GENESIS ENERGY LP (GEL): what the price assumes

boothcheck covers GENESIS ENERGY LP (GEL) but does not put one priced-in number on it: here the defensible answer is the evidence rather than a point estimate. boothcheck publishes no house fair value, target price, or buy/sell rating. Narrative composed 2026-07-26.

Generated: 2026-09-07 · Exported: 2026-09-09 · Source: https://boothcheck.com/report/GEL

Headline

What The Price Assumes (Inversion)

The assumption today's price embeds, recovered by inverting the valuation.

The operating-margin figure is value-band context at year 12: derived from the framework's value band, a separate calculation — not part of the priced-in solve.

The price sits below what even a 5%/yr operating-profit decline would warrant; the inversion reports a bound, not a solved growth path.

Solve inputs: computed at a 7% cost of capital with 4% terminal growth over a 5-year stage (computed at the 7% minimum rate; the CAPM rate 4.5% sits below it).

How unusual the bet is: within-range (limited comparison data)

Valuation X-Ray

The price is justified by relative-multiple and growth-DCF; earnings-power land below the price.

How the valuation models price the stock relative to the market price. Price/FV above 1.0 means the market pays more than that lens defends (expensive); at or below 1.0 the lens can defend the price.

Families that justify the price: Relative, Growth Families that call it expensive: Earnings

The models below discount at their own flat-beta convention rates (cost of equity 9.3%, WACC 6.6%); the inversion above states its own rate.

Per-Model Detail (n=13)

Economic-Unit Decomposition (Sum Of The Parts)

The disclosed units share an operating capital structure; consolidated cash-flow lenses remain coherent and the unit split is explanatory.

No total common-equity value is stated. One or more material units lack a supported unit value. The displayed values are an indicative subtotal; consolidated debt and cash cannot be applied to a fraction of the company.

Solvency

Interest expense is not separately reported in the latest filings, so interest coverage cannot be computed.

Bullet Takeaways

• The offshore construction program is finished, and the clearest evidence sits in the revolver: 6.4 million dollars drawn at the end of December 2025 against 291.0 million a year earlier.
• The defining structural risk is contractual rather than competitive, because the partnership's life-of-lease offshore dedications reprice downward at their ten-year anniversaries, and one such step-down helped cut offshore segment margin 18% during 2024.
• Management has guided full-year 2026 Adjusted EBITDA to at or near the midpoint of a range built on 15% to 20% growth over a normalized 2025 baseline of roughly 500 to 510 million dollars.

Bull Case

Look at the revolver first. At the end of December the senior secured credit facility carried 6.4 million dollars of borrowings against 291.0 million a year earlier. Very little a partnership says about its intentions is as informative as what it has quietly stopped borrowing to do. Genesis spent the better part of three years building two things in the Gulf: a roughly 105-mile, 20-inch crude oil pipeline it owns outright, and an expansion of the larger system it owns 64% of. Both are complete. The capital that was going into the seabed now has somewhere else to go, and the annual report names the queue: reducing debt in absolute terms, opportunistically redeeming our Class A Convertible Preferred Units and thoughtfully evaluating increases in our quarterly distributions to common unitholders.

What that construction bought is already showing up. Offshore pipeline transportation segment margin reached $385.7 million in 2025 against $332.8 million the year before, a 16% increase, as two new standalone deepwater developments came on stream. The commercial terms behind them are unusually clean: the partnership entered into definitive agreements to provide transportation services for 100% of the crude oil production associated with two separate standalone deepwater developments. That is not a volume the operator can route elsewhere in a soft market. And it is not finished ramping, with a fifth well potentially drilled and completed as early as the fourth quarter of 2026, at which point one of the two fields is anticipated to approach 50 to 60 MBbls/day.

The distribution history is where the deleveraging thesis stops being a slogan. The payment made on February 13, 2026 for the fourth quarter of 2025 was $0.18 per common unit, a 9% increase on the previous quarter. In the first quarter of 2026 the partnership generated Available Cash before Reserves to common unitholders of $43.8 million, which covered that same $0.18 payment 1.99 times, and operating cash flow of $81.7 million against $24.8 million in the year-earlier quarter.

One structural point is worth keeping in view when comparing this partnership with its neighbours. Fee-based work is 57% of revenue and product sales are 39%, and those product sales are largely back-to-back purchases and resales that pass through at almost no spread. They swell the revenue line without contributing much profit, which is why the partnership's reported margin on revenue lands between the pure toll-road models and the marketing-heavy ones. WMB earns 28.7% on its revenue and KMI 28.7%; PAA earns 3.3% and ET 10.3%. The right comparison for Genesis is not the top of that range or the bottom of it, and reading the middle as mediocrity mistakes a revenue-recognition artifact for an economic one.

Bear Case

The best asset this partnership owns is a set of life-of-lease dedications on deepwater fields, and those dedications are built to get worse with age. At the start of the third quarter of 2024 Genesis reached the 10-year anniversary of a certain existing life-of-lease dedication, which resulted in the contractual economic step-down of the associated transportation rate. Offshore segment margin fell $73.9 million that year, or 18%. No competitor took a barrel. The contract simply repriced itself downward on the calendar it always carried, and the rest of the dedication portfolio has the same clock running underneath it. A moat with an expiry schedule written into the deed is a different asset from one that has to be attacked.

Away from the offshore system the trend lines are not helping. Sulfur services revenues on the partnership's stated basis came to 142.9 million dollars in 2025 against 156.0 million in 2024 and 183.5 million in 2023, a business roughly a fifth smaller across two years. Marine transportation contributed $9.3 million less segment margin in 2025 than in 2024, on slightly lower utilization. Those two lines are the ballast that is supposed to steady the offshore cycle, and both are lighter than they were.

Then there is who gets paid before the common unitholder. Over the twelve months through March, interest expense net ran close to 262.7 million dollars while operating profit on the same trailing basis reached about 312.8 million, so roughly five dollars in six of operating profit went to lenders before anyone else was considered. Behind them sit 15,695,722 Class A Convertible Preferred Units carrying an effective 11.24% distribution rate and a quarterly payment of $0.9473 per unit, which the partnership itself reports as approximately $13.6 million a quarter deducted before common holders see anything. The credit agreement measures the result at a bank leverage ratio of 5.38 times. None of that is a crisis. All of it means the equity is the residual claim on a thin residual.

Which is what makes the embedded assumption less comfortable than it sounds. Today's price asks for essentially no growth in company-wide operating profit, and the partnership has already told the market that one of the two new deepwater fields will contribute $12 million to $15 million less segment margin in 2026 than its original guidance contemplated, after production from that facility declined from unusually strong initial rates. If the downside case runs, what remains outside the operating businesses is modest: equity-method stakes carried near 215.6 million dollars, which bounds the fall without cushioning much of it.

Valuation

Run the quoted price backwards and the assumption it embeds is close to nothing. The market is not paying for company-wide operating profit to compound; it is paying for the profit stream to hold roughly where it is over a five-year window and then settle. That is an unusual thing to find in an energy partnership, and it is the single most important fact about how these units are priced today. Against the pipeline cohort, the multiple carrying that assumption sits in the upper half of the peer range, so the modesty of the growth demand is not the same thing as the units being cheap against comparable names.

The methods split along a clean and explainable line. Peer-multiple approaches and the cash-flow methods both reach the price or land above it. The earnings-power methods land far below, and the reason is arithmetic rather than insight: those methods capitalize GAAP earnings per unit of $0.29, and for a partnership carrying 232.1 million dollars of annual depreciation and amortization on long-lived steel, with a preferred class taking its distribution ahead of the common, per-unit accounting earnings are a poor proxy for what the pipe actually produces in cash. A reader who sees a large gap there should read it as a statement about the accounting, not about the assets.

What the assets do produce is measurable and filed. Adjusted Consolidated EBITDA came to $587.0 million for the twelve months through March 31, 2026 on the credit agreement's definition, against total segment margin of $577.9 million for calendar 2025. Depreciation and amortization of 232.1 million dollars in 2025 is the bridge between that earnings measure and the much smaller operating profit line, and it is a real cost eventually, because deepwater pipe does not last forever even if it lasts a long time.

Solvency is the binding constraint here rather than a footnote to it. The partnership held 4.2 million dollars of cash at the end of March, which is normal for a business that runs on a revolver, but it leaves no buffer independent of that facility. Unit count has been effectively unchanged over the past four years, so nothing in the recent record has been financed by issuing equity to the common. The relevant question is not whether the distribution is covered, because on the partnership's own cash measure it was covered nearly twice over in the first quarter. It is whether the coverage survives the next contractual step-down, and that answer arrives one dedication anniversary at a time.

Catalysts

First-quarter results landed on May 7, 2026 and were the cleanest comparison the partnership has had in a while. Net income attributable to Genesis Energy was $6.8 million, against a net loss of $469.1 million in the same quarter of 2025. Operating cash flow was $81.7 million versus $24.8 million a year earlier. Total segment margin came to $156.4 million and Adjusted EBITDA to $140.9 million.

Management framed the year rather than the quarter. Full-year 2026 Adjusted EBITDA is expected at or near the midpoint of a range contemplating 15% to 20% growth over a normalized 2025 baseline of approximately $500 to $510 million, with the chief executive describing the first quarter as shaped by the timing of producer turnarounds and a heavier marine dry-docking calendar. The one genuine guidance change was specific: roughly $12 million to $15 million less segment margin from the Shenandoah development in 2026 than originally contemplated, after production declined from unusually high initial rates.

The forward schedule around that same field is dense and dated. The operator has a rig on location for two wells in the Monument tie-back, one scheduled by the end of this year and the second early in 2027, with two further wells planned at Shenandoah across 2027 and a sub-sea pumping system expected in early 2028. The floating production unit's operator is working to expand total crude oil handling capability to 140 thousand barrels a day, and every one of those barrels is contracted to move through the partnership's wholly owned lateral and then its 64% owned trunk line to shore.

Peer Cohorts (Per Segment, With Filing Citations)

Offshore Pipeline Transportation / Marine Transportation / Onshore Transportation and Services (reported)

• WMB (WILLIAMS COMPANIES, INC.)
• FY2025 10-K: …gas gathering lines to report incidents and file annual reports. The final rule also established a new Type C regulated gathering line and now requires Type C gathering lines to comply with specifically identified PHMSA regulations in 49 Code of Federal Regulations Part 192. Since the rule was published, Williams has…
• FY2025 10-K: …in Other. 112 Table of Contents Notes (Continued) Transmission, Power & Gulf is comprised of interstate natural gas pipelines and their related natural gas storage facilities including Transco, NWP, and MountainWest Pipelines Holding LLC (MountainWest) and a 50 percent equity-method investment in Gulfstream Natural…
• OKE (ONEOK INC /NEW/)
• FY2025 10-K: . See further discussion in the "Regulatory, Environmental and Safety Matters" section. Natural Gas Pipelines Overview of Operations - In our Natural Gas Pipelines segment, we receive residue natural gas from third parties and our own natural gas processing plants and interconnecting pipelines. Residue natural gas is…
• FY2025 10-K: …areas in Canada and the United States via our interstate and intrastate natural gas pipelines, Northern Border and Matterhorn, which enables us to provide essential natural gas transportation and storage services. Growing demand from data centers and continued demand from local distribution companies,…
• KMI (KINDER MORGAN, INC.)
• FY2025 10-K: …and governmental regulations, the ability to convert to alternative fuels, and weather. 9 Products Pipelines Our Products Pipelines business segment consists of our refined petroleum products, crude oil, and condensate pipelines, and associated terminals, our condensate processing facility, and our transmix…
• FY2025 10-K: …income, and cash flows from our businesses that produce, process, or purchase and sell crude oil, NGL, or natural gas, and could have a material adverse effect on the carrying value (which includes assigned goodwill) of our CO 2 business segment's proved reserves, and to a lesser extent, certain assets in certain…
• TRGP (TARGA RESOURCES CORP.)
• FY2025 10-K: …perform receipt, delivery and transportation services in order to meet refinery demand. Commercial Transportation Our NGL transportation and distribution infrastructure includes a wide range of assets supporting both third-party customers and the delivery requirements of our marketing and asset management business.…
• FY2025 10-K: …wildfires and wintry conditions and could have an adverse effect on our infrastructure or continued operations as well as the operations of our oil and gas exploration and production customers that deliver natural gas to us for processing and throughput, our third party vendors that supply us with goods, utilities…
• ET (ENERGY TRANSFER LP)
• FY2025 10-K: …based on the actual throughput of natural gas by the customer, (iii) fuel retention based on a percentage of gas transported on the pipeline or (iv) a combination of the three, generally payable monthly. We also generate revenues and margin from the sale of natural gas to electric utilities, independent power plants,…
• FY2025 10-K: …Energy Transfer operates one of the largest intrastate pipeline systems in the United States, which provides energy logistics to major trading hubs and industrial consumption areas throughout the country. In Texas, our intrastate transportation and storage segment provides transportation of natural gas to major…
• EPD (ENTERPRISE PRODUCTS PARTNERS L.P.)
• FY2025 10-K: …service in the first half of 2026. Crude Oil Pipelines & Services This business segment includes our crude oil pipelines, crude oil storage and marine terminals, and related crude oil marketing activities. Crude oil pipelines We have crude oil gathering and transportation pipelines located in Oklahoma, New Mexico and…
• FY2025 10-K: …based on either tariffs regulated by governmental agencies or contractual arrangements. Under certain agreements, customers are required to ship a minimum volume over an agreed-upon period, with make-up rights. Revenue attributable to such agreements is initially deferred and subsequently recognized at the earlier of…
• PAA (PLAINS ALL AMERICAN PIPELINE LP)
• FY2025 10-K: …facilities. We also generate significant revenue through a variety of commercial and merchant activities that often result in increased utilization of our transportation and storage assets. Crude Oil Segment Assets Overview As of December 31, 2025, the assets utilized in our Crude Oil segment included the following:…
• FY2025 10-K: …users. Although new pipeline projects represent a source of competition for our business, existing third-party owned pipelines with excess capacity in the vicinity of our operations also expose us to significant competition based on the relatively low operating cost associated with moving an incremental barrel of…

Methodology Note

• Priced-in inversion: the valuation is inverted on the current price to recover the operating-income growth, duration, and steady-state margin the price embeds (ROE for financials, FFO growth for REITs).
• Valuation x-ray: the valuation models, grouped into four families (asset, earnings, relative, growth). Each model is expressed as a price/FV ratio (distance from price), not a point fair-value estimate. The spread across families is the disagreement.
• Economic-unit decomposition (SOTP): each disclosed business unit is assigned its native valuation basis before any multiple is applied. Operating units are valued on enterprise value; funded financial units are valued on their own common equity, because their borrowings fund earning assets rather than levering the parent. A company total is stated only once every material unit carries a supported value and the parent capital bridge reconciles.
• Solvency: net cash/debt, net-debt-to-NOPAT, interest coverage, and share-count CAGR from EDGAR financials (net debt / FFO and fixed-charge coverage for REITs; regulatory-capital framing for financials).
• Peer cohorts: per-segment comparables with deep-linkable SEC filing citations.

Fundamentals sourced from SEC EDGAR filings. Current price from Databento. The priced-in inversion and valuation x-ray are computed by the boothcheck engine; narrative composed by AI from the structured data.