Dorian LPG - Earnings Call - Q4 2025

Executive Summary

• Q4 FY25 revenue and earnings significantly contracted year over year and missed Wall Street consensus: revenue $75.9M vs $79.0M consensus; adjusted EPS $0.25 vs $0.45; adjusted EBITDA $36.6M vs $40.4M, driven by lower spot rates and a heavy drydock schedule, partly offset by lower bunker costs. EPS, revenue, and EBITDA consensus from S&P Global; values marked with * are from S&P Global.
• Sequentially, results softened vs Q3 on revenue ($80.7M → $75.9M) and adjusted EBITDA ($45.2M → $36.6M) as the quarter absorbed weaker February freight and drydock OpEx.
• Forward indicators improved: management has fixed ~79% of June-quarter pool days at roughly $42,000/day and highlighted constructive 2025 supply-demand with limited newbuild deliveries and rising ton-miles from trade re-routing amid tariffs.
• Capital returns continue but moderated: irregular dividend of $0.50/sh in May (down from $0.70 in Feb), reflecting balanced capital allocation given drydock cadence and market volatility; Board decisions are dynamic with improving rate outlook into June-quarter noted on the call.

What Went Well and What Went Wrong

• What Went Well

  • Forward bookings and rate setup into June-quarter: “we have fixed 79% of the pool’s available days in the quarter at a TCE of roughly $42,000 per day,” signaling a better near-term pricing environment.
  • Liquidity and leverage: cash of ~$317M at March 31; debt ~$557.4M; debt-to-cap 34.8% and net debt-to-cap ~15%, supporting flexibility for dividends, debt amortization, and vessel progress payments.
  • Strategic optionality and efficiency: ongoing installation of energy-saving devices; 16 scrubber-fitted and 4 dual-fuel LPG vessels; second vessel upgraded to carry ammonia (third planned in 4QCY25), enhancing commercial optionality as ammonia markets develop.

• What Went Wrong

  • Freight rate pressure and TCE decline: fleet TCE fell 44% YoY to $35,324/day as spot rates were weaker in February; Baltic benchmark averaged $51,715 vs $68,429 YoY; revenue fell 46% YoY.
  • Cost headwinds from drydocking: daily OpEx rose to $12,671 including ~$1,017/day non-capitalizable drydock costs; non-capitalizable drydock OpEx totaled ~$3.2M in the quarter, pressuring margins.
  • Derivatives swung negative: unrealized loss of ~$2.6M vs prior-year gain, reducing adjusted results; realized derivative gains also fell YoY.

Transcript

Operator (participant)

Good morning and welcome to the Dorian LPG Fourth Quarter and Full Year 2025 Earnings Conference Call. At this time, all participants are in a listen-only mode. A brief question-and-answer session will follow the formal presentation. As a reminder, this conference is being recorded. Additionally, a live audio webcast of today's conference call is available on Dorian LPG's website, which is www.dorianlpg.com. I would now like to turn the conference over to Ted Young, Chief Financial Officer. Thank you, Mr. Young. Please go ahead.

Ted Young (CFO and Treasurer)

Thank you, Nikki. Good morning, everyone, and thank you all for joining us for our Fourth Quarter 2025 Results Conference Call. With me today are John Hadjipateras, Chairman, President, and CEO of Dorian LPG Limited., John Lycouris, Head of Energy Transition, and Tim Hansen, Chief Commercial Officer. As a reminder, this conference call webcast and a replay of this call will be available through May 29, 2025. Many of our remarks today contain forward-looking statements based on current expectations. These statements may often be identified with words such as expect, anticipate, believe, or similar indications of future expectations. Although we believe that such forward-looking statements are reasonable, we cannot assure you that any forward-looking statements will prove to be correct. These forward-looking statements are subject to known and unknown risks and uncertainties and other factors, as well as general economic conditions.

Should one or more of these risks or uncertainties materialize, or should underlying assumptions or estimates prove to be incorrect, actual results may vary materially from those we express today. Additionally, let me refer you to our unaudited results for the quarterly and annual periods ended March 31, 2025, that were filed this morning on Form 8-K. In addition, please refer to our previous filings on Forms 10-K and 10-Q, where you'll find risk factors that could cause the actual results to differ materially from those forward-looking statements. Also, please note that we expect to file our full 10-K no later than May 30th, 2025. Finally, I'd encourage you to review the investor highlights slides posted this morning on our website. With that, I'll turn over the call to John Hadjipateras.

John Hadjipateras (Chairman, CEO and President)

Good morning and thank you for joining us. My colleagues, Ted, John, and Tim, will provide you with detailed comments on our financial results, our sustainability and operational progress, and our market outlook. First, I'd like to highlight the following. Our dividend of $0.50 per share, totaling $21.3 million, reflects our commitment to returning capital to shareholders in a manner that's aligned with market conditions and our policy of distributing earnings prudently. This past fiscal year, we paid over $155 million in dividends. So far, in 2025, freight rate movements have been dramatic. While traders grappled with the tariff announcements and the fact that for a time it became uneconomic to export U.S. LPG to China, the market quickly assessed the ability of the Middle East and Canada to replace U.S. tons.

Through this, U.S. exports remained strong, with more than 300 VLGCs loading more than 14 million tons in the last quarter. US LPG specifications are particularly attractive for Chinese PDH plants. As you will hear from Tim, we believe that increased production in the US and the Middle East and U.S. terminal expansion, combined with just nine new buildings for the rest of the year, will support a balanced freight market and healthy earnings for 2025. We are confident in the long-term fundamentals of LPG demand, which are underpinned by growing petrochemical and residential consumption, particularly in Asia, and by infrastructure expansions in the U.S., which will support steady growth in NGL output. Moving to the operational side of our business, we are progressing our investments in quick payback energy-saving devices and performance optimization. We have eight dry dockings planned for this year. John L.

will provide an update on our initiatives and our decision to convert some of our VLGCs to facilitate the carriage of ammonia. I would like to pass it over to our CFO, Ted Young, for our quarterly financial overview.

Ted Young (CFO and Treasurer)

Thanks, John. My comments this morning will focus on capital allocation, our financial position on liquidity, and our unaudited fourth quarter results. At March 31, 2025, we reported $317 million free cash, which was sequentially up from the previous quarter. Cash flow from operations more than doubled from $24 million to $50.3 million quarter-over-quarter, and we generated $10 million from the maturity of some bond holdings, all of which gave us enough cash flow to support our dividend, a progress payment on our new building made in January, and our quarterly debt amortization. Thus, in spite of significant outflows, we still managed a modest increase in cash. As disclosed two weeks ago, we will pay an irregular dividend of $0.50 per share, or roughly $21 million in total, on or about May 30, 2025, to shareholders of record as of May 16.

Including this dividend, we have returned approximately $875 million in cash through dividends, a self-tender offer, and open market repurchases since our IPO. With a debt balance at quarter end of $557.4 million, our debt-to-total book capitalization stood at 34.8% and net debt-to-total capitalization at 15%. We have well-structured and attractively priced debt capital with a current all-in cost of about 5.1%, an undrawn $50 million revolver, and one debt-free vessel. Coupled with our strong free cash balance, we have a comfortable measure of financial flexibility. Looking ahead, we expect our cash cost per day for the coming year to be approximately $26,000 per day, excluding capital expenditures for dry docking and progress payments on our new building. For the discussion of our fourth quarter results, you may also find it useful to refer to the investor highlights slides posted this morning on our website.

I would also remind you that my remarks will include a number of terms such as TCE, available days, and adjusted EBITDA. Please refer to our filings for the definitions of those terms. Looking at our fourth quarter chartering results, given the fact that our entire spot trading program is conducted through the Helios pool, its reported spot results are the best measure of our spot chartering performance. For the March 31 quarter, the Helios pool earned a TCE per day for its spot and COA voyage of $29,800, reflecting the more challenging LPG product environment during the quarter, which Tim will get into more in his remarks. Our available days were also affected by a relatively heavy dry docking schedule. The overall TCE result for the pool of $33,200 per day reflects the strong time charter out portfolio in the pool.

On page four of our investor highlights material, you can see that we have three Dorian vessels on time charter within the pool, indicating spot exposure of just over 89% for the 28 vessels in the Helios pool. Dorian's reported TCE revenue for available day was about $35,300 per day. This rate was marginally lower than the prior quarter's results, again reflecting the challenging LPG product market. However, forward bookings for the quarter ending June 30, 2025, are more promising. We currently estimate that we have fixed 79% of the pool's available days in the quarter at a TCE of roughly $42,000 per day. The rate includes both spot fixtures and time charters in the Helios pool.

Given the difficulty in predicting loading rates, which obviously have a huge effect on revenue recognition, disport options in some charters, and the fact that some of our COAs are priced on average Baltic rates, the estimates we quote during these calls and the rates actually realized can vary. Daily OpEx for the quarter was $11,000 a day, excluding dry docking-related expenses, which was up from the prior quarter. Crew and spare and stores costs were both up. This quarter also saw nearly $1,000 a day difference between reported OpEx that includes expense dry docking amounts and our preferred measure of OpEx that excludes those costs. Those non-capitalized dry docking expenses totaled about $3.2 million and equated to $0.07 per share for the quarter. Our time charter in expense for the four time charter in vessels came in at about $10.3 million, or about $28,600 per time charter in day.

Thus, those vessels contributed positively to our quarterly profits. Total G&A for the quarter was $8.3 million, and cash G&A, which is G&A excluding non-cash compensation expense, was about $6.8 million. This amount contained about $800,000 of statutory accruals, which puts our core G&A at around $6 million, more in line with our typical levels. That $800,000 was worth about $0.02 per share. Our reported adjusted EBITDA for the quarter was $36.6 million. Total cash interest expense for the quarter was $6.7 million, which is down sequentially from the prior quarter. Note that we capitalized approximately $425,000 of interest related to our new building during the quarter. Principal amortization remained steady at around $13 million. For the current fiscal year ending March 2026, we expect to dry dock eight of our vessels, for which we have budgeted approximately $12 million, excluding off-hire time.

Days in dry dock should be consistent with our disclosures, namely around 25 days per vessel. Also, we have two progress payments on our new building in September and December 2025, each of roughly $12 million. The irregular dividend declared at the beginning of the month of $0.50 per share brings to $15.70 per share in irregular dividends that we have paid since September 2021. The modest reduction of the dividend versus the prior quarter is consistent with our previous discussions around the topic. It reflects a balanced mix between results and the long-term needs and prospects of the business. Obviously, recent rate gyrations underscore the range of variables that affect our business, whether terminaling fees, global petrochemical demand, and global trade policies, just to name a few.

Including the irregular dividend to be paid this month, we've paid over $640 million of dividends and have generated net income of $641 million over the same time period, i.e., back to June 30, 2021. Our board weighs current earnings, our current near-term cash forecast, future investment needs, and the overall market environment among a number of factors in making its determination of the appropriate level, if any, for our dividends. The $0.50 per share dividend reflects a constructive market view when considering last quarter's earnings and our heavy dry dock schedule this past year and for the coming year. In addition, the dividend decision was made before the conclusion of the most recent U.S.-China trade talks. We continue to be on the lookout for fleet renewal opportunities and will be judicious with our free cash flow, working to balance shareholder distributions, debt reduction, and fleet investment.

With that, I'll pass it over to Tim Hansen.

Tim Hansen (Chief Commercial Officer and Director)

Thank you, Ted, and good day, everyone. At the start of the quarter ending March 31st, the trade market kept its momentum from last December. Activity remained strong in the east, with the Indian PSU actively covering January requirements. In the west, charters quickly returned post-holidays to secure first-half February liftings out of the U.S. Gulf at rates in the low 110s on the BLPGs. Three routes used into Chiba, which equals some TCEs in the mid to high 40s that day. The rates trended upwards at the end of 2024, and the typical winter spike was yet to materialize. Thus, there were expectations of further gains. However, in the second week of January, a cold spell in the U.S. Gulf caused charters to pause forward fixing, being aware of disruptions such as a Texas freeze in prior years and recent terminal delays experienced last summer.

Sudden tightening in the Panama Canal, with options fees spiking to $500,000, added to further strain on the voyage planning. Repeated cold spells in the U.S. drove up domestic LPG demand, leading to a rise in the Mont Belvieu LPG price. In the meantime, seasonally warm weather and subdued petrochemical demand in Asia narrowed the arbitrage, tightening the terminal fees and freight rates. With no spot activity, rates began to soften on sentiment. With February exports down with about $1 million worldwide, with $300,000 in the east and about $700,000 out of the U.S., and no U.S. spot activity for the second-half February liftings. Thus, you mentioned uncertain Panama transit costs. More owners started to ballast from Asia towards the Middle East Gulf or via Cape to the U.S. Gulf, putting pressure on the Middle East Gulf rates and increasing vessels availability.

Due to limited US activity, vessels availability gradually increased and freight rate continued to decline. By mid-February, earnings on a modern non-scrubber vessel had dropped from the high $40,000 a day in early January to low $20,000 a day in both the east and west market. Activity eventually resumed, stabilizing the rates at these levels before recovery began in early March. As certain fixtures by mid-March, driven by a tightening position list, led to a sharp rebound and ending the quarter with earnings back in the mid to high $40,000 per day range. The quarterly average spot earnings were settled around $30,000 a day, reflecting a balanced market. This was despite the absence of a typical winter demand in the east in both Q4 and Q1.

The U.S. cold snaps, as mentioned, February export dip elevated feedstock costs wailing on PDH and petrochemical margins and a narrow arbitrage, plus a high oil and gas market volatility amidst the tariff announcement by the U.S. administration. Reciprocal tariffs by China announced in Q1 2025 did not initially include LPG imports from the U.S. to China, but spurred a caution as by charters for committing too far ahead with the ever-changing tariff announcement and the possibility of China including LPG in the reciprocal tariffs again. U.S. LPG production hit another quarterly record in the first quarter of 2025, producing 500,000 tons above the previous quarter. Despite U.S. LPG exports falling from 5.6 million tons in January to 4.9 in February, the quarterly exports have shown to be the highest on record for Q1, and it is the third highest on record per quarter overall.

In addition to the first quarter updates, by early April, the trade war continued to escalate. China included LPG and ethane in the reciprocal tariffs. This caused a huge shock to the LPG market, causing freight rates to collapse from approximately $40,000 a day down to OpEx level virtually overnight. Two traders relit their vessels at roughly $40 per ton below the last ton levels on the Houston-Chiba route, reflecting the expectation of immediate market disruptions. However, within a week, the market stabilized and freight rate rebounded to a more sustainable level, although still below the highs seen at the end of the first quarter. While a steep rise in tariffs effectively prevented direct LPG trade from U.S. to China, the market anticipated a repeat of the 2019 trade war pattern, with China sourcing replacement volumes from alternative origins.

Although substituting the entire Chinese to U.S. originated volumes would be difficult and could cause some demand destruction, the shift in trade lanes happened quickly and led to inefficiencies and increased ton-mile demand, as also seen in the previous trade war. This time, to a larger extent, due to the large volumes to be substituted and the limitations of such available alternative volumes. The Mont Belvieu prices declined rapidly along other energy markets, making U.S. LPG increasingly competitive as an after-substitute for non-Chinese PDH units and for steam crackers. This shift supported demand outside China, while the concerns being that the Chinese PDH demand destruction might lead to rising U.S. inventories, especially in a post-winter period. The improved price competitiveness of U.S. LPG helped sustain export flows. The key question was whether the increased ton-mile demand elsewhere would be sufficient to offset the loss in Chinese volume.

In the short term, it did. This dynamic was quickly overtaken by development in the U.S. to China trade policy. Tariffs were temporarily reduced, at least from the critical levels of 245 and 225, respectively, for a 90-day period, with a 10% Chinese import tax on U.S. LPG production. Notably, even this lower tariff level was enough to alter the trade floats in 2019. Today, we have a high Saudi CP price and a low value price, which suggests that U.S. cargoes may remain competitive on a landed price basis into China despite the tax. As negotiation continues, the market has regained balance and has been trending upwards since the tariff reduction. While the potential impact of future trade tensions remains uncertain, we are positive in our outlook for the market in 2025.

U.S. production and exports are set to increase, supported by terminal capacity expansions scheduled in the second half of the year, alongside Asia continuing to drive growth with new PDH plants coming online in China and sustained competitiveness of propane and butane versus naphtha in both east and west, increasing the overall demand. Additional support comes from a Panama Canal at the moment operating at maximum efficiency. Thus, a limited downside and limited new building deliveries, as mentioned by John in 2025. This contributes to a favorable supply-demand balance. With that, I'll pass over to Mr. John Lycouris.

John Lycouris (Head of Energy Transition)

Thank you, Tim. At Dorian LPG, we are committed to continuously improving energy efficiency and advancing the sustainability of our operations and our vessels. We maintain a daily focus on optimizing vessel operational efficiency, whether underway or in port, while continuously incorporating insights from our crew. To ensure comprehensive performance monitoring, we leverage both proprietary tools and third-party platforms to assess the efficiency of the hull, main engine, auxiliary engines, boilers, and the integrity of data quality. Hull performance is assessed by monitoring frictional resistance with careful consideration of trim and speed optimization. We consistently monitor and clean the hull and propeller to optimize performance and minimize overall fuel consumption. We conduct regular monitoring of the main engine, auxiliary engines, and boiler, focusing on performance metrics such as utilization, power loads, and lubrication efficiency.

Our scrubber vessel savings for the first quarter of 2025 amounted to $1,370,000, or about $1,174 per calendar day per vessel, net of all scrubber operating expenses. Fuel differentials between high sulfur fuel oil and very low sulfur fuel oil averaged $67 per metric ton, while the differential of LPG as fuel versus the very low sulfur fuel oil stood at about $93 per metric ton, making LPG economically attractive for our dual-fuel vessels. We now operate 16 scrubber-fitted vessels and four dual-fuel LPG vessels. We have now completed the second VLGC vessel upgrade to carry ammonia cargo, and a third vessel is planned to be upgraded during its dry docking in the fourth quarter of 2025. Once this last vessel is completed, four VLGC vessels in our Dorian LPG fleet will be able to carry ammonia cargos in addition to our newbuilding VLGC VLAC vessel delivering in 2026.

We believe that the cargo fitness upgrades to include the ammonia cargo capability enhance the fleet's commercial optionality and readiness for employment when the first ammonia projects develop and when the large ammonia cargo markets are established. At MEPC 83 during April 2025, member states finalized and approved the draft legal text for the IMO Net Zero Framework as part of the IMO's midterm greenhouse gas reduction measures to be added as a new Chapter 5 to MARPOL Annex VI.

Key features include: one, a mandatory well-to-wake greenhouse gas fuel intensity standard, which is called GFI, effective 1st January of 2028. Two, two compliance tiers, a base and a direct, with annual tightening reduction factors through 2035. Three, remedial units at $100 per ton for every CO2 equivalent unit and $380 per ton for each carbon CO2 equivalent unit, tier two, for compliance shortfalls payable into the IMO Net Zero Fund. Credits, that's number four, credits of overcompliance aiming to accelerate zero and near-zero carbon fuel uptake. Detailed implementation and verification guidelines for the IMO Net Zero Framework are due to be finalized in mid-2025 ahead of formal adoption at the extraordinary MEPC session to be scheduled in October 2025.

The IMO committee also adopted resolution MEPC 400, which sets out annual CII reduction factors relative to the 2019 reference line at 13.58% in 2027, increasing incrementally by 2.58% each year to reach 21.5% in 2030 compared to the 2019 reference. Our continued focus on energy and emission savings reflects our belief that our environmental responsibility aligns with long-term value creation for our shareholders. I would like to pass it over to John Hadjipateras for final comments.

John Hadjipateras (Chairman, CEO and President)

Thank you all. Thank you, John, Tim, and Ted. Nikki, we can open up for questions.

Operator (participant)

At this time, if you would like to ask a question, please press the star and one on your telephone keypad. You may withdraw your question by pressing star two. Once again, to ask a question, please press the star and one on your telephone keypad. We'll take our first question from Omar Nokta with Jefferies. Please go ahead. Your line is open.

Omar Nokta (Managing Director)

Thank you. Hey, guys. Good morning. I wanted to just ask a bit about the volatility that we've been seeing in the VLGC market. Obviously, there's always volatility. It just seems to be much more extreme, perhaps, recently. One thing is clearly the spot rates have exceeded many expectations. Right now, we're covering over $50,000 a day, it seems, on the spot market. Ted, you mentioned you booked 79% of the quarter at $42,000. It seems that the rates are basically much stronger than anticipated. Could you maybe, I know Tim, you talked about this a little bit, could you talk about what's driving this market strength here recently? Is this sort of, are there any kind of trade pattern changes that have evolved out of what happened in April between China and the U.S.?

Could you just give a bit more context as to what's driving this latest upswing? Thank you.

John Hadjipateras (Chairman, CEO and President)

Yeah. Thank you. Thanks for the question, Omar. I think Ted, I mean, sorry, I think Tim is best positioned to answer you this. He's on the front line, and obviously, it's something on everybody's mind. Tim, can you take it, please?

Tim Hansen (Chief Commercial Officer and Director)

Yeah. Omar, as you said, it has gone up quite a lot lately. I mean, we see that tightening instead, we still see these trade flows that altered when the high tariffs were in place and China put on the retaliatory tariffs. We are still seeing a lot of cargoes going from the U.S. to India and to Southeast Asia. That, of course, gives a lot of ton miles. I think it is still a balance between whether it makes sense to swap the tons and with the 10% tax, whether it makes sense to use U.S. origins into China or whether it is better to take and supplement out of AG. There does not seem to be demand destruction, but some of the cargoes are still going the longer route around the Cape to Southeast Asia and to India, particularly.

That also means that you have more ton miles out of the AG when they go to China, which would normally go, for example, to India. On top of that, I mean, the production is still very strong, and we have, before we talked about tariffs, expected a strong year of 2025, which has seemed to be a little bit forgotten in all the noise on the tariff trade. We have, I mean, 2025 was predicted to be relatively tight compared to 2024 with the limited new building deliveries. You can say that the previous little jump in new building deliveries has been absorbed now from 2023, 2024, and production is still quite high. Plus, as John mentioned also, you do have a lot of dry dockings coming this year and even more next year. We did have kind of a firm outlook for 2025 already.

Yeah, with the change in trade routes, that has definitely helped, especially as we haven't seen any destruction of demand here in China.

Omar Nokta (Managing Director)

Okay. Thank you.

Yeah. Sorry, go ahead.

John Hadjipateras (Chairman, CEO and President)

No, I was going to say, even at the best of times, it's very difficult to kind of make a projection on rates. Right now, it's even more. All else, if things are staying the way they are, which they rarely do, we feel that these rates are sustainable.

Omar Nokta (Managing Director)

Yeah. Yeah. Oh, good. I guess maybe just kind of on that, you talked a bit about kind of the reshuffling, perhaps, of vessel capacity kind of moving into different trade routes. You have a longer ton mile since this U.S.-China trade deal over the beginning of last week. Have you seen kind of a flood of inquiry or a flood of fixtures on the part of Chinese buyers again? Have you seen a noticeable pickup, or are these trade lanes kind of perhaps becoming more saturated in how they've been developing the past several months?

John Hadjipateras (Chairman, CEO and President)

Tim?

Tim Hansen (Chief Commercial Officer and Director)

Yeah. I think it seems to have kind of settled now. I mean, when you had the high 24%-25% tariffs, definitely, you did not see any U.S. going into China. Now, I think we do, so it is balanced. It seems to have already shifted, and people seem content to keep selling to India. I guess also expectation of things could change again. As long as it is on balances, you could say it was immaterial whether you go one or the other place. You would probably still try to place U.S. tons outside China just to make sure that no surprises spring upon you. We have seen a change in the trade routes and also the way that Indians import and have taken advantage of the U.S.-China trade war.

Omar Nokta (Managing Director)

Got it. Okay. And then final one. I think, Ted, you may have mentioned in your opening comments that the decision on the dividend was made before the China-U.S. trade talks. Is that perhaps maybe a hint that you're more comfortable with something different, something higher, perhaps, especially given the rate improvement we've seen recently?

John Hadjipateras (Chairman, CEO and President)

I wouldn't want to commit the board or anybody. I just think that, obviously, it did change things, as you just talked about. The board made the decision with the best information available at the time. I wanted folks to have the benefit of understanding that. How the board in its discretion decides to evaluate the environment when it next meets, we'll see. Obviously, it is a better rate outlook, as John said. As John also said, things rarely stay the same. We shall see.

Omar Nokta (Managing Director)

Yeah. No, that's clear. I appreciate that. Thanks, guys. That's it for me.

John Hadjipateras (Chairman, CEO and President)

Thank you. Thank you, Omar.

Operator (participant)

Thank you. We show no further questions at this time. I will turn the call back to management for closing remarks.

John Hadjipateras (Chairman, CEO and President)

Thank you, Nikki, for running a good show for us. Thank you, Omar, as always, for your difficult and incisive questions. Have a good summer. Talk to you in late July or early August.

Operator (participant)

Thank you. This does conclude today's program. Thank you for your participation. You may disconnect at any time.