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Intrinsic Value is all-important and is the only logical way to evaluate the relative attractiveness of investments and businesses.
My name is Casey, and I will be your conference operator today. At this time, I would like to welcome everyone to the UGI Corporation and AmeriGas Partners Fiscal Second Quarter Earnings Call. [Operator Instructions] Mr. Ruthrauff, Director of Investor Relations, you may begin your conference.
Thanks, Casey. Good morning, everyone, and thank you for joining us. With me today are Hugh Gallagher, CFO of AmeriGas Propane; Kirk Oliver, CFO of UGI Corporation; Jerry Sheridan, President and CEO of AmeriGas Propane; and John Walsh, President and CEO of UGI.
Before we begin, let me remind you that our comments today will include certain forward-looking statements, which management believes to be reasonable as of today's date only. Actual results may differ significantly because of risks and uncertainties that are difficult to predict. Please read our earnings release and our annual report on Form 10-K for an extensive list of factors that could affect results. We assume no duty to update or revise forward-looking statements to reflect events or circumstances that are different from expectations.
We'll also describe our business using certain non-GAAP financial measures. Reconciliations of these measures to the comparable GAAP measures are available in the appendix of our presentation.
Now let me turn the call over to John.
Thanks, Will. Good morning, and welcome to our call. I hope that you've all had the opportunity to review our press releases reporting second quarter results and updated fiscal '18 guidance for UGI and AmeriGas.
We had a very strong Q2, achieving record EPS on both a GAAP and adjusted earnings basis. Each of our 4 businesses contributed higher adjusted net income than in Q2 fiscal '17. Weather was slightly warmer than normal in each of our domestic businesses and slightly colder than normal for UGI International. Our strong performance in the quarter reflects the positive impact of more normal winter weather in our domestic businesses, our lower effective tax rate following passes of the tax reform act and the continuing earnings contributions from our new investments and acquisitions.
I'll comment on noteworthy activities and market developments in Q2, then turn it over to Kirk, who'll provide you with a detailed overview of UGI's financial performance. Jerry will review Q2 for AmeriGas, and I'll then wrap up with an update on our strategic initiatives.
We're pleased to once again report record earnings for UGI. Our Q2 GAAP EPS was $1.57, and our adjusted EPS was $1.69. That adjusted Q2 EPS was 29% above our Q2 fiscal '17 adjusted EPS of $1.31, which at the time was the highest adjusted Q2 earnings reported in UGI's history. Both quarters have been adjusted for mark-to-market valuation of unsettled hedges and other items, which Kirk will cover later.
While our Q2 results clearly benefited from the impact of tax reform, our underlying business performance was extremely strong. EPS, excluding the positive tax impact, was up almost 15% over Q2 fiscal '17.
Now that we reported Q2, we're in a good position to update UGI's full year guidance for fiscal '18. On a year-to-date basis, our adjusted EPS is running over 20% above prior year. Based on this very strong performance, we're increasing our guidance to a range of $2.70 to $2.80. The midpoint of the updated guidance is almost 8% above the midpoint of our original fiscal '18 guidance of $2.45 to $2.65 and 20% above our fiscal '17 full year adjusted EPS of $2.29.
In addition to the strong earnings performance in the second quarter, it's important to note the progress we've made on a number of strategic projects and activities. Our teams, as always, maintained their focus on meeting our critical commitments to customers and the communities we serve, while also ensuring that our new capital projects and acquisitions meet or exceed their performance targets.
Some highlights for the quarter. With our first certificate in hand, the PennEast partnership team is now focused on local activities in both Pennsylvania and New Jersey. The partnership is working cooperatively with property owners and has attained survey permission for 97% of the route in Pennsylvania and 50% of the route in New Jersey. This project will provide critical new pipeline capacity and enhanced access to affordable Marcellus gas to residential customers in eastern Pennsylvania and across the State of New Jersey. We're working closely with governmental agencies in both states as we move through the detailed processes related to property surveys, land acquisitions and local permitting.
Our LNG facilities were extremely busy in Q2, particularly during the period of severe cold in early January. We made great use of our new Manning liquefaction facility, which came onstream last year. The LNG produced at Manning is being used to service our growing portfolio of peaking contracts and also positions us well to provide incremental LNG services to critical customers in New England.
Demand for LNG is very high as the combination of increased peak-day demand for most gas LDCs and ramping power generation demand strains the available pipeline capacity for many areas of the Mid-Atlantic region and all of New England. LNG has become an essential element of the supply portfolio in those regions, and our Manning investment was well-timed as the sector looks for incremental supply capacity.
We continue to grow our customer base at UGI Utilities as we add new customers along our mains and extend our mains to reach underserved towns across the Commonwealth. We've added over 86,000 new residential heating and commercial customers year-to-date, and demand for gas service continues to be very strong. UGI Utilities now serves almost 650,000 natural gas customers in Pennsylvania, an increase of approximately 50,000 customers over the past 5 years.
We continue to make great progress with our mission to replace and reinforce critical infrastructure across our system. Our infrastructure replacement program for cast iron and bare steel remains on pace.
AmeriGas had a very solid quarter, with adjusted EBITDA up 14% over Q2 fiscal '17. The team at AmeriGas did an outstanding job handling the variable weather conditions across the U.S. during the quarter as we moved LPG, assets and drivers to the areas where they were needed. Jerry will comment in much more detail on AmeriGas' Q2 performance in a few minutes.
UGI International had a strong quarter reflecting solid underlying performance across the business and the positive contributions from DVEP and UniverGas, 2 acquisitions made in late fiscal '17 and early fiscal '18. Adjusted income before tax was up approximately 5% versus Q2 fiscal '17. On a year-to-date basis, adjusted income before tax is roughly equivalent to the record earnings achieved by UGI International in the first half of fiscal '17. These 2 outstanding years back-to-back clearly demonstrate the resiliency and earnings power of UGI International.
I'll return later on the call to comment on our strategic initiatives, but I'd like to turn it over to Kirk at this point for the financial review. Kirk?
Thanks, John. Good morning, everybody on the phone. This table lays out our GAAP and adjusted earnings per share for this quarter compared to Q2 of last year. As you can see, adjusted results exclude the impact of mark-to-market changes and commodity hedging instruments, a loss of $0.08 this quarter versus $0.02 in the prior year. You can also see the integration expenses associated with the Finagaz acquisition, the unrealized losses on foreign currency hedges and the onetime tax impacts of the French finance bill and the Tax Cuts and Jobs Act.
Our adjusted earnings, $1.69 per share for the quarter, is up $0.38 from last year, largely due to weather that was relatively normal but significantly colder than the prior year, and the positive contributions from our recent capital projects and acquisitions. This quarter's results include a $0.19 positive benefit due to a lower federal income tax rate resulting from the Tax Cuts and Jobs Act, net of the negative impact of higher tax rates in France. Approximately half of this benefit for the quarter and the year-to-date is attributable to the utility.
As you can see, all of our businesses posted results that were higher than the prior year. In the case of Midstream & Marketing and UGI Utilities, adjusted EPS was up 54% and 38%, respectively, highlighting the positive impact of colder weather, the benefits of tax reform and the contributions from investments we have made over the past few years.
As mentioned, AmeriGas experienced weather that was approximately normal but 14% colder than the prior year. Retail volume was up 10%, driving total margin that was about $49 million above the prior year level. Adjusted EBITDA was $309 million for the quarter, representing an increase of $38 million or 14% versus the second quarter of last year. Jerry will spend some more time on AmeriGas in just a bit.
UGI International contributed $129 million in adjusted income before taxes, about a $6 million increase over last year. Retail volumes were up 25 million gallons or 10% driven by weather that was 6% colder than last year as well as incremental volume from the UniverGas acquisition in Italy that we completed last October. Total margin was up $61 million reflecting higher incremental margins in UniverGas as well as DVEP and stronger foreign currency exchange rates partially offset by slightly lower LPG unit margins. Operating and administrative expenses increased by about $40 million reflecting currency translation effects as well as $10 million of incremental expenses associated with the UniverGas and DVEP acquisitions. As a reminder, foreign currency fluctuations impact individual financial statement line items but are largely offset by our foreign exchange hedging. The gains and losses from hedging are recorded in other income and expense.
Midstream & Marketing income before taxes is up $24 million to $107.6 million for the quarter. Total margin was up $33 million reflecting higher capacity management, peaking, natural gas gathering margin as well as higher electric generation margin. These increases were driven by extremely cold weather that occurred early in the quarter, an increase in the number of peaking contracts and contributions from the Sunbury pipeline as well as the Texas Creek gathering assets we acquired in October.
Turning to Slide 13. Utilities is reporting income before taxes of $124 million, about $18 million higher than last year's quarter. As I mentioned earlier, utilities experienced weather that was about 11% colder than last year, which along with continued growth in our customer base, drove an increase in core market margin -- I'm sorry, core market throughput of about 15%. Total margin was up $30 million due to the higher throughput, higher PNG base rates that went into effect in October and higher large firm deliveries. Partially offsetting this weather-driven increase in margin were operating and administrative expenses that were up $8 million, primarily driven by higher accounts receivable reserves and compensation expenses, both driven by our increased revenues and volumes in the quarter.
This slide compares the first half of -- EPS results with the first half of results from 2013, the last time the company experienced relatively normal weather in all of its service territories. You can see that adjusted EPS, excluding the benefits from tax reform, has increased by $0.82 or more than 50%. With the benefits of tax reform included, adjusted EPS growth over the past 5 years is approximately 69%. This growth is due to the disciplined investment of UGI's capital into very attractive projects and the company's intense focus on operational efficiency.
That completes my prepared remarks, and I'll now turn the call over to Jerry for his report on AmeriGas.
Thanks, Kirk. AmeriGas finished the second quarter with adjusted EBITDA of $310 million, 14% ahead of the second quarter of last year. Weather in Q2 was essentially at 15-year normal and 14% colder than last year. It's certainly welcome development to see normalized weather during the critical winter earnings cycle.
Although the weather was basically normal for the quarter, there were some significant swings. As I noted on the Q1 call, January benefited significantly from the extreme cold temperatures in late December. January was 11% colder than the previous January, and volume was up 19% due to the lag between weather, customer orders and the delivery cycle. February, on the other hand, turned very warm, almost 10% warmer than normal. Mid- to late March returned to colder-than-normal weather, and this trend continued into April. Overall, volume for the quarter was up 10% over last year with 14% colder weather, so good relationship.
Propane costs has been relatively stable this quarter, though up from last year. Mont Belvieu cost for the quarter was $0.84 per gallon, up 19% from Q2 last year. And operating expenses in the quarter were up 5%, mostly related to delivery costs associated with a 10% greater volume in the quarter.
Finally, we are updating our guidance, principally due to the warm start in Q1 and warm weather again in February, to $625 million to $645 million of adjusted EBITDA for the year. At the midpoint of this range, EBITDA would be up 13% from fiscal 2017 on 12% colder weather.
Now turning to our growth trust. The AmeriGas Cylinder Exchange program saw a 15% increase in volume for the quarter as compared to Q2 last year, including a 6% increase in same-store sales. Our National Accounts program volume was up 18% due to both weather and new business, so a very strong quarter for both of these -- both platforms. We also closed one acquisition in April, and that's expected to add 3 million gallons annually.
Before moving on, I wanted to mention an upcoming accounting matter. As a result of the Heritage Propane acquisition in 2012, we acquired trade names that we intended to use across our newly expanded footprint. Now that we are more than 6 years removed from the Heritage acquisition, we previously disclosed our intent to complete a review of the operational value of these trade names during fiscal 2018. This work was just recently completed, and we concluded that these trade names, which previously had an indefinite life and were not subject to amortization, will now have a definite life of 3 to 5 years. And we will either eliminate or adopt co-branding strategies across the acquired trade names. During April, we recorded a noncash charge of approximately $70 million to adjust for the fair value of these trade names, given the shorter useful life. And this charge will be excluded from adjusted EBITDA.
These revalued trade names will be amortized over the next 3 to 5 years, as I mentioned, beginning in Q3. And while there's no cash flow impact as this is a noncash charge, I wanted to make you aware of it as an upcoming Q3 event. And it will also be disclosed in our upcoming 10-Q.
Finally, our Board of Directors recently approved the distribution of $0.95 per quarter, unchanged from the prior quarter. This is the time of year when we discuss the annual distribution actions with our board. And we recommended, and they approved, holding the distribution flat this year. We really believe this action, along with our significantly improved results, will go a long way as we seek to build distribution coverage following 2 warm years in 2016 and 2017. We expect to finish 2018 with improved leverage in the range of 4.3x and distribution coverage over 1x.
So thank you. That concludes my comment. I'll turn the call back over to John.
Thanks, Jerry. Before I review our strategic investment activities, I'd like to take a moment to comment on this slide. These side-by-side photos show, on the left, our Auburn Pipeline during the construction phase; and on the right, that same section of the Auburn line after the pipeline was put into service.
There is a significant amount of public discussion today around the need for new infrastructure and the challenges related to placing that new infrastructure into service. The commitment to responsible development is something UGI, and our colleagues in the sector, take very seriously. And the restoration of the Auburn line right of way is just one example of that commitment to responsible development.
As I mentioned in my earlier remarks, we were pleased to report record adjusted EPS for Q2 and increase our guidance for full year adjusted EPS. In addition to that earnings performance, there were several other noteworthy achievements in the quarter that will position us well for future earnings growth. UGI and many other East Coast LDCs experienced record natural gas demand during the first 2 weeks of January. Our peak-day sendouts were 7% to 14% above the record sendouts achieved during the Polar Vortex of 2014. This peak demand exceeded available pipeline capacity in the Mid-Atlantic and New England.
In light of this strong natural gas demand, we continue to see a significant need for new delivery capacity. We're pushing forward on multiple fronts to address this market need, which creates new investment opportunities for the company.
I commented on the status of PennEast earlier on the call. This is an important project for UGI and our partners, but it's only one portfolio of new UGI natural gas infrastructure investments.
We continue to expand our LNG network with a series of investments focused on meeting the rapidly escalating demand for peaking services. We've concluded the construction of the Steelton Pennsylvania LNG storage and vaporization unit, and our board has approved the construction of another new LNG storage and vaporization facility in Bethlehem, Pennsylvania. This project, representing an approximately $60 million investment, will add 2 million gallons of LNG storage to our network. It will enhance our ability to meet the rapidly growing demand for LNG and strengthen our ability to use our LNG system assets dynamically based on market conditions. There's very strong demand for LNG peaking services in the Mid-Atlantic and New England as LDCs and other large consumers seek supply solutions to ensure long-term access to natural gas delivery capacity.
Our investment outlook for utilities remains very strong. We're deploying record levels of capital to address infrastructure needs while growing our customer base. Our goal is to ensure continued access to low-cost natural gas for our core customers and provide access in previously unserved or underserved areas of the Commonwealth. As I noted on our last call, we plan to deploy upwards of $1.2 billion in capital at the utilities over the next 4 years.
The AmeriGas team is doing a great job of utilizing their scale and operational capabilities as the nation's largest propane distributor to drive growth into National Accounts and ACE Cylinder Exchange programs. As Jerry mentioned, volumes in the second quarter for our National Accounts customers were up 18%, while our ACE Cylinder Exchange volumes grew 15%.
We continue to be very pleased with the performance of our 2 most recent acquisitions in Europe: DVEP, the power and natural gas marketing unit in the Netherlands; and UniverGas, our initial investment in the Italian LPG market. I should also comment on the progress made on our integration activities in France related to our 2015 acquisition of Finagaz. Our integration program is now in the final stages. Our team in France has done an outstanding job of achieving all the critical integration and performance milestones for Finagaz. We're approaching the 3-year anniversary of that strategic investment, and we expect that our integration work will conclude on schedule this fiscal year.
As Kirk highlighted in his remarks, the combination of strong business unit operating performance and the beneficial impact of tax reform legislation drove excellent financial performance for the quarter and enhanced our full year outlook. As I mentioned at the beginning of the call, we are increasing our fiscal year adjusted EPS guidance range from $2.45 to $2.65 to a range of $2.70 to $2.80. This guidance reflects our strong operating performance over the first 2 quarters as well as the benefits of tax reform. And it excludes the impact of the noncash charge related to trade names in AmeriGas that Jerry discussed in his remarks.
We have great confidence in the ability of our teams to execute operationally and identify attractive growth investments that align with our business unit strategies. We're also excited about the long-term positive impact of the recent tax reform legislation. These changes benefit companies who consistently invest in growth opportunities and also reward companies that have been prudent in managing their balance sheet. UGI fits both of these descriptions, so these benefits are very meaningful for us.
Our new CFO, Ted Jastrzebski will be joining the company in about 3 weeks. And we look forward to introducing Ted to our investors over the course of the summer and fall.
Finally, I'd like to close off my remarks with a thank you to Kirk Oliver for his leadership and contributions to our success as our CFO over the past 5 years. We wish Kirk all the best in his new endeavors, and we're grateful for the opportunity we've had to work with him.
With that, I'll turn the call back over to Casey who will open it up for your questions. Casey?
[Operator Instructions] And your first question comes from Mirek Zak with Citigroup.
So I understand the relationship between weather and volumes isn't necessarily linear, but it seems volume didn't quite respond to the more normal winter weather than some might have expected. So I would just like to if -- you saw any other dynamics playing out during the quarter, maybe increased pricing competition with mom and pops or large players? Or any sort of increased level of customer attrition during the quarter?
No, no. The -- so it's been a pretty good year for us in terms of customer retention, number one. We did have moments of some shortage in parts of the country during parts of January, where we did do some short filling, where we just don't have enough propane to fill all the tanks. But that was really minor. I think the headline for the quarter really was February being 10% warmer than normal. It really caused the order pool to slow down quickly, and then of course, it responded around mid-March, got very strong again. So just as you saw the cold in late December help January, the warm in February affected the early part of March. But the cold March certainly gave us a great lead into April. So April's been an outstanding month for us as well.
And I'd just comment more broadly, because we look at both AmeriGas and UGI International. The patterns with regard to weather and the response of volumes to weather patterns, very similar in the U.S. and Europe. So when we compare kind of that weather and volume pattern in AmeriGas to say that same pattern in France, where we have a large business, very, very similar. You get that lag effect depending on -- so the timing of weather and volumes follow, but with a lag.
Okay, so considering the weather, you wouldn't necessarily consider this is a sort of a more normalized situation going forward.
It's normal across a period of time. But you also remember Q1, excluding the last week of December, was 7% warmer than normal. So we got off to a relatively warm start, had sudden and extreme cold. But really, when we look at a normal year, we're looking at not having these peaks and troughs that have been so significant this year. So that does affect things.
Is there a way you can quantify sort of what you think that -- the delta was due to these peaks and troughs?
As far as volume.
Yes.
Yes. So when you look at across the entire year, and if you -- for instance, this quarter, we're looking at weather that's 14% colder and volume, up 10%. And not all of our business is weather-sensitive, so you don't expect it to be 1:1. We've got a lot of commercial business, restaurants and so forth, forklifts that really don't care about the weather. So having that relationship year-over-year is really something that's quite normal, that you have that kind of 70% of the weather effect.
Okay. And just one more quick one. On the Cylinder Exchange business, what's the typical capital investment you make to operate that business in a typical year, sort of excluding what's associated with growing the business? And is that seen in your maintenance expense?
This is Hugh. It's in maintenance and growth. We don't disclose capital separately by type of business. But it -- half of the -- half of ACE's Cylinder Exchange business is maintenance capital, half is growth. But we don't disclose the details.
[Operator Instructions] Your next question comes from Ben Brownlow with Raymond James.
Just to kind of dovetail on the last question. I guess to approach it from a slightly different angle, on the guide down for the year, was that entirely volume-driven? Or can you provide any color around kind of the unit margins in the OpEx versus what your internal expectations were?
Total volume expenses have been tracking very well. In fact, we've had some callback opportunities in the back half of the year. But really, February is just such an important month to our year. And for that not to come through -- we probably could have made up what we lost in Q1, but February was a bit of a problem. But -- midpoint of our guidance, down 5%, and you have a critical month that came in 10% warmer than normal.
Yes. When you look at the critical metrics, unit margins or EBITDA per delivered gallon, the business is performing very well. So the underlying metrics that would capture sort of commercial effectiveness and operational effectiveness in the business are trending in the right direction. So it's volume-related.
Our EBITDA per gallon is the highest it's been since we've acquired Heritage, both quarter and year-to-date.
And how do we think about the distribution coverage ratio and obviously very seasonally high, but on a trailing 4-quarter basis, just below 1x. And winter tends -- obviously, extremely volatile, not ideal, but definitely colder year-over-year, closer to this sort of norm. Can you walk us through the high-level steps to improving the coverage ratio? Is it just getting an ideal weather pattern? Or how should we think about that on a go-forward basis? Obviously, maintaining the distribution at its current level is one step.
Yes. We -- there's no suggestion that we're not going to keep it at the current level. But we -- I think we watch the rating agencies, and Moody's has had us on a negative watch. And we're very sensitive to all the constituencies, so we're going to spend a little time building back to where we like to be, which is 1:1 to 1:2. This year will be a great step forward. Next year, we do see more normalized weather on a ratable basis instead of extremes. We should be back completely and might be in a position to increase the distribution next year.
And we're confident, as we look over at the last 2 quarters of the year, obviously, they're lower-activity-level quarters. But if you look at our guidance for the year, the updated guidance for AmeriGas, and if you look at what we're predicting or forecasting for the balance of the year, it's actually quite a strong 2 quarters of performance that's driven by growth in some of the core sectors we talked about, like ACE and National Accounts, but also driven by operational efficiencies and improved performance there. So as we drive operational efficiencies and grow those specific segments, obviously, the underlying performance of the business improves, which puts us in a great position moving into FY '19 when you look at overall business performance. It gives us a lot of confidence in terms of distribution coverage as well.
And I guess one just last follow-up. You commented -- made a comment around kind of late-March demand. Any insight into how propane sales were in April?
Yes, April was a -- it was a record -- close to a record month for volume. It was about 20% higher than last year, so very strong. Q3 is really shaping up nicely.
Your final question today comes from Chris Sighinolfi with Jefferies.
Jerry, I just wanted to -- have a couple of questions first to ask for you. With regard to the trademark commentary you were offering before, I just wanted to make sure I'm understanding that correctly. That's just an accounting -- change in your accounting practices. But do you still intend to use those trade names in all the regions?
Yes. We're going -- believe it or not, we have 100 brands across the country, and that is kind of an expensive way to do business. You've got to have your websites, all the things that you've got to -- call it marketing collateral. So we've reviewed it with our operating folks in the field, concluded there's around 15 brands that are -- have really high local value. So we'll begin to co-brand them. And slowly over time, the rest will be co-branded and then slowly removed. But the whole event is completely operational, total noncash charge. It's just something that was hung up on the balance sheet 6 years ago, that we now are going to take away because the value's diminished.
Right. Okay. But there is that practice of, I guess, now streamlining the numbers of brand names under which AmeriGas operates. And that'll be true when you make acquisitions from here as well, likely? Just do a market study on how valuable they are in the region?
Yes, yes. I wouldn't say that we'll never acquire a company and leave the brand alone ever again. But our bias will be toward keeping everything AmeriGas as best we can and continue to improve the digital experience that the customer has.
Yes. I think that last part is really critical. As we communicate a lot more in new ways and enhance our communication with customers, particularly using digital tools, it's really helpful if we can align on a branding approach so that this is reflecting that sort of acceleration of that activity.
So longer term, I would imagine, this is a lot more than efficient. There will be some efficiency gains putting them into a streamlined trademark-branded product. But is there an uptick in costs we should expect, Jerry, as you sort of do away with that and co-brand. Like you said, do you have signage costs that are very meaningful in any way or something that akin to that?
Nothing material. I mean, we replace signs all the time anyway. So this is not going to be a massive undertaking.
Okay. Perfect. And then I guess if I could just switch gears. John, I was interested in your comments. It's something we've thought a lot about. As PennEast and other regional pipelines have encountered, seems to be an intensification of the opposition to them. Is this whole notion -- if we go back a couple of years ago, you would talk and Lon would talk about the infrastructure gap that exists between the production fields of Pennsylvania and the demand sources to the east and north? And that your marketing and midstream business is positioned to take advantage of that. The dislocations that happened, straddling that infrastructure gap, that, that it was also actively working to bridge that gap with new infrastructure. And so the peaking demand that you talked about and the appetite for LNG peaking, I was interested in the new Bethlehem plant. But I guess a broader question is, how does the regulator think about that? I look at the UGI utility throughput, and you had mentioned in your release that the heating [indiscernible] were pretty smart at 2013. I went back and looked, they were within 5%. But your load was up about 30% over that time period. So how does the -- I guess how does the state regulator think about the fact that -- maybe it's not a Pennsylvania question. Maybe it's a question beyond that. But think about this infrastructure gap, in fact, may be getting worse before it gets better.
Yes. I think that's a major concern. Certainly within the state, we're fortunate for most of Pennsylvania, you have pretty ready access to the Marcellus resources. So our utility and others are sourcing the vast majority, upwards of 90% -- 90%, 95% of your natural gas is coming from the Marcellus. So Pennsylvania's pretty well-placed, and it's all about being efficient. And that's where peaking comes in. Peaking is a very efficient solution to provide that access. I think if you're east or northeast of Pennsylvania, you're -- there are significant challenges that we, as a supplier can see, because we're not unique in the type of demand ramp that you described, Chris. Most utilities are seeing core customer demand ramping up as they add new customers. And many utilities, including us, are serving new gas-fired power generation facilities that have been built over the last 5 to 7 years. So that demand continues to rise. And what's happening on the infrastructures side is, as you noted, projects are slowing down. Some are being canceled. Many are slowing down, which then creates a bigger gap, which is a challenge for all utilities and for us, creates opportunities for investment, like the LNG investment. What it also does is create incremental demand on some existing systems we have as producers and others look for pipeline capacity to move product to market. And if they have fewer options, then they'll tend to come back and utilize some existing paths to market, which creates opportunities for us to expand our systems, such as Auburn. And it certainly provides us with opportunities to expand our LNG network, because that demand is high for peaking services and also just provision of LNG across the region, Mid-Atlantic and New England.
Okay. And I guess we saw the original Temple build, and then we saw Manning a bit mured by Steelton regas. Now we're adding liquefaction in Bethlehem. Should we think about there being another regas opportunity at some point, somewhere on the system that's tight?
No. Bethlehem is storage and vaporization. So Bethlehem is kind of a twin to Steelton. So that's a site where we can store, vaporize and inject to directly serve demand, which for us is a critical commitment we have, in this case, to UGI Utilities to serve their customers with -- provide that peaking service that they'll use to serve their customers. But also, it provides to the midstream marketing team another significant asset that can be utilized during periods of sort of peak activity and volatility to create value across the system. Because we can vaporize and inject on a local basis and free up pipeline capacity that can be utilized on those cold days to deliver gas to constrained areas. And certainly, we saw a significant amount of that this quarter. In the very beginning of the quarter, there was significant volatility. So the ability to move gas east and northeast on those days was quite valuable.
Okay. My mistake. I guess, final question for me is just with regard to the dividend, historically, you guys have had a very static payout ratio guidance range in terms of how the dividend policy works. And I guess I'm just curious, given the new guidance range, midpoint of $2.75, and what you'll end up paying this year with the raise you just announced, sort of puts us at that low end of the 35% to 45% ratio. So I'm just curious as the board considers -- you've done punctuated step-ups in the past. Just what are some of the other factors we should be thinking about that the board might be considering, I guess, as it comes to future dividend declarations and the potential for another punctuated step-up?
Sure. Yes, as you point out, Chris, we have that kind of dual-element approach in terms of dividend policy. We state what our target is, it's [indiscernible]. But as we level through that range, we then look at making sure we're roughly in that range of 35% to 45% with the new guidance. And the increased dividend, we'd be somewhere around 38%, so we're coming down, which is a good thing. So we'd certainly keep those 2 factors in mind moving forward. As you look historically, we -- our average over a, say, a 5- or 10- or 15-year period is higher. It's depending on which period it is. It's 6% or 7% is our long-term average for dividend increases because of that -- those periodic increases that we make to keep us within that rough range that we use. I think one consideration as we think about the dividend policy was, the tax reform act was clearly beneficial and evident when you look at our earnings -- the earnings impact. The cash impact will be positive for us, but the positive cash impact of the tax reform act is deferred. So it's really 2 years until we see material positive cash impact based on the tax reform act, just based on some of the intricacies of that. But when it turns positive, it's materially positive. It's roughly somewhere in the neighborhood of $25 million to $30 million of incremental cash that we'll see. But as I said, that's deferred for a couple of years. It's neutral in the interim, neutral from a cash basis in the interim.
Best of luck, Kirk, on your next endeavors. It's been a pleasure working with you.
Thanks, Chris. I appreciate that.
And I will now turn the call back over to Mr. John Walsh for closing remarks.
Okay. Thank you, Casey. And thank you, everyone, for your time and attention this morning. And we look forward to keeping you updated on progress and speaking with you on our next call. Thank you.
And ladies and gentlemen, this concludes today's conference call. You may now disconnect.