Kinder Morgan, Inc. · NYSE:KMI
Kinder Morgan — Q4 2025 Earnings Presentation
38 slides from Kinder Morgan's earnings presentation, Jan 21, 2026
Slide 1: 4Q 2025 Investor Presentation
4Q 2025 Investor Presentation December Update EPNG Mojave Compressor Station
Slide 2: Disclosure
Disclosure Forward-Looking Statements / Non-GAAP Financial Measures / Industry & Market Data General – The information contained in this presentation does not purport to be all-inclusive or to contain all information that prospective investors may require. Prospective investors are encouraged to con
Slide 3: 2026 Guidance
2026 Guidance Robust Natural Gas Market Fundamentals Supporting Sustained Growth and Attractive Investment Opportunities Variance to Key Metrics 2026 Budget 2025 Forecast Adjusted EPS $1.37 +8% Increase driven primarily by continued execution on expansion projects in our Natural Gas segment Adjusted
Slide 4: Irreplaceable Infrastructure Portfolio
Irreplaceable Infrastructure Portfolio NATURAL GAS Delivering Energy. Improving Lives. Largest U.S. Natural Gas Transmission Network(a) — ~58,500 miles of transmission & ~7,500 miles of 65% gathering pipelines — Transport ~40% of U.S. natural gas production — Interest in over 700 bcf of working stor
Slide 5: Driving Long-Term Shareholder Value
Driving Long-Term Shareholder Value Predictable & Natural Gas Balance Sheet High-Returning Returns to Growing Cash Focus Strength Growth Projects Shareholders Flows ~2/3 of cash flows ~69% of cash flows ~3.8x YE 2025B Net Increasing dividend come from are take-or-pay or Debt / Adjusted for 8th strai
Slide 6: Highly Contracted, Predictable Cash Flows
Highly Contracted, Predictable Cash Flows CASH FLOW MIX 95% Take-or-Pay, Fee-Based, or Hedged Cash Flows Unhedged Hedged 5% 5% Take-or-Pay 64% Entitled to payment regardless of throughput Reservation fee for capacity Fee-Based Fee-Based 26% Fixed fee collected regardless of commodity price Volumetri
Slide 7: Strong Business Mix Continues to Improve
Strong Business Mix Continues to Improve BUSINESS MIX Natural Gas Transmission & Storage Natural Gas G&P CHANGES SINCE 2014 CO2 Refined Products Natural Gas Transmission & 27% Steady 26% Storage increased +16% 9% 19% -10% 6% Natural Gas G&P decreased -5% -5% 11% NATURAL GAS CO2 reduced -10% 59% 43%
Slide 8: Growing Our Project Backlog While Maintaining Discipline on Returns
Growing Our Project Backlog While Maintaining Discipline on Returns PROJECT BACKLOG OVER TIME(a) $ Billion Expansive footprint creates opportunities for Natural Gas Segment Other Segments differentiated returns $9.3 Natural gas backlog up $8.1 Every project must meet disciplined return +$6.2 billion
Slide 9: $9.3bn Committed Growth Capital Project Backlog as of 9/30/2025
$9.3bn Committed Growth Capital Project Backlog as of 9/30/2025 ~20% of Backlog Capital in Service Between 4Q 2025 and 2026 $ million TOTAL Natural Gas (excluding G&P) $7,566 Nearly all serving Power, LDC, and LNG demand Other 363 Primarily refined product projects Subtotal $7,929 Contracted, stable
Slide 10: Extensive Network Well-Positioned to Serve Growing U.S. Natural Gas Demand
Extensive Network Well-Positioned to Serve Growing U.S. Natural Gas Demand U.S. NATURAL GAS DEMAND bcfd U.S. NATURAL GAS TRANSMISSION KMI Wood Mackenzie PIPELINE MILEAGE BY OPERATOR(a) 140 +28 bcfd New Infrastructure Will The Scale and Connectivity Be Needed to Support 135 58,500 +22 bcfd of Our Foo
Slide 11: WoodMac Natural Gas Demand Overview: 2024 – 2030
WoodMac Natural Gas Demand Overview: 2024 – 2030 ~85% of Growth is Expected to Occur in Texas & Louisiana, Driven by LNG Exports & Industrial 2024 U.S. Demand 110 bcfd Increase in demand by 2030 +22 bcfd LNG Feedgas 1 +15 bcfd of Gulf Coast demand growth Well positioned to grow our deliveries over t
Slide 12: LNG Exports Driving Natural Gas Demand Growth
LNG Exports Driving Natural Gas Demand Growth Growth Primarily Along the Texas & Louisiana Gulf Coast with Great Overlap with Our Assets MEP WOODMAC U.S. LNG FEEDGAS SNG FORECAST bcfd Louisiana Mississippi NGPL KMI has long-term contracts to move ~8 bcfd to TGP facilities today & ~12 bcfd by the end
Slide 13: Growing Power Needs Boosting Demand for Natural Gas
Growing Power Needs Boosting Demand for Natural Gas INCREASING NATURAL GAS FIRED POWER DEMAND DRIVEN BY >50% of contracted Population Migration Coal-to-Gas Industrial Renewable Data Center $9.3bn project & Economic Growth Conversions Reshoring Backup Demand backlog directed to power generation & uti
Slide 14: Rising Need for Natural Gas Amid Growing Market Volatility
Rising Need for Natural Gas Amid Growing Market Volatility Lower 48 Natural Gas Demand(a) vs. Average Daily Temperature Natural gas demand for a given 2024 2019 2014 2009 degree day continues to increase 145 Increasingly variable demand leads 130 to greater spikes in demand Weather-driven demand 115
Slide 15: WoodMac Natural Gas Supply Overview: 2024 – 2030
WoodMac Natural Gas Supply Overview: 2024 – 2030 2024 U.S. Production 103 bcfd Increase in supply by 2030 +22 bcfd 5 Northeast +7 bcfd from the Marcellus/Utica 1 Production constrained despite ample, low-cost supply 5 Limited infrastructure opportunity despite strong demand 5 1 Permian +7 bcfd of as
Slide 16: Natural Gas Segment Overview
Natural Gas Segment Overview Connecting Key Natural Gas Resources with Major Demand Centers Largest Natural Gas Transmission Network in the U.S.(a) KMI Transports ~40% of U.S. Natural Gas Production ~45% ~50% ~45% of all feedgas of all U.S. natural of all direct natural deliveries to U.S. gas export
Slide 17: Rising Demand Benefitting Our Natural Gas Transportation Business
Rising Demand Benefitting Our Natural Gas Transportation Business INCREASED PIPELINE USAGE FACTOR(a) 2016 5-Pipe 2024 5-Pipe Increased Demand Leading To Average Average WOODMAC U.S. NATURAL GAS DEMAND 74% 87% bcfd +20% INCREASED CONTRACT TERMS AND/OR RATES +38% EXAMPLES 8.1 132 7.3 years years 110 5
Slide 18: ~$8.4 Billion of Approved Natural Gas Projects
~$8.4 Billion of Approved Natural Gas Projects Capital(a) Capacity In-Service Primary Major Projects ($bn) (bcfd) Date Driver Pursuing substantial additional 1 South System Expansion 4 4Q28, opportunities beyond those $1.8 1.3 Power SNG & EEC 4Q29 9 currently in our backlog 2 Trident (Phase I & II)
Slide 19: Products Segment & Terminals Segment Overview
Products Segment & Terminals Segment Overview Both Segments Principally Refined Products Focused Nearly $11bn of Adjusted Segment EBDA & $8bn of FCF Generated Over 5 Years (a) TERMINALS & PRODUCTS PIPELINES ADJUSTED SEGMENT EBDA $ Millions NY Harbor Products Segment Terminals Segment $2,263 $2,282 $
Slide 20: CO2 Segment: EOR and CO2 Transport Overview
CO2 Segment: EOR and CO2 Transport Overview World Class, Fully-Integrated Assets Consistently Generating Robust Free Cash Flow CO2 EOR & TRANSPORT FREE CASH FLOW Interest in 3 oil CO2 pipelines $ Millions fields with 8.8 CO2 source fields (a) FCF Capex Acquisitions Adj. Segment EBDA Oil fields billi
Slide 21: CO2 Segment: Energy Transition Ventures (ETV) Group Overview
CO2 Segment: Energy Transition Ventures (ETV) Group Overview Pursuing Commercial Opportunities Emerging from the Lower Carbon Energy Evolution Future RNG CCS Opportunities Established a strategic RNG platform Evaluating commercial Up to 6.4 bcf(a) of opportunities across the Renewable Fuels, with 6.
Slide 22: Committed to Being a Good Steward
Committed to Being a Good Steward $ Reduce & Avoid Leak Continuous Employee Investing in Lower Methane Emissions Detection Improvement Development Carbon Fuels ~10% 100% BB → AAA 283 $8.4bn Reduction in of our natural gas MSCI score Participants in Primarily natural gas; methane emissions compressor
Slide 23: Sustainability Ratings Recognition
Sustainability Ratings Recognition Highly rated by multiple agencies MSCI AAA Sustainalytics Top 10% Oil & Gas Refining, out of 84 Oil & Gas Marketing, Transportation Storage and Transportation Companies & & Storage Industry 166 Refiners & Pipelines Refinitiv #5 S&P Global CSA FTSE #2 of 237 Oil & G
Slide 24: APPENDIX
APPENDIX EPNG McClellan Creek Crossing
Slide 25: Contract Strategy Insulates Cash Flows Through Commodity Cycles
Contract Strategy Insulates Cash Flows Through Commodity Cycles Structure Long-Term Contracts That Minimize Price & Volume Volatility Take-or-Pay or Hedged Fee-Based Commodity- Avg. remaining Volumes & price are Price is fixed, contract term contractually fixed volumes are variable Price Based as of
Slide 26: High-Quality, Natural Gas Focused Cash Flows
High-Quality, Natural Gas Focused Cash Flows G&P 9% Natural Gas Transportation & Storage CASH FLOW MIX(a) – Accounts for 59% of 2025B KMI Adjusted Segment EBDA Remaining KM 35% – 88% take-or-pay cash flows(a) Transportation & Storage – Average remaining contract life: 91% – ~7 years for transportati
Slide 27: Use of Non-GAAP Financial Measures
Use of Non-GAAP Financial Measures Our non-GAAP financial measures described below should not be considered alternatives to GAAP net income attributable to Kinder Morgan, Inc. or other GAAP measures and have important limitations as analytical tools. Our computations of these non-GAAP financial meas
Slide 28: Use of Non-GAAP Financial Measures (Continued)
Use of Non-GAAP Financial Measures (Continued) Amounts Associated with Joint Ventures - Certain Items, DCF and Adjusted EBITDA reflect amounts from unconsolidated joint ventures (JVs) and consolidated JVs utilizing the same recognition and measurement methods used to record “Earnings from equity inv
Slide 29: Net Income, Adjusted EPS, & Adjusted EBITDA
Net Income, Adjusted EPS, & Adjusted EBITDA In Billion 2025 2026 Forecast Budget Net income attributable to KMI $ 2.9 $ 3.1 Total Certain Items (a) - - DD&A 2.4 2.5 Income tax expense(b) 0.8 0.9 Interest, net (b) 1.8 1.8 Amounts associated with joint ventures Unconsolidated JV DD&A (c) 0.4 0.4 Remov
Slide 30: Net Income & Distributable Cash Flow (DCF)
Net Income & Distributable Cash Flow (DCF) In Billion, Except Per Share 2025 2026 Forecast Budget Net income attributable to KMI $ 2.9 $ 3.1 Total Certain Items (a) - - DD&A 2.4 2.5 Income tax expense(b) 0.8 0.9 Cash taxes - - Sustaining capital expenditures (0.9) (0.9) Amounts associated with joint
Slide 31: Net Income, Adjusted Net Income Attributable to KMI, and DCF
Net Income, Adjusted Net Income Attributable to KMI, and DCF $ in Millions 2025 2024 Change Q3 2025 Budget Actual $ % Actual Net income attributable to KMI $ 2,829 $ 2,613 $ 216 8% $ 628 Certain Items Change in fair value of derivative contracts - 72 (72) (100%) 24 Loss on impairment - (69) 69 100%
Slide 32: 2014 and 2025B Reconciliation of Segment EBDA to Adjusted Segment EBDA
2014 and 2025B Reconciliation of Segment EBDA to Adjusted Segment EBDA $ in Millions 2025 2014 2025 2014 (a) (a) Segment EBDA Budget Actual Segment EBDA Budget Actual Natural Gas Pipelines Segment EBDA $ 5,636 $ 4,288 CO2 Segment EBDA 755 1,248 Certain Items (b) Certain Items (b) Contract early term
Slide 33: 2024 Reconciliation of Recasted Adjusted Segment EBDA
2024 Reconciliation of Recasted Adjusted Segment EBDA $ in Millions 2024 2024 (a) (b) Segment EBDA Actual Adjustment Recasted Natural Gas Pipelines Segment EBDA $ 5,427 $ (34) $ 5,393 Certain Items (c) - Change in fair value of derivative contracts 75 - 75 Loss on impairments, divestitures and other
Slide 34: Reconciliation of Adjusted Net Income Attributable to Common Stock and Adjusted EPS
Reconciliation of Adjusted Net Income Attributable to Common Stock and Adjusted EPS $ in Millions 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025B Net income attributable to KMI $ 708 $ 183 $ 1,609 $ 2,190 $ 119 $ 1,784 $ 2,548 $ 2,391 $ 2,613 $ 2,829 NCI associated with Certain Items (8) - - - -
Slide 35: Reconciliations of KMI FCF and CO2 EOR & Transport FCF
Reconciliations of KMI FCF and CO2 EOR & Transport FCF $ in Millions Reconciliation of KMI FCF 2020 2021 2022 2023 2024 2025B CFFO (GAAP) $ 4,550 $ 5,708 $ 4,967 $ 6,491 $ 5,635 $ 5,899 Capital expenditures (GAAP)(a) (1,707) (1,281) (1,621) (2,317) (2,629) (3,141) FCF 2,843 4,427 3,346 4,174 3,006 2
Slide 36: Reconciliations of Terminals FCF and Products Pipelines FCF
Reconciliations of Terminals FCF and Products Pipelines FCF $ in Millions Reconciliation of Terminals FCF 2020 2021 2022 2023 2024 2025B EBDA for Terminals (b) $ 1,045 $ 908 $ 975 $ 1,039 $ 1,099 $ 1,103 Certain items: Loss (gain) on impairments, divestitures and other write-downs, net (55) 34 - - -
Slide 37: Reconciliation of Adjusted EBITDA, Normalized for Divestitures
Reconciliation of Adjusted EBITDA, Normalized for Divestitures $ in Millions Reconciliation of Adjusted EBITDA, Normalized for Divestitures 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025B Net income attributable to KMI $ 708 $ 183 $ 1,609 $ 2,190 $ 119 $ 1,784 $ 2,548 $ 2,391 $ 2,613 $ 2,829 NCI
Slide 38: Reconciliation of Net Debt
Reconciliation of Net Debt $ in Millions Reconciliation of Net Debt 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025B Current portion of debt $ 2,696 $ 2,828 $ 3,388 $ 2,377 $ 2,558 $ 2,646 $ 3,385 $ 4,049 $ 2,009 $ 1,209 Total long-term debt 37,354 35,015 33,936 31,915 32,131 30,674 28,403 28,067