CVR Energy (CVI) 2026 年第三季法說會：42 億美元煉油廠交易與創新高業績

CVR Energy (NYSE: CVI) 公布 2026 年第三季淨利為 5.63 億美元，調整後 EBITDA 為 5.82 億美元，主要受惠於更強勁的 Group 3 裂解價差與更高的煉油廠提煉量。該公司亦宣布一項價值 42 億美元的協議，將收購馬拉松石油 (Marathon Petroleum) 的兩座煉油廠及其相關資產。

重點提要

• 2026 年第三季淨利為 5.63 億美元，或稀釋後每股盈餘 5.67 美元。調整後每股盈餘為 4.00 美元，調整後 EBITDA 則達 5.82 億美元。
• 石油部門調整後 EBITDA 從 2025 年第三季的 1.2 億美元增加至 5.65 億美元，主要受 Group 3 裂解價差及提煉量提升所推動。
• CVR Energy 同意以約 42 億美元收購馬拉松石油 (Marathon Petroleum) 位於聖保羅公園 (St. Paul Park) 與曼丹 (Mandan) 的煉油廠、相關行銷業務及特定物流資產。
• 收購的煉油廠合計銘牌原油加工能力約為每日 17.7 萬桶。此筆交易將使 CVR Energy 的總加工能力從每日約 20.7 萬桶提升至 38.4 萬桶。
• 管理層預計，在交易完成後的第一個完整年度內，該筆收購將對每股盈餘及自由現金流帶來超過 50% 的增益，並實現每年約 7,000 萬美元的常態性綜效。
• 董事會宣布派發 2026 年第三季每股 0.10 美元的股利。管理層預期煉油產業的上行週期可能會持續到 2027 年，但計畫在收購完成後優先降低槓桿。

核心財務結果

列報的財務結果包含 3.14 億美元的有利 RFS 負債變動、3,500 萬美元的有利庫存估值影響，以及 1.27 億美元的未實現衍生性商品虧損。衍生性商品虧損總計 2.59 億美元，包括 1.33 億美元的已實現虧損與 1.27 億美元的未實現虧損。

業務與營運表現

合計提煉量約為每日 22.8 萬桶。原油產能利用率達到銘牌產能的約 105%，輕質產品良率占總提煉量的 93%。

Group 3 2-1-1 裂解價差平均為每桶 68.50 美元，高於 2025 年第三季的 25.94 美元。CVR Energy 的調整後已實現利潤為每桶 34.97 美元，相當於 51% 的抓取率。

RIN 價格年增超過 125%，達到每桶 14 美元以上。不含 RFS 負債變動的淨 RIN 費用為 2.35 億美元，即每桶 11.20 美元。管理層表示，這使季度基準抓取率降低了約 16 個百分點。

美國環保署 (EPA) 授予 Wynnewood 煉油公司 2025 年義務的完整小型煉油廠豁免權，使資產負債表上的 RFS 負債減少了 2.53 億美元。截至 9 月 30 日，應計 RFS 義務金額為 2.30 億美元，涵蓋 1.13 億個 RIN，平均標價為 2.04 美元。

石油部門直接營運費用從 2025 年第三季的每桶 5.69 美元上升至每桶 6.15 美元，主因是人事費用增加，包括股份基礎給付。

肥料部門調整後 EBITDA 降至 2,000 萬美元。氨產能利用率為 80%，反映了 East Dubuque 廠區的計畫性停工檢修。CVR Partners 宣派每普通單位 1.79 美元的分配金，CVR Energy 預計依其 37% 的股權比例可獲得約 700 萬美元。

馬拉松煉油廠收購案

這筆價值 42 億美元的交易包含位於明尼蘇達州、每日產能 10.5 萬桶的聖保羅公園 (St. Paul Park) 煉油廠，位於北達科他州、每日產能 7.2 萬桶的曼丹 (Mandan) 煉油廠，擁有高達 590 個品牌據點的相關行銷業務，以及特定物流資產。

管理層表示，收購價格低於其對被收購業務 2026 年預估 EBITDA 的 3.5 倍。依截至 2026 年 9 月 30 日止 9 個月的擬議 (pro forma) 基準計算，CVR Energy 表示 EBITDA 將從約 9 億美元增加至約 20 億美元，稀釋後每股盈餘將從 3.73 美元升至 7.67 美元。

公司計畫利用普通股、現金及債務融資來資助此項收購。資金來源包括來自 Trafigura 的大量普通股投資、來自 IEP 的 5 億美元股權承諾金、約 6.5 億美元的 CVR Energy 現金、25 億美元的承諾過渡性融資，以及預計從擴大規模至 11 億美元的 ABL 融資額度中提領的 3 億美元。

在排除 CVR Partners 的情況下，交割時的擬議債務預計約為 38 億美元，低於管理層預估 2026 年合併擬議 EBITDA 的兩倍。CVR Energy 還計畫贖回其尚未到期的 2028 年優先票據，並打算利用在高於中期週期利潤環境下產生的現金流來降低槓桿。

管理層營運展望

在不含收購之馬拉松資產的情況下，CVR Energy 提供以下 2026 年第四季展望：

管理層預計 2026 全年合併資本支出約為 2.2 億至 2.4 億美元。肥料部門展望反映了 10 月份 East Dubuque 停工檢修的完成。

馬拉松交易預計將於 2026 年年底前完成，須滿足慣常的交割條件並獲得監管批准，包括哈特-斯考特-羅迪諾 (Hart-Scott-Rodino) 等候期的屆滿。

風險與觀察重點

• 該筆收購仍需取得監管批准、執行融資安排及滿足其他慣常的交割條件。
• 能否實現預期的綜效與增益，取決於被收購煉油廠、行銷業務與物流資產的成功整合。
• 擬議債務預計將增加至約 38 億美元，使交割後的去槓桿化與現金流執行變得至關重要。
• 高企的 RIN 成本仍是煉油利潤的主要壓力來源。此項收購將透過提升混合能力來減少 CVR Energy 的未避險 RIN 風險敞口，但合併後的業務不會成為 RIN 的淨多頭。
• 煉油利潤仍受波動的原油與成品油市場影響。管理層對未來 12 至 24 個月利潤保持高位的預期，部分是基於全球供應中斷與低庫存。
• 該交易預估的效益、綜效、增益與交割時程表均屬於前瞻性陳述，並面臨執行風險。

分析師問答亮點

管理層表示，其中期週期估值框架採用約 10 年的歷史裂解價差，並針對 RIN 波動進行調整。對於被收購的資產，其預估的中期週期盈餘水平被描述為可能接近分析師所提及約 4 億美元數字的兩倍。管理層亦認為未來的中期週期利潤可能會高於歷史水平，儘管談判估值中未包含最近的市場上漲空間。

收購的煉油廠每日加工約 12.6 萬桶巴肯 (Bakken) 原油與略低於 5 萬桶的加拿大原油。加拿大原油產量中約有一半為 WCS 或其他重質原油。

管理層指出，歷史上被收購資產的產品中僅約 15% 進入大宗市場。曼丹 (Mandan) 作為北達科他州唯一的煉油廠，受惠於在地產品分銷；而聖保羅公園 (St. Paul Park) 則服務於具吸引力的大都會機架 (rack) 批發市場。

被收購的營運項目為行銷業務，而非零售門市業務。CVR Energy 期望對產品銷售與調配有更大的控制權，以獲取額外利潤並減少其合併後的未避險 RIN 風險敞口。

曼丹 (Mandan) 獲得了其 2023 年、2024 年及 2025 年義務 50% 的小型煉油廠豁免。管理層在收購估值中並未納入未來的豁免，這意味著任何額外的寬減都將構成其假設的潛在利多。

CVR Energy 已在其預測中納入馬拉松目前計畫的資本項目。管理層表示，這些資產維護良好，近期的優先事項集中於成功整合而非重大結構調整，不過公司會考慮更長期的項目，例如聖保羅公園 (St. Paul Park) 的焦化爐 (coker)。

法說會完整逐字稿

完整財報電話會議逐字稿

管理層陳述

Operator

Hello, everyone. Thank you for joining us, and welcome to CVR Energy's Third Quarter 2026 Earnings Call. [Operator Instructions]

I will now hand the conference over to Richard J. Roberts, Chief Financial Officer. Richard, please go ahead.

Richard Roberts

Thank you. Good morning, everyone. We very much appreciate you joining us this morning for our CVR Energy Third Quarter 2026 Earnings Call. With me today are Dane Neumann, our Chief Executive Officer; Mike Wright, our Chief Operating Officer; and other members of management.

Today, we announced our agreement to acquire 2 refineries from Marathon Petroleum, and we have posted a presentation on the Investor Relations section of our website. We will refer to that presentation during our prepared remarks.

Prior to discussing our 2026 third quarter results, let me remind you that this conference call may contain forward-looking statements as that term is defined under federal securities laws. For this purpose, any statements made during this call that are not statements of historical facts may be deemed to be forward-looking statements. You are cautioned that these statements may be affected by important factors set forth in our filings with the Securities and Exchange Commission and our latest earnings release. As a result, actual operations or results may differ materially from the results discussed in the forward-looking statements. We undertake no obligation to publicly update any forward-looking statements, whether as a result of new information, future events or otherwise, except to the extent required by law.

This call also includes various non-GAAP financial measures. The disclosures related to such non-GAAP measures, including reconciliation to the most directly comparable GAAP financial measures, are included in our 2026 third quarter earnings release that we filed with the SEC and Form 10-Q for the period and will be discussed during the call.

In addition, our remarks today include forward-looking statements regarding the proposed acquisition, including its expected benefits, synergies, accretion, financing and timing to close. These statements are subject to risks and uncertainties, including the satisfaction of customary closing conditions and regulatory clearance, our ability to finance the transaction and to integrate the acquired assets and the other factors described in our press release and SEC filings.

With that said, I'll turn the call over to Dane.

Dane Neumann

Thank you, Richard. Good morning, everyone, and thank you for joining our earnings call. This is a historic day for CVR Energy as we announced the largest acquisition in the company's history, along with a record earnings quarter on both a consolidated basis and in the Refining segment. We are also pleased to announce a third quarter 2026 dividend of $0.10 per share. We believe current market conditions, along with the platform expansion opportunities afforded by this transaction, generate tailwinds for our business that should create tremendous value for our shareholders. Before Richard takes you through the quarter, I want to spend a few minutes on the news we announced this morning.

Starting on Slide 2 of the presentation, CVR Energy has entered into a definitive agreement to acquire Marathon's St. Paul Park, Minnesota and Mandan, North Dakota refineries, along with their associated marketing business and certain logistics assets for total consideration of approximately $4.2 billion, subject to certain customary closing adjustments. The 2 refineries have a combined nameplate crude capacity of approximately 177,000 barrels per day with St. Paul Park at 105,000 and Mandan at 72,000. Combined with Coffeyville and Wynnewood, our crude processing capacity would increase from approximately 207,000 to approximately 384,000 barrels per day.

This is a transformative acquisition for CVR Energy, nearly doubling our refining capacity, enhancing our geographic scope and diversifying our distribution footprint through a highly complementary marketing and logistics platform. The transaction implies an asset acquisition multiple of less than 3.5x management's estimate of 2026 EBITDA for the acquired business. For the 9 months ended September 30, 2026, on a pro forma basis, giving effect to the transaction, CVR's EBITDA increased from approximately $900 million on a stand-alone basis to approximately $2 billion and diluted earnings per share increased from $3.73 on a stand-alone basis to $7.67. Further, we expect the transaction to be greater than 50% accretive to CVR's earnings and free cash flow in the first full year after closing.

We intend to fund the transaction with a mix of common equity, cash and debt, and we plan to redeem our outstanding 2028 senior notes. The equity portion is intended to be funded by a large common equity investment from Trafigura, along with a $500 million equity commitment from IEP and approximately $650 million of cash from the CVI balance sheet. We have $2.5 billion of committed bridge financing from our banks, which we expect to replace with syndicated secured debt financing prior to closing, and we expect to draw $300 million on an upsized $1.1 billion ABL facility.

We also expect to equally and ratably secure our 2031 and 2034 senior notes upon the completion of the permanent financing. Pro forma for the transaction, we expect total debt, excluding CVR Partners of approximately $3.8 billion at closing, less than 2x our estimated 2026 consolidated pro forma EBITDA. We remain committed to a strong balance sheet, and we intend to capitalize on the above mid-cycle margin environment to further reduce leverage.

As the potential transaction is absorbed, we also see potential to substantially improve our corporate credit rating profile. The transaction has been unanimously approved by our Board of Directors and is expected to close by year-end 2026, subject to customary closing conditions and regulatory clearance, including expiration of the waiting period under the Hart-Scott-Rodino Act.

Turning to Slide 3. This is a unique opportunity for us to acquire high-quality geographically advantaged assets from an established operator at a compelling valuation. This transaction would expand our footprint to new geographic areas across the Upper Midwest and Northern Great Plains regions, broadening our exposure to regional transportation fuel demand and expanding our presence across the broader PADD II region.

From an operations perspective, these assets are similar to what we own and operate today, medium-sized inland refineries with advantaged crude access via Bakken and Canadian crude oil processing. They are also well-maintained assets, supported by strong historical investment by Marathon that drove average utilization levels over the past 5 years in the high 90s. The transaction would include Marathon's associated marketing business with up to 590 branded locations across the Upper Midwest and Northern Great Plains regions and long-standing relationships with strategic counterparties. It gives us a diversified distribution mix across gasoline, ultra-low sulfur diesel, jet fuel and asphalt in new geographies through a combination of local rack sales and wholesale channels and a platform for potential expansion into our existing footprint.

The business also has high blending capacity, which would increase our internal RIN generation capability and reduce some of our reliance on third-party RIN purchases, potentially further improving the overall RIN exposure of the company on a consolidated basis. I would also note that Mandan has received a small refinery exemption for 50% of their 2023, 2024 and 2025 obligations. Additionally, a larger, more diversified asset base would support more durable free cash flow through the cycle, enhanced balance sheet flexibility and more sustainable capital returns. This should also mitigate the volatility inherent in our smaller existing system. We expect to see approximately $70 million in cost and operational synergies on an annual run rate basis. Ultimately, we believe a larger platform improves our positioning for future growth, supported by a larger and more diversified shareholder base.

Turning to Slide 5. We believe this transaction comes at an attractive point in the cycle with a compelling forward margin environment. The ongoing conflicts in Russia, Ukraine and the Middle East continue to drive volatility across crude oil and refined product markets. Disrupted shipping through the Strait of Hormuz, combined with damage to refineries in the Middle East and Russia continues to constrain global refined product supply. Even if an effective reopening of the strait eases crude supply constraints, we believe refined product prices could stay elevated for longer as damaged refineries must be repaired and global inventories rebuilt. We think global supply dislocations and historically low inventory levels support a higher than mid-cycle margin environment for at least the next 12 to 24 months.

Looking at the U.S., the domestic refining fleet ran hard in the third quarter as companies deferred maintenance and maximize throughput volumes to keep product supply flowing to meet the needs of consumers. U.S. refinery utilization averaged 96% in the quarter, well above the 5-year average of 92% for the same time period. Despite the high utilization, refined product inventories have continued to decline due to resilient demand trends and increased refined product exports. Domestic gasoline inventories are currently 5% below the 5-year average and distillate inventories are 9% below the 5-year average. Exports of gasoline and diesel from the U.S. averaged 2.9 million barrels per day for the third quarter, an increase of nearly 20% from the third quarter of 2025.

Slide 6 shows how PADD II refining dynamics reflect similar trends with supply-demand fundamentals and widening light heavy differentials supporting margins in the region.

Before we speak to our third quarter results, I want to recognize the employees at St. Paul Park and Mandan, who have built a long record of safe and reliable operations, along with the team at CVR Energy that has worked tirelessly on this transaction. We look forward to welcoming these new employees to CVR Energy following our closing, and our focus between now and closing will be a seamless transaction for our new colleagues and customers.

Now let me turn the call over to Richard to discuss our third quarter results.

Richard Roberts

Thank you, Dane, and good morning, everyone. Turning to our third quarter results highlighted on Slide 10. For the third quarter of 2026, our consolidated net income was $563 million, earnings per share was $5.67 and EBITDA was $804 million. Our third quarter results include a favorable change in our RFS liability of $314 million, favorable inventory valuation impacts of $35 million and unrealized derivative losses of $127 million. Excluding the above-mentioned items, adjusted EBITDA for the quarter was $582 million and earnings per share was $4. Adjusted EBITDA in the Petroleum segment was $565 million for the third quarter compared to $120 million for the third quarter of 2025. Elevated Group 3 crack spreads and higher throughput volumes drove the majority of the increase from the prior year period, offset somewhat by higher RIN expenses and realized derivative losses.

Combined total throughput for the third quarter of 2026 was approximately 228,000 barrels per day. Crude utilization for the quarter was approximately 105% of nameplate capacity and light product yield was 93% on total throughput volumes. The Group 3 2-1-1 averaged $68.50 per barrel for the third quarter of 2026 compared to $25.94 per barrel in the third quarter of 2025.

Our third quarter realized margin adjusted for the change in RFS liability, inventory valuation and unrealized derivative losses was $34.97 per barrel, representing a 51% capture rate on the Group 3 2-1-1 benchmark. RIN price increased significantly from third quarter 2025 levels, up over 125% to average over $14 per barrel for the third quarter of 2026. Net RIN expense for the quarter, excluding the change in RFS liability, was $235 million or $11.20 per barrel, which negatively impacted our capture rate for the quarter by approximately 16%.

The estimated accrued RFS obligation on the balance sheet was $230 million at September 30, representing 113 million RINs mark-to-market at an average price of $2.04. We were pleased with the EPA's decision in August to grant Wynnewood Refining Company a full SRE for its 2025 obligation, which reduced the RFS liability on the balance sheet by $253 million. We appreciate EPA's recognition that Wynnewood Refining Company is disproportionately economically harmed by the RFS and deserves full relief. However, the exorbitant cost of RINs continues to disproportionately harm small and merchant refineries like ours, along with American consumers as RINs currently represent roughly $0.28 of every gallon that hits the pump. If the President wants to lower the price of fuel today, he should pull the only lever he can that doesn't need an act of Congress, exercise of the EPA administrator's existing RFS waiver authority.

Our third quarter 2026 results include derivative losses totaling $259 million, comprised of a $133 million realized loss and a $127 million unrealized loss. For the fourth quarter of 2026, we have approximately 2.3 million barrels of diesel hedged with a total notional value of approximately $93 million. For 2027, we have approximately 3.2 million barrels of diesel hedged fairly ratably across the year.

Direct operating expenses in the Petroleum segment were $6.15 per barrel for the third quarter compared to $5.69 per barrel in the third quarter of 2025. The increase in direct operating expenses per barrel was primarily due to increased personnel expense, largely due to share-based compensation.

Adjusted EBITDA in the Fertilizer segment was $20 million for the third quarter compared to $71 million for the prior year period. Ammonia utilization rate was 80%, which was impacted by the planned turnaround at East Dubuque during the quarter. The Board of Directors of CVR Partners General Partner declared a distribution of $1.79 per common unit for the third quarter of 2026. As CVR Energy owns approximately 37% of CVR Partners common units, we will receive a proportionate cash distribution of approximately $7 million.

Cash flow from operations for the third quarter of 2026 was $655 million and free cash flow was $593 million. Significant uses of cash in the quarter included $61 million of capital spending, $46 million of cash interest, $41 million paid for the noncontrolling interest portion of the CVR Partners' second quarter 2026 distribution and $10 million for dividends. Total consolidated capital spending on an accrual basis was $58 million, which included $22 million in the Petroleum segment and $35 million in the Fertilizer segment. For the full year 2026, we estimate total consolidated capital spending to be approximately $220 million to $240 million.

Turning to the balance sheet. We ended the quarter with a consolidated cash balance of $1.3 billion, which includes $158 million of cash in the Fertilizer segment. Total liquidity as of September 30, excluding CVR Partners, was approximately $1.7 billion, which was comprised primarily of $1.1 billion of cash and availability under the ABL facility of $530 million.

Looking ahead to the fourth quarter of 2026 and excluding the acquired Marathon assets for our Petroleum segment, we estimate total throughput to be approximately 210,000 to 225,000 barrels per day, direct operating expenses to range between $115 million and $125 million and total capital spending to be between $45 million and $55 million. For the Fertilizer segment, we estimate our ammonia utilization rate to be between 88% and 93%, which will be impacted by the completion of the East Dubuque turnaround in October. We estimate direct operating expenses, excluding inventory and turnaround impacts, to be between $58 million and $63 million, turnaround expenses to be between $4 million and $6 million and total capital spending to be between $26 million and $34 million.

With that, Dane, I'll turn it back to you.

Dane Neumann

Thank you, Richard. In summary, we delivered a great quarter in refining, and we remain constructive on the outlook for both segments. I would like to thank our employees for all their hard work during the quarter, delivering crude utilization of 105% and completing the East Dubuque turnaround on the revised schedule. Our third quarter results show the benefits of focusing on safe and reliable operations. We continue to believe this up cycle in refining could persist through 2027, and today's announcement is a clear example of our focus on pursuing accretive growth opportunities intended to add value for our shareholders.

We have approached the Marathon acquisition with discipline. We underwrote it on historical mid-cycle earnings rather than today's elevated margins and at less than 3.5x our estimates of 2026 EBITDA that includes both Refining and Marketing, we consider the transaction to be extremely compelling for CVR Energy through the cycle with the current environment as upside. Subject to closing, we look forward to welcoming the St. Paul Park and Mandan employees to CVR Energy.

With that, operator, we are ready for questions.

Operator

[Operator Instructions] Your first question comes from the line of Matthew Blair with TPH.

分析師問答

Matthew Blair

Congrats on the strong quarter. I think you mentioned at the end that this transaction was predicated on mid-cycle economics. Maybe you could talk a little bit about what your assumptions are for mid-cycle. If we look back, it looks like the Mid-Con segment for MPC made about $5 to $6 a barrel in 2024 and 2025, which I think, if I'm doing the math correctly, would put the EBITDA around $400 million. Does that seem reasonable for a mid-cycle environment? Or are you projecting something higher?

Richard Roberts

Matthew, yes, the idea of mid-cycle and refining is something that we talk about every quarter. I would say from a historical basis, not taking into account any of the changes in refining fundamentals recently, looking back over a 10-year period, that's typically the way we view mid-cycle. We look at a 10-year period of cracks, adjust that for the RIN component since the RVO has been so volatile and then gross that up with the current RIN price on a go-forward basis, we get to a number probably close to double that, that you threw out for a historical mid-cycle basis on these assets.

I think our view is that given all the changes in the global refining supply-demand picture recently, that the go-forward mid-cycle is probably higher than the historical mid-cycle. But I would point out, too, that the negotiations on these assets started before the Ukraine war kicked off. So all of the upside that we've seen in the market here recently and that we're looking forward to for the next couple of years most likely, really wasn't factored into the valuation that we had here.

Matthew Blair

Okay. Sounds good. And then could you talk a little bit about the crude slate and then the product exposure for the acquired refineries. I think I remember the St. Paul Park refinery running about 1/3 WCS. And so I guess that would put the total crude slate for the package at maybe roughly 20% WCS, 80% Bakken. Is that reasonable?

And then on the product exposure, I thought that these refineries also sold into the Mid-Con Group 3 product market like your existing system. So what is a good approximation for the split between Mid-Con and Midwest exposure for the acquired assets on the product line?

Dane Neumann

Yes, Matt, this is Dane. So total crude throughput for the acquired assets, call it, around 175,000 barrels a day. Bakken is about 126,000 of that, just approximately. And then total Canadian just under 50,000 barrels and half of that Canadian would be WCS or heavy. So -- and then on the, call it, the product side, these assets actually, with their wholesale marketing and strong, call it, presence of distribution in the, call it, the northern part of the Mid-Con -- there's really historically about 15% of their product that ends up, kind of, in that bulk market, so substantially lower than ours, and they have significantly more advantaged product placement.

North Dakota, obviously, the only -- sorry, Mandan is the only refinery in North Dakota and can place the majority of its product in relatively local areas. And then St. Paul Park has a really attractive metropolitan area that allows it to place the majority of its product over the rack. So from a marketing perspective, substantially different than what we have in our existing business today and don't really see a significant amount of overlap or bulk market volumes.

Operator

[Operator Instructions] Your next question comes from the line of Neil Mehta with Goldman Sachs.

Neil Mehta

Congrats on the transaction. I had a couple and I might queue back in here, which is -- the first is just around Mandan. Historically, this has been eligible for a small refinery exemption. Can you remind us that, I believe, has been more partial versus full, but help us size what that's been in terms of a cash flow tailwind? And how does that feed into the way that you thought about valuing these assets?

Dane Neumann

Yes. Thanks, Neil. Yes. So Mandan has received 50% waivers for the '23, '24, '25 period. In terms of our valuation, we actually did not apply any waivers into the go-forward business and any waiver received would be upside from our transaction valuation.

Neil Mehta

That's helpful. And just the follow-up is how do you weigh this relative to the path that you were on around deleveraging? Because you had gotten the balance sheet back into a good place at the precipice of reinstating the dividend. So how do you think about this relative to return of capital?

Dane Neumann

Yes. So Neil, for us, I think that we've all talked a long time that CVI, just kind of as a stand-alone business, always suffered from lack of geography, lack of scale and lack of really controlling the barrel downstream of this. So as this opportunity came up, and again, as Richard pointed out, we believe in an elevated period of time of cracks here for the next year or so or further, taking a little excess leverage and then using the incremental tailwinds we have from the market to get us back to a more normalized level across the entire fleet became the more accretive option for us. So while there is a little bit of excess leverage, if you think about a mid-cycle level on a, call it, LTM or on a '26 estimate or what we believe the '27 environment look like, it seems like a decent leverage target, but we want to continue to work that down over time.

Operator

[Operator Instructions] Your next question comes from the line of Neil Mehta with Goldman Sachs.

Neil Mehta

Can you spend a little bit more time talking about the retail side of the business and the marketing side of the business? A lot of us covered Northern Tier back in the day, and I know that was a business they were looking to grow. But just give us a mark-to-market on that -- on those assets and how we should be thinking about that?

Dane Neumann

Yes, Neil. So just to clarify, it's not a retail business and that we don't own the retail stores. It's more...

Neil Mehta

As a marketing...

Dane Neumann

Marketing [indiscernible]. So for one, that's a business we don't have today in our existing assets in the Southern Mid-Con and Group 3. So there is some margin that we're giving up between where we're selling in the bulk market and where that product ends up to the ultimate retailer. So by controlling that piece of the value chain, there's some incremental margin that we get to capture there. In addition to that or as part of that, which is actually a pretty meaningful piece, is the RIN generation that comes along with controlling that piece of the business, along with the significant rack sales relative to what we have today.

So I think we mentioned in the prepared remarks, but on a go-forward basis, even not giving credit to the SREs that we've gotten at Wynnewood and that Mandan has received, our consolidated RIN obligation would go down quite a bit just from the additional blending. And as you layer in those potential additional SRE benefits that it goes even lower. So incremental margin there just on controlling more of the barrel and where it goes on top of the additional RIN generation.

Operator

Your next question comes from the line of Matthew Blair with TPH.

Matthew Blair

I guess just to clarify on the RIN exposure, are you saying that you can overblend on these assets that you actually are, I guess, net long RINs on the acquired assets? Or maybe I'm misinterpreting here.

Dane Neumann

Yes. No, Matt. It wouldn't be a net long position. The relative blending capacity of the acquired assets is significantly higher than the relative blending capacity of the CVR assets, predominantly the St. Paul Park with that local rack supplying a substantial portion of their volumes. What the RIN exposure comment is, as it relates to the weighted average across the 2 facilities, our percentage will come down in terms of open exposure pretty dramatically.

Matthew Blair

Okay. And then are you expecting any notable capital investments with this acquisition? Just thinking that the St. Paul Park runs a fair amount of WCS, but I believe it still does not have a coker. Would you consider putting in a coker or any other notable capital investments?

Richard Roberts

Thanks, Matt. I'll take that one. Yes, we would consider it. I think that there's -- really that's a pretty heavy lift in terms of capital dollars and really where would that -- how much more of the value would we capture in that mode. Coffeyville, we do have the benefit of having a gasifier fertilizer business right next door and can get a decent netback and that's a good synergy, and we probably don't have that as much. It's a pretty big transportation that they get from St. Paul down. There is capital that is planned, and we put all of the capital that was currently planned with Marathon into our future forecast, and we expect to complete those. Not -- they've done a really good job of maintaining those assets and don't see really a lot of makeup capital like you see in some other assets that go on the market. So excited about these assets the way they are well maintained and reliable. So look forward to working with them. And really, it's more about a successful integration than it is trying to re-kit that right away.

Matthew Blair

Sounds good. And then finally, is there any sort of earn-out on the transaction?

Dane Neumann

No, sir.

Operator

We have reached the end of the Q&A session. I will now turn the call back to Dane for closing remarks.

Dane Neumann

All right. Again, I would like to thank you all for your interest in CVR Energy and our employees for their hard work and commitment towards safe, reliable and environmentally responsible operations. And we look forward to reviewing our fourth quarter 2026 results during our next call in a couple of months. Have a safe day.

Operator

This concludes today's call. Thank you for attending. You may now disconnect.