provider of natural gas services. During our last two quarterly calls, I've shared the progress we are making to minimize our carbon footprint as well as our water and land impact at some of our offices and service centers, including the work we are doing to increase the amount of RNG we have on our system today and to help customers reduce their carbon emissions. To date, we are evaluating approximately 30 RNG projects across our systems. As a reminder, our environmental strategy is focused on five key areas: gas supply, operations, fleet, facilities, and customers. Today, I want to highlight how Atmos Energy is working to reduce methane emissions as we modernize our business and infrastructure by investing in innovation and technology. The following examples illustrate how Atmos Energy will meet our goal to reduce methane emissions by 50% by 2035, as well as how we are helping customers understand the role that natural gas plays in reducing their carbon footprint at home in an affordable manner. We recently installed a new methane monitoring technology at our Tri-Cities underground storage facility, called gas cloud imaging camera. This 360-degree fixed base camera will continuously monitor our compression and storage field assets for methane emissions. If necessary, the technology will send alerts, including pop-up alerts with images to our plant operations employees in addition to text and email alerts. In addition to our existing methane monitoring and detection equipment, we are finalizing plans to deploy fixed base and mobile technologies throughout our underground storage operations. Additionally, we are in the process of installing a fuel cell to generate low-carbon electricity at one of our facilities. The fuel cell will be powered with natural gas and is anticipated to substantially reduce the carbon footprint for that facility. We anticipate the fuel cell will be operational by the end of this calendar year. With affordability and community support always top of mind for us, our Colorado team partnered with the Greeley-Weld County Habitat for Humanity Group to build a zero-net energy home for a local family. This will be the first of its kind for local habitat homes. This home is designed to receive a home energy rating system score of zero, which means the home produces the same amount of energy it consumes over the course of the year by using efficient natural gas appliances, better insulation, and solar technology. The total utility cost for this home is anticipated to be approximately $350 per year, which is expected to provide about $2000 in annual utility bill savings relative to the average US home. This solution is significantly less expensive than an all-electric home. We are also working with builders in two Texas locations to design homes that are expected to yield similar environmental results. Our employees put their heart, soul, time, and energy into projects like these every day to modernize our system, do our part to protect and preserve our environment for generations to come, and support the communities where they live and work. I'm very humbled by their compassion and commitment to be good neighbors. Providing this family with a natural gas home that is environmentally friendly and cost-efficient is just one way Atmos Energy fuels safe and thriving communities. Last year, legislation designed to promote the use of all energy sources and maintain customer energy choice, which we refer to as all fuels legislation, was passed in Louisiana and Tennessee. During the second quarter, similar legislation was passed in Kansas, Kentucky, and Mississippi. Earlier this week, the Texas Senate passed HB 17 and it is now on its way to the Governor for signature. Assuming it is signed, six of our eight states will have passed all fuels legislation. The successful execution of our strategy and our financial position have us well positioned to continue safely delivering reliable, affordable, efficient, and abundant natural gas to homes, businesses, and industries to fuel our energy needs now and well into the future. I will now open up the call for questions. Dan, I'll turn it back over to you and the operator.

Thank you. Our first question today is coming from Insoo Kim from Goldman Sachs. Your line is now live.

Thank you. Good morning. My first question is for Chris. For the quarter, thank you for explaining what contributed to the year-over-year increase. It seems there was a timing issue with the asset lower tax rate, but that will be adjusted by the end of the year without affecting the overall yearly results. However, even without that, it appears to have been a relatively strong quarter compared to our expectations. Could you explain how much of that increase you anticipated and how much was an additional benefit from factors like rates or non-weather related volumes? Also, as you reiterate your guidance, do you feel confident at least at the midpoint at this time?

Sure, good morning. There were a few key points to discuss. The regulatory outcomes aligned with our expectations due to the capital spending from the previous fiscal year, which has carried over into this year. We had good visibility into these results when we submitted our filings late last year. There’s also a temporary change in the annual effective tax rate that will correct itself by the end of the year. We were conservative with our operating and maintenance spending in the first half of the fiscal year, taking a cautious approach during the pandemic, especially regarding our commercial customers. However, their performance has exceeded our expectations. We have held back some of the operating and maintenance spending until we had a clearer understanding of when revenues would materialize. Now that the winter heating season has passed and we are looking ahead to the second half of the year, we plan to modestly increase our operating and maintenance spending. With the positive momentum from regulatory outcomes and improved commercial sales volumes as economic activity rises, along with our planned increases in spending, we feel confident that we’ll be at the upper end of our fiscal year range.

Okay. That's definitely helpful. Kevin, I have a broader strategic question. Coming off the recent sale of some gas utilities at impressive valuations, we’ve asked about M&A strategies before. You've mentioned the strong organic growth opportunities in most of your areas, which I appreciate. How do you weigh the market's valuation from recent transactions against your ongoing financing needs? At some point, does it make sense to consider these factors to determine the ideal portfolio mix for Atmos?

No. Good morning. I appreciate your question. Let's just start with the transaction that you're talking about there, and discussion around our assets. And again, as you heard Chris go through the financial updates, the performance for year-to-date, our historical performance, we remain very happy with our asset mix and our regulatory construct. And again, Insoo, as you know, we began to earn 90% of our investment in the first six months and 99% after 12 months. And we've talked about how that story is very simple, very straightforward and easy for our folks, investors, and all stakeholders to understand. And there are complications with these acquisitions as we go forward. That's why we like our plan that we have laid out today, the performance that our divisions execute on day in and day out. But I think this transaction sends a very strong signal right to the market. In our opinion, it sends a very strong message about the value of natural gas and the role it plays in meeting the energy needs going forward. The value of these assets that have been somewhat questioned over time should now be coming into clear focus. So I think it sends a very strong signal to everybody about the role that natural gas is playing and will continue to play going forward and the value of this infrastructure out there for its reliability, certainty, and affordability. I'm very happy to see that have occurred, but remain very, very positive with our regulatory construct and the performance of our assets.

Understood. Thank you so much.

Thank you. Our next question today is coming from Stephen Byrd from Morgan Stanley. Your line is now live.

Hey, good morning. Congrats on continued great performance.

Thank you.

I wanted to just discuss renewable natural gas a little bit more and maybe just at a high level get your thoughts on the kind of the overall magnitude of that potential in the longer term away from kind of very near term just thinking through how meaningful that might be? I know it's a broad question. Just interested in your longer-term take on that.

Yeah. I think as you've heard us say, we continue to grow the number of projects that we have out there under evaluation. We're up to 30 now, and it's a mixture of dairy as well as landfill gas. We've got a combination of those things we're looking at now. We're doing about 5.5 to 6 Bcf a year. That's a little north of the 2% range, I think, when you compare that to the average distribution sales volumes that we move across our system on an annual basis. I think we'll continue to see these projects come up, and with the help of some of these energy firms that are out there, I think we'll have a good opportunity to bring them on our system. But right now, to hang a number on it, I think it's still a little bit early. As I said, we're at the 2% of our overall distribution sales throughput volumes. I think there's opportunity there for us. But until we can get in and see what infrastructure may be required, how near our systems are, and whether that will require pipes or what's needed on the other side of that, through digesters or processing equipment, I think it's still a little bit premature on our side to try and hang a target or a number out there, where this could go. But we remain very optimistic about the opportunities that continue to come up.

No, that's fair. Great. And then maybe just – I wanted to dig in a little bit more on Texas and lessons learned from the winter storm. You all gave a very good and very thorough update on sort of everything going on in Texas. Again, kind of a longer-term question. Just interested in your take on sort of other changes that you see that would be needed in Texas whether that's operational changes, changes to contract structure? Just other things on your mind longer-term to ensure kind of we don't have a repeat of what happened in Texas?

No good question. And I think our team, as I pointed out in my earlier remarks, is continuing to evaluate things that occurred throughout that 12 to 14-day period there. We look at how we can improve our systems, things we can put on our systems to monitor supplies and additional supply diversification that we can bring on. So that's continuing to go on. But really those are things we do each year. The strength, as I pointed out in my prior remarks for us, is our planning process. Those projects I mentioned are already in our five-year plan and have been in our five-year plan to allow us to continue to fortify and grow, and think about where those next challenges could be. Just for example, again the storage piece of that. So as we develop those salt cabins, we're not only thinking about past performance but also about growth on the system as well. Other places to fortify are, whether it's APT infrastructure or distribution systems as well. So I think the ongoing evaluation of that performance continues, but I'm very proud of how our system performed through that, and we'll look for whether it's technology solutions or supply diversification again to help us through that. And the last thing I'll mention on that is around that supply diversification. You look at, I'll just use our APT asset as an example. When that supply stopped flowing in from the West from the Permian, we were able, through the network that we've been building and fortifying over the last 10 years, to pull from the North out of the Barnett, out of Oklahoma, we fortified that with additional supplies coming out of Carthage from the East. We had our fortifications in place where we could pull from Katy up from the South. All of those points helped us get through that situation during that storm, and we needed all of those and that versatility in the system to pull that and pull it at those levels, as well as the many suppliers we have across those areas to be able to bring those into those points. So I'm very proud of how we performed during that period and how our system continues to provide many options for us going forward.

That’s really great color. Thank you so much.

Thank you. Our next question today is coming from Ryan Levine from Citi. Your line is now live.

Hi, everybody. In terms of the salt-dome storage project that you highlighted in the Dallas region, could you speak to what additional development opportunities you have on salt-dome storage within your footprint more broadly?

Well, in our footprint, salt-dome is here in Texas. This is our third cabin here in Texas. Those are behind the APT system to meet the demands of its customer base and the firm needs there for human needs customers on the Mid-Tex system. So, our other storage fields, throughout our other properties are all traditional sandstone reservoirs. There are no salt-dome projects on or available in those other facilities. But we do have contract storage services that we use through our interstate supply contracts and with third-party sources as well to supplement our peaking capacity needs. And some of that may potentially be salt. Right now, most of that is generally sandstone reservoirs. So right now, we've taken a good hard look at this third cabin development here and see that being able to help us for the near to longer-term at this point.

Are there additional opportunities within your footprint on the salt-dome side, that you have the resource or commercial arrangements that you would be able to pursue, to the extent that it was needed?

No. Again, let's think about storage. Storage for us is there to supplement our peak day at our interstate capacity to meet those firm needs. The only opportunity for salt right now, as I said, is here in Texas. Our other opportunities are sandstone reservoirs. Those are near market, near our large customer bases. So we continue to use those other 15 fields to do exactly that. The only salt-dome available is here in Texas, and right now our third cavern development is the one we're focused on.

Okay. And then, in terms of the financing plan, I appreciate the update around the securitization proceedings in the different service territories. To the extent that the Senate and the Governor support the proposal in Texas, does that crystallize financing plans for 2021? And can you provide some color around how you're currently thinking about your equity needs, in light of evolving regulatory decision-making?

I will start, and Kevin can join in as well. If securitization is approved in Texas, we plan to participate in that program. This would clarify how we intend to use the $2.2 billion in long-term debt that we arranged in March. Regarding our financing plan, aside from the $2.2 billion, we will continue to fund our operations in a balanced way, utilizing a combination of long-term debt and equity. We do not expect to change this financing strategy, as it has been effective for us over the past decade and is well understood by our regulators and the investment community. We don't foresee any changes at this time.

So just a follow-up, to the extent that that were to happen, does that put off the table any additional equity financing needs beyond the forward agreements that and other programs you already have in place?

If we have the chance to join the securitization program in Texas and also securitize the costs in Kansas, we expect our financing strategy to remain in line with what we have previously done.

Thank you. Our next question is coming from Charles Fishman from Morningstar. Your line is now live.

Good morning. Kevin, assuming the securitization passes, we're also seeing signs of inflation across the economy that people are concerned about, which will make it more difficult to control your O&M costs, which you've certainly done a phenomenal job over the last years. Now, that certainly puts some pressure on rates and create some headroom issues because we obviously know it's important to keep rates at the general inflation or less. But does that put some pressure on that 7% to 8% CapEx growth there? How do you think about that? Because obviously that's the key to your earnings growth?

Yeah. You broke up there just a little bit, so let me see if I can answer your question here. I think when you look at the supply right now, the abundance of the supply and the pricing it's come back down to, today, Waha was in the 250 range or so. You look at the growth across our system, and our average bills right now are in that $49 to $50 range absent what we've gone through this past winter obviously. But I think, given those supply pricing and given the growth we have on our system, the signals we can send on our annual mechanisms right now, I think we're very comfortable with our costing and how we compare moving forward in terms of our O&M and compliance needs. And again, you've heard me talk before about our all-in cost, which again, assuming we get securitization spread out on these winter pricing events, at $5 to $5.50 right now, that equates to about $0.01 to $0.015 on a kilowatt rate. So I think we still remain very competitive out there compared to electric pricing on a go-forward basis for us as well.

Yes. I'm sorry for the interruption. Clearly, regulators evaluate the overall level of rate increases. The question I have is whether costs beyond your control, such as inflation and rising interest rates, will impact your targeted annual CapEx growth rate of 7% to 8% over the next five years.

I'm not anticipating any pressure at this point on our CapEx program. Again, we've modeled a lot of things going forward into our five-year plan. We continue to monitor the need for our projects and can pull things forward or push some things back. So, I think right now, given the layout we have for this year and the next few years going forward, I feel very comfortable with what we'll be able to execute upon.

I have a follow-up question. Earlier this week, I was intrigued when the utility in Phoenix expressed pride in the industrial growth in the area, noting it was second only to Dallas, which surprised me. I understand that the focus is on electricity while we are discussing gas, and that industrials make up a small percentage of your revenue, around 2%. However, in light of this industrial growth, are you noticing increased gas demand from specific chemical industries or any other factors that could significantly enhance your revenues from the industrial sector in the future?

Not that I would say would equate to an extra boost, if you will. I think we see, certainly as the vaccines have started to roll out, the economy to your point has started to pick back up. Things are opening back up. We see some of our industrial customers across the eight states getting back to what we would call pre-pandemic levels. Now, some of them stayed at that because they were associated with the specific needs of industries like the medical or metals industries that held steady. However, those that pulled back during that period have now started to pick back up and hit that normal pace. To your point, we continue to see new additions and expansions across our system. But I don't know that I would categorize it at this point as an extra boost. We're very proud to see the growth from an economic and a utilization of natural gas standpoint. And it seems to be a good diversified load from auto to the distilling industry to the metals industry. But we're very proud to see that, but nothing that's been unanticipated at this point.

Okay. That’s all I had. Thank you.

Thank you. We've reached the end of our question-and-answer session. I'd like to turn the floor back over to management for any further closing comments.

Thank you. We appreciate your interest in Atmos Energy, and thank you again for joining us. A recording of this call will be available for replay on our website through June 30 of 2021. Have a good day.