tapebrief

KMI · Q2 2025 Earnings

Bullish

Kinder Morgan

Reported July 16, 2025

30-second summary

Revenue grew 13.1% YoY to $4.04B and the project backlog expanded from $8.8B to $9.3B in the quarter, with roughly half of backlog now tied to power demand rather than LNG feed gas alone. Management reiterated full-year 2025 Adjusted EBITDA of $8.3B and Adjusted EPS of $1.27, and flagged that the Outrigger Energy II acquisition should push results above budget. Tax reform pushes material cash tax payments out to 2028, a structural cash-flow tailwind the market has not fully priced.

Headline numbers

EPS

Q2 FY2025

$0.28

Revenue

Q2 FY2025

$4.04B

+13.1% YoY

Free cash flow

Q2 FY2025

$1.00B

Operating margin

Q2 FY2025

28.5%

Key financials

Q2 FY2025
MetricQ2 FY2025YoY
Revenue$4.04B+13.1%
EPS$0.28—
Operating margin28.5%—
Free cash flow$1.00B—

Guidance

Prior quarter data unavailable — comparison not possible.

Other KPIs

Q2 FY2025
SegmentQ2 FY2025
Adjusted EBITDA$1,972 million
Natural Gas Transport Volumes44,585 BBtu/d
Natural Gas Gathering Volumes3,931 BBtu/d
Total Refined Product Volumes1,710 MBbl/d
Crude and Condensate Volumes503 MBbl/d
Liquids Terminal Capacity Utilization94.4%
Project Backlog$9.3 billion
Net Debt-to-Adjusted EBITDA4.0x

Management tone

Management's framing of the gas business has shifted from cyclical commodity exposure to structural multi-decade growth, and the language is unusually assertive for a midstream operator. CEO Kim Dang's line — "It's an amazing time to be in the natural gas industry. This is certainly the best opportunity set I've seen during my 24 years in this industry" — is not the kind of statement infrastructure CEOs make absent high conviction. The "we aren't in the first inning anymore, but we aren't anywhere near the seventh inning stretch" framing explicitly rejects the narrative that the current LNG/power buildout is late-cycle.

Power demand has been re-cast as a co-equal driver alongside LNG, not a secondary opportunity. Roughly 50% of the backlog now serves power, a meaningful re-weighting that management volunteered without prompting: "the breadth and the scope of the power demand is very enormous." This matters because power-driven projects typically carry different contract structures than LNG feed gas, and the mix shift broadens KMI's customer base beyond a handful of large LNG developers.

LNG demand is now framed in explicitly geopolitical terms. "Customers on the receiving end want security of supply without undue worries about disruptions caused by military actions, and this benefits the position of U.S. supply." This is a rare framing for a regulated infrastructure company and signals management views U.S. LNG export contracts as carrying durability premia beyond pure commercial economics.

Tariff risk has been actively de-escalated. Management quantified the impact at ~1% of large project costs and emphasized that estimate "has not changed from our estimate last quarter" — a deliberate signal that what looked like a tail risk has stabilized into a manageable line item.

Tax reform is being treated as a structural cash-flow accelerator, not a one-time benefit. The expectation of no material cash tax payments until 2028 is a meaningful change in capital allocation flexibility, though management was careful to say it does not change financing strategy.

Recurring themes management leaned on this quarter:

Global LNG demand structural growth driven by emerging market electrification and population growthU.S. geopolitical positioning as secure LNG supplier amid Middle East instabilityPower generation demand acceleration as co-equal driver with LNG for domestic gas growthProject backlog expansion (8.8B to 9.3B) reflecting both LNG feed gas and power plant connectivityTax reform enabling significant cash flow benefits 2026-2027 without changing capital deployment disciplineCompetitive advantage through existing asset footprint and execution track record

Risks management surfaced:

Tariffs on large projects (though estimated at only 1% of costs)Permian pipeline contract roll-off risk in 2029-2030 (GCX and PHPR 10-year contracts expiring)Volume exposure in gathering assets vs. take-or-pay contracts requiring higher return thresholdsData center behind-the-meter opportunities still nascent; IPP participation uncertainCompetitive dynamics on larger projects like Copper State Connector

Q&A highlights

Zach Van Everen · TPH

Asking about Haynesville expansion capacity additions and whether demand is coming from larger customers or private producers feeding the system. Also asked about Tennessee Gas's ability to expand further to feed LNG expansion at Plaquemines facility.

Management confirmed demand is from both larger customers and privates. Woodmac expects Haynesville production to double from 13 to 26 BCF/d by 2034. On LNG expansion, Tennessee is already full in multiple directions but management outlined a series of projects (Texas Access Project, Trident, Header) designed to de-bottleneck and bring incremental gas from west to east, potentially accessing Haynesville from different directions to support Plaquemines expansion.

Haynesville production expected to double from 13 to 26 BCF/d by 2034 per WoodmacTennessee Gas already full in multiple directionsSeries of projects (Texas Access, Trident, Header) planned to de-bottleneck and enable incremental supply flow

Jason Gabelman · TD Cowan

Asked about concerns regarding potential LNG oversupply after current wave of capacity comes online and whether management is hearing slowdown in contracting or need for additional piping, or if LNG customers expect new builds to continue through 2030s.

Management stated they are not seeing slowdown in customer discussions. LNG builders continue announcing new projects and signing contracts. Management attributed this to favorable U.S. building environment, trade balance benefits, and rule of law advantages. Provided long-term view: world LNG demand expected to grow 25% through 2050, with U.S. market share growing as well, creating 'almost a doubling effect.' U.S. advantages include rule of law, advanced infrastructure network, proven developer track record, and abundant supply resources.

Global LNG demand expected to grow 25% between now and 2050U.S. market share growing alongside overall demand growthNo slowdown observed in customer contracting discussionsU.S. LNG expected to grow 'well north' of overall global gas demand growth through 2050

Brandon Bigham · Scotiabank

Asked about incremental LNG opportunities outside Haynesville and which basins are next in line to meet LNG growth. Also asked about areas of 2H outperformance offsetting 1H lighter performance to meet full-year EBITDA guidance.

Management identified lean Eagle Ford as important due to low nitrogen content (better for LNG plant efficiency), Permian, and potential Utica opportunities to move gas south via Tennessee network. Emphasized all-of-above approach serving LNG, power demand, and organic LDC needs. On 2H outperformance: cited natural gas capacity sales, Outrigger contribution, parking loan services, and Jones Act tanker contributions as consistent drivers with some 1H timing impacts.

Lean Eagle Ford prioritized for low nitrogen gas quality beneficial to LNG plantsUtica-to-south gas movement via Tennessee network in early phasesAll-of-above basin approach required to serve LNG, power, and LDC demandKey 2H outperformers: natural gas capacity sales, Outrigger, PALS, Jones Act tankers

Harry Matura · Barclays

Asked whether expanded interest deductibility from reconciliation bill benefits causes management to rethink financing or balance sheet strategy to take greater advantage of tax benefits on interest expense.

Management stated the tax reform does not rethink their financing strategy, which is straightforward and plain vanilla. They can fund $2.5 billion internally from cash flow and use external financing primarily to refinance maturing bonds. The expanded interest deductibility will not influence their approach.

Can fund $2.5 billion internally from cash flow annuallyExternal financing used primarily for bond refinancingNo change to financing strategy from tax reform

What to watch into next quarter

Backlog composition and pace: $9.3B backlog up from $8.8B this quarter. Watch whether additions sustain at $400–500M per quarter and whether the power-demand share holds at ~50% or continues climbing — a power-heavy mix changes the contract duration and counterparty risk profile.

Gathering volumes vs. budget: Management acknowledged gathering volumes are running ~3% below 2025 budget despite being ~3% above 2024. Watch whether the gap to budget closes in H2 or persists as a structural shortfall that pressures FY EBITDA achievement.

Net debt / Adj. EBITDA path to 3.8x: Currently 4.0x. Reaching the FY exit target of 3.8x requires either EBITDA expansion or debt paydown in H2; watch the leverage trajectory in Q3 as a leading indicator of FY guidance achievement.

2026 cash flow uplift from tax reform: Management flagged "significant" benefits in 2026 and 2027 but did not quantify. Watch for a specific dollar range when 2026 budget is communicated, likely Q4.

Permian contract roll-off (GCX, PHPR): 10-year contracts expiring 2029-2030 were named as a risk. Watch for early recontracting signals or rate disclosures in upcoming quarters — material to long-dated cash flow visibility.

Copper State Connector: Management flagged competitive dynamics on this large project. Watch for a final investment decision or contract award announcement that would push backlog meaningfully higher.

Sources

  1. Kinder Morgan Q2 2025 press release / 8-K exhibit, filed July 16, 2025: https://www.sec.gov/Archives/edgar/data/1506307/000150630725000042/kmi2025q28-kex991.htm
  2. Kinder Morgan Q2 2025 earnings call commentary (management prepared remarks and Q&A as referenced in tone and Q&A inputs)

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