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2024年10月31日
Genesis Energy, L.P.報告2024年第三季度業績
休斯頓 - （業務線）- genesis energy，L.P.（紐交所：GEL）今天宣佈了其第三季度業績。
我們已生成2024年第三季度的財務結果：
•2024年第三季度Genesis Energy, L.P.歸屬於母公司的淨損失爲1720萬美元，相比之下，2023年同期Genesis Energy, L.P.歸屬於母公司的淨利潤爲5810萬美元。
•2024年第三季度營運活動產生現金流量爲8730萬美元，而2023年同期爲14100萬美元。
•我們宣佈對我們的優先單位進行現金分配，每個優先單位分配$0.9473，相當於約2190萬美元的現金分配，體現爲對普通單位持有人的可用現金減少。
•2024年第三季度普通受益單位持有人可供分配現金淨額爲2450萬美元，爲第三季度每個普通單位0.165美元的季度分配提供了1.21倍的覆蓋率。
•2024年第三季度總分段利潤爲$15110萬。
•2024年第三季度調整後的EBITDA爲13670萬美元。
•截至2024年9月30日，過去十二個月的調整合並稅息折舊及攤銷前利潤（EBITDA）爲74170萬美元，銀行槓桿率爲4.84倍，均根據我們的新一期擔保信用協議計算，並在本公告中進一步討論。
Genesis Energy首席執行官Grant Sims表示：「正如我們一直堅持的，2024年一直被視爲過渡年，因爲我們越來越接近拐點，我們將在2025年開始收穫越來越多的調整後息稅折舊及攤銷前利潤（Adjusted EBITDA），而不再是增長資本支出。我在這裏今天是爲了重申我對這一核心理念的信懇智能，並確認我們相信儘管存在一些近期挑戰，我們仍然按計劃進行。」
雖然我們在第三季度的表現低於我們的預期，但重要的是要記住，迄今爲止影響我們的很大一部分原因是一次性項目或其他我們無法合理控制的因素。 據我們認爲，我們最近面臨的問題中，沒有一個代表我們市場領先業務的預期長期表現發生結構性變化，儘管我們實現大量自由現金流的時間和速度可能有些向右偏移。 我們的資本支出將按計劃停止； 這是一件我們可以，並且會控制的事情。
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在我們的海底管道運輸領域，Winterfell和Warrior兩個新的海底開發計劃出現了意外延遲，之前我們提到的生產機械問題持續惡化，以及最近發生的第三個問題，這些都將在2024年繼續對我們的海底業績產生負面影響。儘管發生了這些不可預見的事件，我們依然對海底管道運輸領域的長期前景充滿信心。實際上，在過去幾個月裏，我親自會見了大部分重要生產商/承運商客戶的高級管理人員。我可以傳達的是，所有這些客戶對他們新批准的項目期望都充滿期待，無論是領域內還是海底機遇，以及他們已在墨西哥灣現有有效租約下確定的勘探機會。我們的海上擴張項目仍按計劃進行，並有望從2025年開始推動我們的海底管道運輸領域利潤的實質增長，SYNC橫向項目和CHOPS擴張將提供超出最初預期量的增量產能，可以用於額外生產或未來發展，而無需Genesis額外資本。
同樣地，我們的蘇打灰業務在本年度的頭三個季度承受了一些意料之外的運營挑戰。 雖然我們合理地預期在啓動Granger擴建項目時會遇到一些持續存在的啓動相關挑戰，但我們沒有預料到我們的Westvaco設施出現了意外的運營挑戰，因此我們從原始預測的全年總銷量中損失了超過30萬噸。此外，蘇打灰價格的短期宏觀條件在過去幾個月變得非常具有挑戰性。 例如，雖然蘇打灰出口價格在第二季度至第三季度出現了順序上升，但第四季度蘇打灰出口價格低於第三季度。 爲了部分緩解這種短期弱勢，我們的蘇打灰領導團隊正在積極研究進一步提高我們的運營效率和降低整個鹼性業務成本的方法。 化鹼業務的全球領導者Genesis Alkali是美國最大、最低成本的天然蘇打灰生產商，我們致力於保持這些相對位置，並準備採取必要措施以確保這一點。
在公司層面上，我們在前三個季度中的兩個主要業務中的表現疲軟，以及對2024年剩餘部分和2025年上半年的影響，並沒有逃過管理層的注意。我們正在積極評估削減成本和提高效率的機會，以幫助抵消預期的短期挑戰。在這方面，我們最近減記了2022年發放的大部分長期激勵報酬，這在很大程度上降低了員工在2024年的薪酬。我們相信，這一舉措不僅強化了我們與利益相關者的充分一致，以及其他節約成本措施一起，也代表了我們將來幾年內最大化可用現金流的承諾。
儘管面臨這些近期挑戰，該合作伙伴繼續着有一個非常明確的視野，從2025年開始實現調整後的息稅折舊攤銷前利潤（Adjusted EBITDA）增長，未來的成本支出將最大化，近期沒有未擔保債務到期，擁有充足的流動性和靈活性，能夠將這種不斷增長的現金流部署到資本結構中。除非發生進一步未預見的情況，我們相信我們將繼續爲資本結構中的每個人提供長期價值。
有了這個，我將簡要討論我們各個業務領域的細節。
在本季度，由於我們所服務的兩個主要深水生產設施出現持續存在的技術問題，導致我們經歷了停機時間。再次說明，受影響的成交量雖然不是非常顯著，但大部分損失的成交量本來將會通過石油和天然燃氣採集及下游運輸，在我們接觸分子的多次過程中生產。因此，這些特定的損失量對我們實現的部門毛利有着重大影響。儘管如此，我們並不會「永久性地」失去經濟利益；它僅僅會在未來的時期得以認可。儘管我們已經看到一部分受影響的產量得到恢復，但目前我們被告知完全的緩解或修復預計要到年底才會完工，因此這些中斷也將對我們第四季度的業績產生負面影響。雖然令人遺憾，生產方已重申他們預期基礎儲層不會有長期的負面影響，並預期到年底或者2025年初這些受影響的成交量將會得以恢復。
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除了生產者製造行業延長停產時間外，第三季度也遇到相對活躍的颶風季節，有兩個被命名的颶風導致製造者關閉和我們離岸製造行業的各種停產。七月，颶風Beryl登陸休斯頓附近，導致我們的離岸管線運量出現一些中斷，因為我們的製造客戶為了避險而限制或停止生產，直到暴風雨過去為止。九月，颶風Francine通過墨西哥灣中部路徑，在最終登陸路易斯安那州南部之前，導致更廣泛的製造者停產。在這兩個風暴期間，我們的離岸製造行業沒有遭受任何損害，但Francine確實導致我們的波塞冬系統比預期的停產時間更長，主要是因為路易斯安那州南部多個接收站的停電，包括第三方燃料幣處理基礎設施的損壞，延遲了運量的重新啟動。盡管波賽東系統在一段時間內停產，但我們在風暴期間能夠繼續在我們的CHOPS系統上運送大部分運量，再次展示了讓我們的製造客戶在多個相互連接的管線到岸上具有交付選擇性的戰略好處，這在灣區是相對獨特的。
我們的離岸施工項目仍然按計劃進行，我們預期大部分的現金支出和施工工作將在今年年底之前完成。剩餘的資本將用於將Shenandoah浮式生產系統連接到我們新的SYNC管道，當其在2025年初到達位於墨西哥灣的最終位置時。我們持續預期Shenandoah和Salamanca的開發及其集體的取或付協議，和合共幾乎20萬桶每天的增量產油能力，將在2025年第二季度開始，並迅速提升，並在各自的首次生產日期後的三到六個月內達到初始峰值產量。我們也預計這些新設施將作為未來海底開發或回接機會的主機平台，這可能在未來多年中支持這些現金流。
在我們的碳酸鈉業務中，由於第三方供電的損失、某些不可預見的設備故障以及在這些非計劃中斷後恢復操作的各種細微差別和挑戰，我們在第三季度再次經歷了一些意想不到的停機和生產挑戰。前九個月的較低生產量不僅對我們的總銷售量產生了負面影響，也導致了更高的維護支出和高於預期的每單位生產成本。儘管面臨這些挑戰，我們的碳酸鈉團隊在過去幾個月中努力工作，找出了這些生產挑戰的根本原因，隨後我們制定了許多新舉措和主動措施，以減少未來的生產問題，降低我們持續的運營成本，並進一步優化和改進我們的碳酸鈉業務。
The global macro conditions for soda ash have become more challenging just in the last three months. Recently, we have started to see a mixed supply and demand picture in China that is driving some uncertainty for soda ash prices in our export markets. Recent data and observations would suggest domestic demand within China is slowing, domestic inventories are increasing and availability of exports of soda ash from China are starting to increase. Despite Chinese export volumes remaining near historical lows, the increase in export availability relative to earlier in the year is causing customers in Asia, outside of China, to believe they should expect to have access to adequate supply in the short-term. These conditions within China have contributed to lower prices in the fourth quarter in our export markets.
However, we would note that the Chinese government has recently announced significant easing of monetary policy within China and is considering additional fiscal stimulus designed to drive meaningful growth in the domestic economy. These stimulative measures will take some time to ultimately work themselves through the economy and should help absorb any excess supply within China. In the meantime, we do believe a significant amount of production of synthetic soda ash, not only in China but also in the European Union, is not profitable at these prices. As a result, we would expect to see an increase in production cutbacks or potential shuttering of synthetic production of soda ash as we move into and through 2025.
Markets work and high-cost producers must adjust to market realities. For instance, we have continued to see significant changes in the flow of physical volumes around the globe, most notably with natural soda ash tons that were moving to Asia earlier this year from both the United States and Turkey, but that are now moving into Europe which increases the pressure on high-cost synthetic facilities in the region. Therefore, we believe the global soda ash market is starting to balance, as commodity markets always do.
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Regardless of the ultimate timing of such balancing, which will happen sooner rather than later if high-cost synthetic producers act more rationally, we remain committed to the soda ash business. We know Genesis holds a competitive advantage as the largest soda ash producer in the United States, and one of the lowest cost producers in the world. In the near-term, we will continue to focus on our costs and make necessary adjustments to deal with the reality of the current market for soda ash. Given our existing position, and by taking some of the steps we are currently evaluating, we believe we will be very well positioned to benefit from the inevitable balancing of the market and the higher commodity prices that will undoubtedly follow.
Our marine transportation segment continues to perform in line with our expectations despite some scheduled drydockings of our offshore vessels taking longer than expected during the quarter. Market fundamentals remain very favorable with steady and robust demand for all classes of our vessels exceeding practical net supply of marine tonnage, which continues to be hindered by the combination of little to no new construction and the continued retirement of older equipment. Given the structural shortage in the market, we continue to operate with utilization rates at or near 100% of available capacity for all classes of our vessels with the progression of day rates being commensurate with these underlying fundamentals. Day rates likely must continue to increase from today’s levels and be expected to sustain at those higher levels for an extended period of time before we see a meaningful amount of new construction of marine tonnage. We continue to anticipate sequential improvement next year in our marine transportation segment as the majority of our scheduled drydockings are complete and our existing portfolio of marine contracts continue to reset higher to current day rates.
Despite all of the noise in 2024, we remain keenly focused on getting to 2025 and the inflection point where we stop spending growth capital and start harvesting significant, and growing, cash flows in excess of the cash cost of running and sustaining our businesses that will allow us to simplify our capital structure, lower our overall cost of capital, optimize our leverage ratio and have the ability to opportunistically create long-term value for all stakeholders in our capital structure.
The management team and board of directors remain steadfast in our commitment to building long-term value for everyone in the capital structure, and we believe the decisions we are making reflect this commitment and our confidence in Genesis moving forward. I would once again like to recognize our entire workforce for their efforts and unwavering commitment to safe and responsible operations. I’m proud to have the opportunity to work alongside each and every one of you.”
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Financial Results
Segment Margin
Variances between the third quarter of 2024 (the “2024 Quarter”) and the third quarter of 2023 (the “2023 Quarter”) in these components are explained below.
Segment Margin results for the 2024 Quarter and 2023 Quarter were as follows:
| Three Months Ended September 30, | |||||||||||
| 2024 | 2023 | ||||||||||
| (in thousands) | |||||||||||
| Offshore pipeline transportation | $ | 72,149 | $ | 109,267 | |||||||
| Soda and sulfur services | 38,188 | 61,957 | |||||||||
| Marine transportation | 31,068 | 27,126 | |||||||||
| Onshore facilities and transportation | 9,703 | 9,547 | |||||||||
Total Segment Margin | $ | 151,108 | $ | 207,897 | |||||||
Offshore pipeline transportation Segment Margin for the 2024 Quarter decreased $37.1 million, or 34%, from the 2023 Quarter primarily due to several factors including: (i) an economic step-down in the rate on a certain existing life-of-lease transportation dedication; (ii) producer underperformance at two of our major host platforms; and (iii) an increase in our operating costs. At the beginning of the 2024 Quarter, we reached the 10-year anniversary of a certain existing life-of-lease transportation dedication, which resulted in the contractual economic step-down of the associated transportation rate. In addition, there was an increase in producer downtime relative to the 2023 Quarter as a result of certain sub-sea operational and technical challenges at fields connected to two of our major host platforms. The production from these wells impacted our results as they are molecules that we touch multiple times throughout our oil and natural gas pipeline infrastructure. We anticipate that the operational and technical issues that were experienced in the 2024 Quarter will be resolved by the end of this year. Outside of these issues, activity in and around our Gulf of Mexico asset base continues to be robust, including incremental in-field drilling at existing fields that tie into our infrastructure. This activity is evidenced by projects such as the Warrior and Winterfell projects, which produced first oil in late June 2024 and early July 2024, respectively, and the Monument development which is currently expected to come on-line in mid to late 2026.
Soda and sulfur services Segment Margin for the 2024 Quarter decreased $23.8 million, or 38%, from the 2023 Quarter primarily due to lower export pricing in our Alkali Business during the 2024 Quarter and lower NaHS and caustic soda sales volumes and sales pricing, which was partially offset by higher soda ash sales volumes in the period. In our Alkali Business, the 2024 Quarter was impacted by a decline in export pricing as compared to the 2023 Quarter as global supply has continued to outpace demand in most markets. Additionally, the 2024 Quarter was negatively impacted by temporary operational issues at our Westvaco facility that led to lower production volumes and reduced operating efficiencies. Despite these operational issues, our Alkali Business experienced higher soda ash sales volumes in the 2024 Quarter as production from our expanded Granger facility came online in the fourth quarter of 2023 and has since ramped up to levels near its nameplate capacity of approximately 100,000 tons of production per month. In our sulfur services business, we have experienced continued pressure on demand in South America, which has negatively impacted NaHS and caustic soda sales volumes and pricing. In addition, production was impacted by a planned outage at one of our largest and lowest cost host refineries during the 2024 Quarter.
Marine transportation Segment Margin for the 2024 Quarter increased $3.9 million, or 15%, from the 2023 Quarter primarily due to higher day rates in our inland and offshore businesses, including the M/T American Phoenix, during the 2024 Quarter. The increase in day rates more than offset the impact to Segment Margin from the increased number of regulatory dry-docking days in our offshore fleet during the 2024 Quarter. Demand for our barge services to move intermediate and refined products remained high during the 2024 Quarter due to the continued strength of refinery utilization rates as well as the lack of new supply of similar type vessels (primarily due to higher construction costs and long lead times for construction) as well as the retirement of older vessels in the market.
Onshore facilities and transportation Segment Margin for the 2024 Quarter increased $0.2 million, or 2%, from the 2023 Quarter primarily due to an increase in the rail unload volumes at our Scenic Station facility. This increase was partially offset by an overall decrease in volumes on our onshore crude oil pipeline systems.
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Other Components of Net Income (Loss)
We reported Net Loss Attributable to Genesis Energy, L.P. of $17.2 million in the 2024 Quarter compared to Net Income Attributable to Genesis Energy, L.P. of $58.1 million in the 2023 Quarter.
Net Loss Attributable to Genesis Energy, L.P. in the 2024 Quarter was impacted by: (i) a decrease in operating income associated with our reportable segments primarily due to a decrease in export pricing in our Alkali Business and a decrease in volumes in our offshore pipeline transportation segment in the 2024 Quarter; (ii) an increase in interest expense, net, of $10.4 million; and (iii) an increase in depreciation, depletion and amortization of $13.5 million during the 2024 Quarter. These impacts were partially offset by higher day rates in our marine transportation segment and higher soda ash sales volumes in our Alkali Business.
Earnings Conference Call
We will broadcast our Earnings Conference Call on Thursday, October 31, 2024, at 9:00 a.m. Central time (10:00 a.m. Eastern time). This call can be accessed at www.genesisenergy.com. Choose the Investor Relations button. For those unable to attend the live broadcast, a replay will be available beginning approximately one hour after the event and remain available on our website for 30 days. There is no charge to access the event.
Genesis Energy, L.P. is a diversified midstream energy master limited partnership headquartered in Houston, Texas. Genesis’ operations include offshore pipeline transportation, soda and sulfur services, onshore facilities and transportation and marine transportation. Genesis’ operations are primarily located in the Gulf of Mexico, Wyoming and in the Gulf Coast region of the United States.
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GENESIS ENERGY, L.P.
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - UNAUDITED
(in thousands, except unit amounts)
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2024 | 2023 | 2024 | 2023 | ||||||||||||||||||||
| REVENUES | $ | 714,297 | $ | 807,618 | $ | 2,240,663 | $ | 2,402,892 | |||||||||||||||
| COSTS AND EXPENSES: | |||||||||||||||||||||||
| Costs of sales and operating expenses | 567,201 | 610,775 | 1,777,849 | 1,880,814 | |||||||||||||||||||
| General and administrative expenses | 15,042 | 16,770 | 48,597 | 48,253 | |||||||||||||||||||
| Depreciation, depletion and amortization | 81,837 | 68,379 | 233,221 | 209,966 | |||||||||||||||||||
| OPERATING INCOME | 50,217 | 111,694 | 180,996 | 263,859 | |||||||||||||||||||
| Equity in earnings of equity investees | 11,634 | 17,242 | 40,288 | 49,606 | |||||||||||||||||||
| Interest expense, net | (71,984) | (61,580) | (211,588) | (184,057) | |||||||||||||||||||
| Other expense | — | — | (1,429) | (1,812) | |||||||||||||||||||
| INCOME (LOSS) BEFORE INCOME TAXES | (10,133) | 67,356 | 8,267 | 127,596 | |||||||||||||||||||
| Income tax benefit (expense) | 846 | (574) | 15 | (1,748) | |||||||||||||||||||
| NET INCOME (LOSS) | (9,287) | 66,782 | 8,282 | 125,848 | |||||||||||||||||||
| Net income attributable to noncontrolling interests | (7,890) | (8,712) | (22,850) | (20,078) | |||||||||||||||||||
| NET INCOME (LOSS) ATTRIBUTABLE TO GENESIS ENERGY, L.P. | $ | (17,177) | $ | 58,070 | $ | (14,568) | $ | 105,770 | |||||||||||||||
| Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units | (21,894) | (22,308) | (65,682) | (69,220) | |||||||||||||||||||
| NET INCOME (LOSS) ATTRIBUTABLE TO COMMON UNITHOLDERS | $ | (39,071) | $ | 35,762 | $ | (80,250) | $ | 36,550 | |||||||||||||||
| NET INCOME (LOSS) PER COMMON UNIT: | |||||||||||||||||||||||
| Basic and Diluted | $ | (0.32) | $ | 0.29 | $ | (0.66) | $ | 0.30 | |||||||||||||||
| WEIGHTED AVERAGE OUTSTANDING COMMON UNITS: | |||||||||||||||||||||||
| Basic and Diluted | 122,464,318 | 122,520,592 | 122,464,318 | 122,559,461 | |||||||||||||||||||
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GENESIS ENERGY, L.P.
OPERATING DATA - UNAUDITED
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2024 | 2023 | 2024 | 2023 | ||||||||||||||||||||
| Offshore Pipeline Transportation Segment | |||||||||||||||||||||||
| Crude oil pipelines (average barrels/day unless otherwise noted): | |||||||||||||||||||||||
CHOPS(1) | 304,198 | 307,045 | 299,628 | 266,974 | |||||||||||||||||||
Poseidon(1) | 249,210 | 310,817 | 273,704 | 304,771 | |||||||||||||||||||
Odyssey(1) | 69,560 | 60,830 | 65,837 | 62,119 | |||||||||||||||||||
| GOPL | 1,583 | 3,033 | 1,801 | 2,471 | |||||||||||||||||||
| Offshore crude oil pipelines total | 624,551 | 681,725 | 640,970 | 636,335 | |||||||||||||||||||
Natural gas transportation volumes (MMBtus/day)(1) | 393,240 | 408,866 | 385,038 | 398,060 | |||||||||||||||||||
| Soda and Sulfur Services Segment | |||||||||||||||||||||||
| Soda Ash volumes (short tons sold) | 995,856 | 867,319 | 2,838,097 | 2,424,150 | |||||||||||||||||||
| NaHS (dry short tons sold) | 23,398 | 27,325 | 82,091 | 81,501 | |||||||||||||||||||
| NaOH (caustic soda) volumes (dry short tons sold) | 16,215 | 18,229 | 52,999 | 58,751 | |||||||||||||||||||
| Marine Transportation Segment | |||||||||||||||||||||||
Inland Fleet Utilization Percentage(2) | 99.4 | % | 99.4 | % | 99.5 | % | 99.8 | % | |||||||||||||||
Offshore Fleet Utilization Percentage(2) | 97.4 | % | 98.5 | % | 97.1 | % | 97.6 | % | |||||||||||||||
| Onshore Facilities and Transportation Segment | |||||||||||||||||||||||
| Crude oil pipelines (barrels/day): | |||||||||||||||||||||||
Texas(3) | 57,726 | 66,376 | 69,149 | 65,648 | |||||||||||||||||||
| Jay | 4,295 | 6,161 | 5,026 | 5,710 | |||||||||||||||||||
| Mississippi | 2,194 | 4,854 | 2,597 | 4,866 | |||||||||||||||||||
Louisiana(4) | 60,255 | 60,973 | 63,084 | 70,843 | |||||||||||||||||||
| Onshore crude oil pipelines total | 124,470 | 138,364 | 139,856 | 147,067 | |||||||||||||||||||
| Crude oil and petroleum products sales (barrels/day) | 18,978 | 23,703 | 21,364 | 23,006 | |||||||||||||||||||
| Rail unload volumes (barrels/day) | 17,757 | — | 12,954 | — | |||||||||||||||||||
(1)As of September 30, 2024 and 2023, we owned 64% of CHOPS, 64% of Poseidon and 29% of Odyssey, as well as equity interests in various other entities. Volumes are presented above on a 100% basis for all periods.
(2)Utilization rates are based on a 365-day year, as adjusted for planned downtime and dry-docking.
(3)Our Texas pipeline and infrastructure is a destination point for many pipeline systems in the Gulf of Mexico, including the CHOPS pipeline.
(4)Total daily volumes for the three and nine months ended September 30, 2024 include 22,959 and 24,159 Bbls/day, respectively, of intermediate refined products and 37,296 and 38,467 Bbls/day, respectively, of crude oil associated with our Port of Baton Rouge Terminal pipelines. Total daily volumes for the three and nine months ended September 30, 2023 include 42,622 and 34,720 Bbls/day, respectively, of intermediate refined products and 17,201 and 35,564 Bbls/day, respectively, of crude oil associated with our Port of Baton Rouge Terminal pipelines.
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GENESIS ENERGY, L.P.
CONDENSED CONSOLIDATED BALANCE SHEETS
(in thousands, except unit amounts)
| September 30, 2024 | December 31, 2023 | ||||||||||
| (unaudited) | |||||||||||
| ASSETS | |||||||||||
| Cash, cash equivalents and restricted cash | $ | 31,768 | $ | 28,038 | |||||||
| Accounts receivable - trade, net | 745,608 | 759,547 | |||||||||
| Inventories | 110,687 | 135,231 | |||||||||
| Other | 37,286 | 41,234 | |||||||||
| Total current assets | 925,349 | 964,050 | |||||||||
| Fixed assets and mineral leaseholds, net of accumulated depreciation and depletion | 5,169,388 | 5,068,821 | |||||||||
| Equity investees | 245,288 | 263,829 | |||||||||
| Intangible assets, net of amortization | 142,071 | 141,537 | |||||||||
| Goodwill | 301,959 | 301,959 | |||||||||
| Right of use assets, net | 225,389 | 240,341 | |||||||||
| Other assets, net of amortization | 49,187 | 38,241 | |||||||||
| Total assets | $ | 7,058,631 | $ | 7,018,778 | |||||||
| LIABILITIES AND CAPITAL | |||||||||||
| Accounts payable - trade | $ | 538,980 | $ | 588,924 | |||||||
| Accrued liabilities | 358,055 | 378,523 | |||||||||
| Total current liabilities | 897,035 | 967,447 | |||||||||
| Senior secured credit facility | 207,600 | 298,300 | |||||||||
| Senior unsecured notes, net of debt issuance costs, discount and premium | 3,419,025 | 3,062,955 | |||||||||
| Alkali senior secured notes, net of debt issuance costs and discount | 382,391 | 391,592 | |||||||||
| Deferred tax liabilities | 16,318 | 17,510 | |||||||||
| Other long-term liabilities | 541,874 | 570,197 | |||||||||
| Total liabilities | 5,464,243 | 5,308,001 | |||||||||
| Mezzanine capital: | |||||||||||
| Class A Convertible Preferred Units | 813,589 | 813,589 | |||||||||
| Partners’ capital: | |||||||||||
| Common unitholders | 371,371 | 519,698 | |||||||||
| Accumulated other comprehensive income | 8,310 | 8,040 | |||||||||
| Noncontrolling interests | 401,118 | 369,450 | |||||||||
| Total partners’ capital | 780,799 | 897,188 | |||||||||
| Total liabilities, mezzanine capital and partners’ capital | $ | 7,058,631 | $ | 7,018,778 | |||||||
| Common Units Data: | |||||||||||
| Total common units outstanding | 122,464,318 | 122,464,318 | |||||||||
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GENESIS ENERGY, L.P.
RECONCILIATION OF NET INCOME (LOSS) ATTRIBUTABLE TO GENESIS ENERGY, L.P. TO SEGMENT MARGIN - UNAUDITED
(in thousands)
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2024 | 2023 | 2024 | 2023 | ||||||||||||||||||||
| Net income (loss) attributable to Genesis Energy, L.P. | $ | (17,177) | $ | 58,070 | $ | (14,568) | $ | 105,770 | |||||||||||||||
| Corporate general and administrative expenses | 13,175 | 18,329 | 49,231 | 52,580 | |||||||||||||||||||
| Depreciation, depletion, amortization and accretion | 84,610 | 71,099 | 241,539 | 218,788 | |||||||||||||||||||
| Interest expense, net | 71,984 | 61,580 | 211,588 | 184,057 | |||||||||||||||||||
| Income tax expense (benefit) | (846) | 574 | (15) | 1,748 | |||||||||||||||||||
Plus (minus) Select Items, net(1) | (638) | (1,755) | 12,744 | 54,701 | |||||||||||||||||||
Segment Margin(2) | $ | 151,108 | $ | 207,897 | $ | 500,519 | $ | 617,644 | |||||||||||||||
(1)Refer to additional detail of Select Items later in this press release.
(2)See definition of Segment Margin later in this press release.
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GENESIS ENERGY, L.P.
RECONCILIATIONS OF NET INCOME (LOSS) ATTRIBUTABLE TO GENESIS ENERGY L.P. TO ADJUSTED EBITDA AND AVAILABLE CASH BEFORE RESERVES - UNAUDITED
(in thousands)
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2024 | 2023 | 2024 | 2023 | ||||||||||||||||||||
| Net income (loss) attributable to Genesis Energy, L.P. | $ | (17,177) | $ | 58,070 | $ | (14,568) | $ | 105,770 | |||||||||||||||
| Interest expense, net | 71,984 | 61,580 | 211,588 | 184,057 | |||||||||||||||||||
| Income tax expense (benefit) | (846) | 574 | (15) | 1,748 | |||||||||||||||||||
| Depreciation, depletion, amortization and accretion | 84,610 | 71,099 | 241,539 | 218,788 | |||||||||||||||||||
EBITDA | 138,571 | 191,323 | 438,544 | 510,363 | |||||||||||||||||||
Plus (minus) Select Items, net(1) | (1,870) | (767) | 10,111 | 57,255 | |||||||||||||||||||
Adjusted EBITDA(2) | 136,701 | 190,556 | 448,655 | 567,618 | |||||||||||||||||||
Maintenance capital utilized(3) | (18,000) | (17,200) | (54,300) | (49,900) | |||||||||||||||||||
| Interest expense, net | (71,984) | (61,580) | (211,588) | (184,057) | |||||||||||||||||||
| Cash tax expense | (333) | (200) | (966) | (823) | |||||||||||||||||||
Distributions to preferred unitholders(4) | (21,894) | (22,612) | (65,682) | (69,928) | |||||||||||||||||||
Available Cash before Reserves(5) | $ | 24,490 | $ | 88,964 | $ | 116,119 | $ | 262,910 | |||||||||||||||
(1)Refer to additional detail of Select Items later in this press release.
(2)See definition of Adjusted EBITDA later in this press release.
(3)Maintenance capital expenditures for the 2024 Quarter and 2023 Quarter were $55.0 million and $33.6 million, respectively. Maintenance capital expenditures for the nine months ended September 30, 2024 and 2023, were $128.6 million and $86.9 million, respectively. Our maintenance capital expenditures are principally associated with our alkali and marine transportation businesses.
(4)Distributions to preferred unitholders attributable to the 2024 Quarter are payable on November 14, 2024 to unitholders of record at close of business on October 31, 2024.
(5)Represents the Available Cash before Reserves to common unitholders.
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GENESIS ENERGY, L.P.
RECONCILIATION OF NET CASH FLOWS FROM OPERATING ACTIVITIES TO ADJUSTED EBITDA - UNAUDITED
(in thousands)
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2024 | 2023 | 2024 | 2023 | ||||||||||||||||||||
| Cash Flows from Operating Activities | $ | 87,324 | $ | 141,043 | $ | 317,966 | $ | 396,364 | |||||||||||||||
| Adjustments to reconcile net cash flows from operating activities to Adjusted EBITDA: | |||||||||||||||||||||||
| Interest expense, net | 71,984 | 61,580 | 211,588 | 184,057 | |||||||||||||||||||
| Amortization and write-off of debt issuance costs, discount and premium | (2,949) | (2,393) | (10,319) | (8,206) | |||||||||||||||||||
| Effects from equity method investees not included in operating cash flows | 6,998 | 6,320 | 18,685 | 19,704 | |||||||||||||||||||
| Net effect of changes in components of operating assets and liabilities | (10,520) | (2,647) | (59,752) | (3,604) | |||||||||||||||||||
| Non-cash effect of long-term incentive compensation plans | 1,666 | (5,580) | (8,120) | (15,236) | |||||||||||||||||||
| Expenses related to business development activities and growth projects | — | — | 60 | 105 | |||||||||||||||||||
Differences in timing of cash receipts for certain contractual arrangements(1) | (7,526) | 11,385 | 8,366 | 33,519 | |||||||||||||||||||
Other items, net(2) | (10,276) | (19,152) | (29,819) | (39,085) | |||||||||||||||||||
Adjusted EBITDA(3) | $ | 136,701 | $ | 190,556 | $ | 448,655 | $ | 567,618 | |||||||||||||||
(1)Includes the difference in timing of cash receipts from or billings to customers during the period and the revenue we recognize in accordance with GAAP on our related contracts. For purposes of our non-GAAP measures, we add those amounts in the period of payment and deduct them in the period in which GAAP recognizes them.
(2)Includes adjustments associated with the noncontrolling interest effects of our non-100% owned consolidated subsidiaries as our Adjusted EBITDA measure is reported net to our ownership interests, amongst other items.
(3)See definition of Adjusted EBITDA later in this press release.
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GENESIS ENERGY, L.P.
ADJUSTED DEBT-TO-ADJUSTED CONSOLIDATED EBITDA RATIO - UNAUDITED
(in thousands)
| September 30, 2024 | ||||||||
| Senior secured credit facility | $ | 207,600 | ||||||
| Senior unsecured notes, net of debt issuance costs, discount and premium | 3,419,025 | |||||||
Less: Outstanding inventory financing sublimit borrowings | (24,200) | |||||||
Less: Cash and cash equivalents | (12,732) | |||||||
Adjusted Debt(1) | $ | 3,589,693 | ||||||
| Pro Forma LTM | ||||||||
| September 30, 2024 | ||||||||
Consolidated EBITDA (per our senior secured credit facility) | $ | 618,816 | ||||||
Consolidated EBITDA adjustments(2) | 122,895 | |||||||
Adjusted Consolidated EBITDA (per our senior secured credit facility)(3) | $ | 741,711 | ||||||
| Adjusted Debt-to-Adjusted Consolidated EBITDA | 4.84X | |||||||
(1) We define Adjusted Debt as the amounts outstanding under our senior secured credit facility and senior unsecured notes (including any unamortized premiums, discounts or issuance costs) less the amount outstanding under our inventory financing sublimit, and less cash and cash equivalents on hand at the end of the period from our restricted subsidiaries.
(2) This amount reflects adjustments we are permitted to make under our senior secured credit facility for purposes of calculating compliance with our leverage ratio. It includes a pro rata portion of projected future annual EBITDA associated with material organic growth projects. For any material organic growth project not yet completed or in-service, the EBITDA Adjustment is calculated based on the percentage of capital expenditures incurred to date relative to the expected budget multiplied by the total annual contractual minimum cash commitments we expect to receive as a result of the project. These adjustments may not be indicative of future results.
(3) Adjusted Consolidated EBITDA for the four-quarter period ending with the most recent quarter, as calculated under our senior secured credit facility.
This press release includes forward-looking statements as defined under federal law. Although we believe that our expectations are based upon reasonable assumptions, we can give no assurance that our goals will be achieved. Actual results may vary materially. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that we expect, believe or anticipate will or may occur in the future, including but not limited to statements relating to future financial and operating results and capital expenditures, our bank leverage ratio and compliance with our senior secured credit facility covenants, the timing and anticipated benefits of the Shenandoah and Salamanca developments, our expectations regarding our Granger expansion, the expected performance of our offshore assets and other projects and business segments, and our strategy and plans, are forward-looking statements, and historical performance is not necessarily indicative of future performance. Those forward-looking statements rely on a number of assumptions concerning future events and are subject to a number of uncertainties, factors and risks, many of which are outside our control, that could cause results to differ materially from those expected by management. Such risks and uncertainties include, but are not limited to, weather, political, economic and market conditions, including a decline in the price and market demand for products (which may be affected by the actions of OPEC and other oil exporting nations), impacts due to inflation, and a reduction in demand for our services resulting in impairments of our assets, the spread of disease, the impact of international military conflicts (such as the war in Ukraine, the Israel and Hamas war and broader geopolitical tensions in the Middle East and Eastern Europe), the result of any economic recession or depression that has occurred or may occur in the future, construction and anticipated benefits of the SYNC pipeline and expansion of the capacity of the CHOPS system, the timing and success of business development efforts and other uncertainties. Those and other applicable uncertainties, factors and risks that may affect those forward-looking statements are described more fully in our Annual Report on Form 10-K for the year ended December 31, 2023 filed with the Securities and Exchange Commission and other filings, including our Current Reports on Form 8-K and Quarterly Reports on Form 10-Q. We undertake no obligation to publicly update or revise any forward-looking statement.
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NON-GAAP MEASURES
This press release and the accompanying schedules include non-generally accepted accounting principle (non-GAAP) financial measures of Adjusted EBITDA and total Available Cash before Reserves. In this press release, we also present total Segment Margin as if it were a non-GAAP measure. Our non-GAAP measures may not be comparable to similarly titled measures of other companies because such measures may include or exclude other specified items. The accompanying schedules provide reconciliations of these non-GAAP financial measures to their most directly comparable financial measures calculated in accordance with generally accepted accounting principles in the United States of America (GAAP). Our non-GAAP financial measures should not be considered (i) as alternatives to GAAP measures of liquidity or financial performance or (ii) as being singularly important in any particular context; they should be considered in a broad context with other quantitative and qualitative information. Our Available Cash before Reserves, Adjusted EBITDA and total Segment Margin measures are just three of the relevant data points considered from time to time.
When evaluating our performance and making decisions regarding our future direction and actions (including making discretionary payments, such as quarterly distributions) our board of directors and management team have access to a wide range of historical and forecasted qualitative and quantitative information, such as our financial statements; operational information; various non-GAAP measures; internal forecasts; credit metrics; analyst opinions; performance; liquidity and similar measures; income; cash flow expectations for us; and certain information regarding some of our peers. Additionally, our board of directors and management team analyze, and place different weight on, various factors from time to time. We believe that investors benefit from having access to the same financial measures being utilized by management, lenders, analysts and other market participants. We attempt to provide adequate information to allow each individual investor and other external user to reach her/his own conclusions regarding our actions without providing so much information as to overwhelm or confuse such investor or other external user.
AVAILABLE CASH BEFORE RESERVES
Purposes, Uses and Definition
Available Cash before Reserves, often referred to by others as distributable cash flow, is a quantitative standard used throughout the investment community with respect to publicly traded partnerships and is commonly used as a supplemental financial measure by management and by external users of financial statements such as investors, commercial banks, research analysts and rating agencies, to aid in assessing, among other things:
(1)the financial performance of our assets;
(2)our operating performance;
(3)the viability of potential projects, including our cash and overall return on alternative capital investments as compared to those of other companies in the midstream energy industry;
(4)the ability of our assets to generate cash sufficient to satisfy certain non-discretionary cash requirements, including interest payments and certain maintenance capital requirements; and
(5)our ability to make certain discretionary payments, such as distributions on our preferred and common units, growth capital expenditures, certain maintenance capital expenditures and early payments of indebtedness.
We define Available Cash before Reserves (“Available Cash before Reserves”) as Adjusted EBITDA adjusted for certain items, the most significant of which in the relevant reporting periods have been the sum of maintenance capital utilized, interest expense, net, cash tax expense and cash distributions paid to our Class A convertible preferred unitholders.
Disclosure Format Relating to Maintenance Capital
We use a modified format relating to maintenance capital requirements because our maintenance capital expenditures vary materially in nature (discretionary vs. non-discretionary), timing and amount from time to time. We believe that, without such modified disclosure, such changes in our maintenance capital expenditures could be confusing and potentially misleading to users of our financial information, particularly in the context of the nature and purposes of our Available Cash before Reserves measure. Our modified disclosure format provides those users with information in the form of our maintenance capital utilized measure (which we deduct to arrive at Available Cash before Reserves). Our maintenance capital utilized measure constitutes a proxy for non-discretionary maintenance capital expenditures and it takes into consideration the relationship among maintenance capital expenditures, operating expenses and depreciation from period to period.
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Maintenance Capital Requirements
Maintenance Capital Expenditures
Maintenance capital expenditures are capitalized costs that are necessary to maintain the service capability of our existing assets, including the replacement of any system component or equipment which is worn out or obsolete. Maintenance capital expenditures can be discretionary or non-discretionary, depending on the facts and circumstances.
Prior to 2014, substantially all of our maintenance capital expenditures were (a) related to our pipeline assets and similar infrastructure, (b) non-discretionary in nature and (c) immaterial in amount as compared to our Available Cash before Reserves measure. Those historical expenditures were non-discretionary (or mandatory) in nature because we had very little (if any) discretion as to whether or when we incurred them. We had to incur them in order to continue to operate the related pipelines in a safe and reliable manner and consistently with past practices. If we had not made those expenditures, we would not have been able to continue to operate all or portions of those pipelines, which would not have been economically feasible. An example of a non-discretionary (or mandatory) maintenance capital expenditure would be replacing a segment of an old pipeline because one can no longer operate that pipeline safely, legally and/or economically in the absence of such replacement.
Beginning with 2014, we believe a substantial amount of our maintenance capital expenditures from time to time will be (a) related to our assets other than pipelines, such as our marine vessels, trucks and similar assets, (b) discretionary in nature and (c) potentially material in amount as compared to our Available Cash before Reserves measure. Those expenditures will be discretionary (or non-mandatory) in nature because we will have significant discretion as to whether or when we incur them. We will not be forced to incur them in order to continue to operate the related assets in a safe and reliable manner. If we chose not make those expenditures, we would be able to continue to operate those assets economically, although in lieu of maintenance capital expenditures, we would incur increased operating expenses, including maintenance expenses. An example of a discretionary (or non-mandatory) maintenance capital expenditure would be replacing an older marine vessel with a new marine vessel with substantially similar specifications, even though one could continue to economically operate the older vessel in spite of its increasing maintenance and other operating expenses.
In summary, as we continue to expand certain non-pipeline portions of our business, we are experiencing changes in the nature (discretionary vs. non-discretionary), timing and amount of our maintenance capital expenditures that merit a more detailed review and analysis than was required historically. Management’s increasing ability to determine if and when to incur certain maintenance capital expenditures is relevant to the manner in which we analyze aspects of our business relating to discretionary and non-discretionary expenditures. We believe it would be inappropriate to derive our Available Cash before Reserves measure by deducting discretionary maintenance capital expenditures, which we believe are similar in nature in this context to certain other discretionary expenditures, such as growth capital expenditures, distributions/dividends and equity buybacks. Unfortunately, not all maintenance capital expenditures are clearly discretionary or non-discretionary in nature. Therefore, we developed a measure, maintenance capital utilized, that we believe is more useful in the determination of Available Cash before Reserves.
Maintenance Capital Utilized
We believe our maintenance capital utilized measure is the most useful quarterly maintenance capital requirements measure to use to derive our Available Cash before Reserves measure. We define our maintenance capital utilized measure as that portion of the amount of previously incurred maintenance capital expenditures that we utilize during the relevant quarter, which would be equal to the sum of the maintenance capital expenditures we have incurred for each project/component in prior quarters allocated ratably over the useful lives of those projects/components.
Our maintenance capital utilized measure constitutes a proxy for non-discretionary maintenance capital expenditures and it takes into consideration the relationship among maintenance capital expenditures, operating expenses and depreciation from period to period. Because we did not use our maintenance capital utilized measure before 2014, our maintenance capital utilized calculations will reflect the utilization of solely those maintenance capital expenditures incurred since December 31, 2013.
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ADJUSTED EBITDA
Purposes, Uses and Definition
Adjusted EBITDA is commonly used as a supplemental financial measure by management and by external users of financial statements such as investors, commercial banks, research analysts and rating agencies, to aid in assessing, among other things:
(1)the financial performance of our assets without regard to financing methods, capital structures or historical cost basis;
(2)our operating performance as compared to those of other companies in the midstream energy industry, without regard to financing and capital structure;
(3)the viability of potential projects, including our cash and overall return on alternative capital investments as compared to those of other companies in the midstream energy industry;
(4)the ability of our assets to generate cash sufficient to satisfy certain non-discretionary cash requirements, including interest payments and certain maintenance capital requirements; and
(5)our ability to make certain discretionary payments, such as distributions on our preferred and common units, growth capital expenditures, certain maintenance capital expenditures and early payments of indebtedness.
We define Adjusted EBITDA (“Adjusted EBITDA”) as Net income (loss) attributable to Genesis Energy, L.P. before interest, taxes, depreciation, depletion and amortization (including impairment, write-offs, accretion and similar items) after eliminating other non-cash revenues, expenses, gains, losses and charges (including any loss on asset dispositions), plus or minus certain other select items that we view as not indicative of our core operating results (collectively, “Select Items”). Although we do not necessarily consider all of our Select Items to be non-recurring, infrequent or unusual, we believe that an understanding of these Select Items is important to the evaluation of our core operating results. The most significant Select Items in the relevant reporting periods are set forth below.
The table below includes the Select Items discussed above as applicable to the reconciliation of Net income (loss) attributable to Genesis Energy, L.P. to Adjusted EBITDA and Available Cash before Reserves:
| Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||||||||||||
| 2024 | 2023 | 2024 | 2023 | |||||||||||||||||||||||
| (in thousands) | ||||||||||||||||||||||||||
| I. | Applicable to all Non-GAAP Measures | |||||||||||||||||||||||||
Differences in timing of cash receipts for certain contractual arrangements(1) | $ | (7,526) | $ | 11,385 | $ | 8,366 | $ | 33,519 | ||||||||||||||||||
| Certain non-cash items: | ||||||||||||||||||||||||||
| Unrealized losses (gains) on derivative transactions excluding fair value hedges, net of changes in inventory value | 1,606 | (12,299) | (9,335) | 17,721 | ||||||||||||||||||||||
| Loss on debt extinguishment | — | — | 1,429 | 1,812 | ||||||||||||||||||||||
Adjustment regarding equity investees(2) | 6,855 | 6,387 | 18,542 | 18,535 | ||||||||||||||||||||||
| Other | (1,573) | (7,228) | (6,258) | (16,886) | ||||||||||||||||||||||
Sub-total Select Items, net(3) | (638) | (1,755) | 12,744 | 54,701 | ||||||||||||||||||||||
| II. | Applicable only to Adjusted EBITDA and Available Cash before Reserves | |||||||||||||||||||||||||
| Certain transaction costs | — | — | 60 | 105 | ||||||||||||||||||||||
| Other | (1,232) | 988 | (2,693) | 2,449 | ||||||||||||||||||||||
Total Select Items, net(4) | $ | (1,870) | $ | (767) | $ | 10,111 | $ | 57,255 | ||||||||||||||||||
(1)Includes the difference in timing of cash receipts from or billings to customers during the period and the revenue we recognize in accordance with GAAP on our related contracts. For purposes of our non-GAAP measures, we add those amounts in the period of payment and deduct them in the period in which GAAP recognizes them.
(2)Represents the net effect of adding distributions from equity investees and deducting earnings of equity investees net to us.
(3)Represents Select Items applicable to all Non-GAAP measures.
(4)Represents Select Items applicable to Adjusted EBITDA and Available Cash before Reserves.
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SEGMENT MARGIN
Our chief operating decision maker (our Chief Executive Officer) evaluates segment performance based on a variety of measures including Segment Margin, segment volumes where relevant and capital investment. We define Segment Margin (“Segment Margin”) as revenues less product costs, operating expenses and segment general and administrative expenses (all of which are net of the effects of our noncontrolling interest holders), plus or minus applicable Select Items. Although, we do not necessarily consider all of our Select Items to be non-recurring, infrequent or unusual, we believe that an understanding of these Select Items is important to the evaluation of our core operating results.
# # #
Contact:
Genesis Energy, L.P.
Dwayne Morley
Vice President - Investor Relations
(713) 860-2536
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