TC ENERGY CORPORATION (TRP): what the price assumes

boothcheck covers TC ENERGY CORPORATION (TRP) 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 2026-07-11.

Generated: 2026-08-10 · Exported: 2026-08-12 · Source: https://boothcheck.com/report/TRP

Headline

What The Price Assumes (Inversion)

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

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 8.4% cost of capital with 4% terminal growth over a 5-year stage.

How unusual the bet is: n/a

Valuation X-Ray

The price is justified by relative-multiple and growth-DCF; asset-based 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: Asset

The models below discount at their own flat-beta convention rates (cost of equity 9.3%, WACC 9.1%); the inversion above states its own rate.

Per-Model Detail (n=18)

Economic-Unit Decomposition (Sum Of The Parts)

Only one reportable economic unit is present in the current topology source. Consolidated operating lenses remain available, but there is no multi-unit decomposition.

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

Bullet Takeaways

• TC Energy is a continental natural gas and power infrastructure system that just printed its first quarter above $3 billion of comparable EBITDA, up 14% year over year, with record volumes and a newly approved $1.5 billion Columbia Gas expansion.
• The tension is between the income statement's two layers: operating income grew 0.9% in fiscal 2025 while net income fell 25.1% on below-the-line items, leaving the dividend at 100.5% of trailing GAAP earnings even though operating cash flow of $5.4 billion covers it roughly twice.
• Watch the reaffirmed 2026 guidance of $11.6 to $11.8 billion in comparable EBITDA and the 2028 target of $12.6 to $13.1 billion, against a share price that currently embeds a modest operating decline.

Bull Case

Start with how this management team treats a dollar. The dividend has been raised for 26 consecutive years, a streak that survived commodity crashes, a pandemic, and the company's own balance-sheet repair, and the current $2.50 per share annualized rate yields 3.7%. The capital going the other direction is disciplined and dated: the newly sanctioned $1.5 billion Columbia Gas expansion extends a system whose revenue comes overwhelmingly from capacity arrangements and transportation contracts rather than commodity exposure, and management paired it with reaffirmed guidance rather than stretched promises: $11.6 to $11.8 billion of comparable EBITDA in 2026, building to $12.6 to $13.1 billion by 2028.

The demand side has turned into the strongest gas story in a decade. TC Energy's first quarter set records: comparable EBITDA above $3 billion for the first time, up 14% year over year, with U.S. natural gas pipelines EBITDA rising to $1.50 billion from $1.37 billion and Mexico nearly doubling to $432 million from $233 million. Behind it sits the structural driver: management sees natural gas demand in the U.S. Heartland growing 40% through 2035 on power generation and data-center expansion, demand that lands directly on systems TC already owns. In Canada, new commercial agreements for Coastal GasLink Phase 2 and a developing framework for NGTL expansions add contracted growth on existing corridors, where expansions earn far better returns than greenfield builds.

The price does not reflect the guidance. At about 13x operating income, today's quote embeds operating income shrinking roughly 2.2% a year for five years, while management guides EBITDA up nearly 10% over the next two. Three of the four valuation method families, earnings power, peer multiples, and growth-based approaches, land at or above the current price, with the growth methods supporting levels well above it. Operating cash flow of $5.4 billion funds the capital program and the dividend from internal generation. A regulated-and-contracted asset base, a demand supercycle arriving at its doorstep, and a price calibrated for decline is the kind of mismatch that patient income investors are usually paid to wait out, and at 3.7% they are.

Bear Case

Every gas-infrastructure company in North America is telling the same story right now, and that is precisely the problem. Data-center power demand has become the sector's universal justification for capacity additions: TC's $1.5 billion Columbia expansion, Coastal GasLink Phase 2, prospective NGTL expansions, and parallel buildouts by every major U.S. midstream operator are all being sanctioned against the same forecast of 40% Heartland demand growth through 2035. Infrastructure cycles end the same way each time: the demand estimate is made at the peak of enthusiasm, the capacity arrives years later all at once, and the contracted rates on renewal reflect the surplus. TC's own margin trajectory shows where in the cycle we are, with operating margin at 52.7% in fiscal 2025 versus 19.9% three years earlier; the question a buyer at 27x trailing GAAP earnings should ask is which of those numbers is sustainable mid-cycle.

The income statement already shows strain beneath the operating line. Fiscal 2025 net income fell 25.1% and earnings per share fell 26.2% while operating income grew just 0.9%, a divergence driven by below-the-line items, and it leaves the $2.50 dividend at 100.5% of trailing GAAP earnings. The cash frame is kinder, with $5.4 billion of operating cash flow, but the historical pattern matters: in each of fiscal 2022 through 2024, capital spending consumed more than operating cash flow generated, leaving free cash flow negative while the dividend was paid anyway, which is how the debt got here. Operating income covers interest only about 2.0 times, thin for a company whose composite balance-sheet gauge sits in its warning zone, and the equity multiplier of 4.4x means small changes in asset returns swing equity outcomes hard.

The valuation methods split against the comfortable reading. Asset-based approaches put the price at 2.1x what the recorded asset base supports, meaning the market pays double book-anchored value for regulated assets whose allowed returns are set by regulators, not by data-center enthusiasm. The trailing P/E of 27.1x sits above the 20x sector median. Rate exposure runs through everything: higher-for-longer raises the cost of the perpetual refinancing a 2.0x-coverage balance sheet requires, and utilities-shaped equities de-rate mechanically when bond yields compete with a 3.7% dividend that is currently growing faster than the GAAP earnings covering it.

Valuation

The oddity at $67.32 (July 10, 2026) is that the price and the guidance point in opposite directions. Unwound into assumptions, the market is paying about 13x operating income, which implies operating income declining about 2.2% a year for five years. Management's reaffirmed guidance calls for comparable EBITDA of $11.6 to $11.8 billion this year rising to $12.6 to $13.1 billion by 2028, roughly 4% annual growth. One of those two views is wrong, and the spread between them is the investment case in both directions.

The method families sort accordingly. Earnings-power approaches land at about 1.1x the price, peer multiples at 0.8x, and growth-based methods at 0.7x, all supporting or exceeding the quote; only asset-based methods call it expensive, at 2.1x, which is typical for long-lived pipeline assets carried at depreciated cost far below replacement value. The trailing 27.1x GAAP P/E against a 20x sector median needs its bridge clause: fiscal 2025 earnings per share fell 26.2% on below-the-line items while operating income was flat, so the trailing multiple is inflated by a depressed denominator rather than by an expensive price against operating economics, where the EV/EBITDA read of 9.0x sits below the 13x sector median.

The balance sheet is the discount's justification. Operating income covers interest only about 2.0 times, leverage is meaningful, and the dividend, at $2.50 annualized and 100.5% of trailing GAAP net income, relies on the $5.4 billion of operating cash flow rather than the earnings line, with fiscal 2022 through 2024 each showing capital spending in excess of that cash flow. What the buyer is weighing at this price is a contracted, demand-advantaged asset system, record first-quarter volumes and the first $3 billion EBITDA quarter in company history, against a capital structure that requires the growth to arrive on schedule to keep the 26-year dividend streak funded without more debt.

Catalysts

The first quarter delivered the year's headline early: comparable EBITDA above $3 billion for the first time, up 14% year over year, with revenue of $3.86 billion, record volumes across the gas systems, and a beat against consensus. Alongside the print, TC approved a $1.5 billion expansion of the Columbia Gas system, and the next quarterly reports will track that project's cost and schedule alongside the reaffirmed 2026 guidance of $11.6 to $11.8 billion in comparable EBITDA and higher comparable earnings per share than 2025.

The project pipeline carries the multi-year story. New commercial agreements were reached for Coastal GasLink Phase 2, a new investment framework for NGTL expansions is under discussion in Canada, and management frames the U.S. Heartland as the central opportunity, with natural gas demand there expected to grow 40% through 2035 on power generation and data-center buildout. Sanctioning decisions on any of those fronts are discrete catalysts, as each converts forecast demand into contracted EBITDA. Segment mix is worth watching quarter to quarter: Mexico's EBITDA nearly doubled year over year to $432 million as new assets entered service, and whether that step-change holds is a meaningful swing factor in the 2028 target of $12.6 to $13.1 billion. The dividend, raised for a 26th consecutive year, keeps its own calendar; the next increase announcement, and whether below-the-line drags on GAAP earnings reverse, are the twin signals for income holders.

Peer Cohorts (Per Segment, With Filing Citations)

Mexico Natural Gas Pipelines (reported)

• ENB (ENBRIDGE INC.)
• FY2025 10-K: …pools that include the Marcellus and Utica shale developments, offering consistent supply and stable pricing to a growing population of end-use customers across our multiple systems under long-term, utility-like arrangements. With connectivity to the Appalachian, the Midwest market has access to a low cost gas…
• FY2025 10-K: …over time using an output method based on volumes of commodities delivered or transported. The measurement of the volumes transported or delivered corresponds directly to the benefits received by the shippers or customers during that period. Determination of Transaction Prices Prices for transportation and gas…
• WMB (WILLIAMS COMPANIES, INC.)
• FY2025 10-K: …natural gas pipeline system extending from Texas, Louisiana, Mississippi and the Gulf of America through Alabama, Georgia, South Carolina, North Carolina, Virginia, Maryland, Delaware, Pennsylvania, and New Jersey to the New York City metropolitan area. The system serves customers in Texas and the 12 southeast and…
• 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…
• KMI (KINDER MORGAN, INC.)
• FY2025 10-K: …and Bravo pipelines are in direct competition with other CO 2 pipelines. We compete with other interest owners in the McElmo Dome unit and the Bravo Dome unit for transportation of CO 2 to the Denver City, Texas market area. Major Customers Our revenue is derived from a wide customer base. For each of the years ended…
• FY2025 10-K: …manage the extent to which each shares in the potential risks and benefits of changing commodity prices. Our natural gas marketing activities generate revenues from the sale and delivery of natural gas purchased either directly from producers or from others on the open market. Natural Gas Pipelines Segment…
• EPD (ENTERPRISE PRODUCTS PARTNERS L.P.)
• FY2025 10-K: …Our natural gas transmission pipelines transport natural gas from regional processing facilities to downstream electric generation plants, local gas distribution companies, industrial and municipal customers, storage facilities or other connecting pipelines. The results of operations from our natural gas pipelines…
• FY2025 10-K: …$ 1,501 $ 1,646 Selected volumetric data: Crude oil pipeline transportation volumes (MBPD) 2,578 2,528 Crude oil marine terminal volumes (MBPD) 763 955 Gross operating margin from our Crude Oil Pipelines & Services segment for the year ended December 31, 2025 decreased $145 million when compared to the year ended…
• 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: …through NGL pipelines to fractionation facilities for further processing. In our Natural Gas Liquids segment, NGLs are extracted at our own and third-party natural gas processing plants and are gathered by our NGL gathering pipelines. Gathered NGLs are directed to our downstream fractionators to be separated into…
• ET (ENERGY TRANSFER LP)
• FY2025 10-K: …hubs as well as major western markets in Arizona, New Mexico, Nevada and California. Transwestern's customers include local distribution companies, producers, marketers, electric power generators and industrial end-users. An expansion of the Transwestern Pipeline, including upsizing pipeline diameter to increase…
• 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…
• MPLX (MPLX LP)
• FY2025 10-K: …gain in 2025 related to the formation of a new joint venture, Texas City Logistics LLC. See Supplemental Information on Equity Method Investments for additional information regarding the results of our equity method investments. Segment Adjusted EBITDA increased $81 million in 2025 compared to 2024. The increase is…
• FY2025 10-K: …investments included in the above tables, we also have ownership interests in natural gas and NGL pipeline systems through the following entities: Diameter Length (miles) Ownership Percentage Natural Gas Pipelines: Delaware Basin Residue, LLC (1) 10" - 42" 298 10% MXP Parent, LLC (2) 36" - 42" 580 10% WPC Parent, LLC…
• TRGP (TARGA RESOURCES CORP.)
• FY2025 10-K: …facility design and economies of scale. The Gathering and Processing segment's assets are located in the Permian Basin of West Texas and Southeast New Mexico (including the Midland, Central and Delaware Basins); the Eagle Ford Shale in South Texas; the Barnett Shale in North Texas; the Anadarko, Ardmore, and Arkoma…
• FY2025 10-K: …the RRC. Some of these Texas intrastate pipelines also transport natural gas in interstate commerce pursuant to Section 311 of the Natural Gas Policy Act of 1978 ("NGPA"). Under Sections 311 and 601 of the NGPA, an intrastate pipeline may transport natural gas in interstate commerce without becoming subject to FERC…

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.