B U I L D I N G B R I G H T E R F U T U R E S Goldman Sachs Leveraged Finance and Credit Conference Mark Spurbeck, Chief Financial Officer | May 12, 2022
2 Disclosure Regarding Forward-Looking Statements This presentation contains forward-looking statements within the meaning of applicable securities laws. Forward-looking statements can be identified by the fact that they do not relate strictly to historical or current facts. They often include words or variation of words such as "expects,” "anticipates," "intends," "plans," "believes," "seeks," "estimates," "projects," "forecasts," "targets," "would," "will," "should," "goal," "could" or "may" or other similar expressions. Forward-looking statements provide management's current expectations or predictions of future conditions, events or results. All statements that address operating performance, events, or developments that Peabody expects will occur in the future are forward-looking statements. They may include estimates of sales and other operating performance targets, cost savings, capital expenditures, other expense items, actions relating to strategic initiatives, demand for the company’s products, liquidity, capital structure, market share, industry volume, other financial items, descriptions of management’s plans or objectives for future operations and descriptions of assumptions underlying any of the above. All forward- looking statements speak only as of the date they are made and reflect Peabody’s good faith beliefs, assumptions and expectations, but they are not guarantees of future performance or events. Furthermore, Peabody disclaims any obligation to publicly update or revise any forward-looking statement, except as required by law. By their nature, forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those suggested by the forward-looking statements. Factors that might cause such differences include, but are not limited to, a variety of economic, competitive and regulatory factors, many of which are beyond Peabody’s control, including the ongoing impact of the COVID- 19 pandemic and factors that are described in Peabody’s Annual Report on Form 10-K for the fiscal year ended Dec. 31, 2021, and other factors that Peabody may describe from time to time in other filings with the SEC. You may get such filings for free at Peabody’s website at www.peabodyenergy.com. You should understand that it is not possible to predict or identify all such factors and, consequently, you should not consider any such list to be a complete set of all potential risks or uncertainties.
3 2021 Peabody Quick Facts(1) 1. All statistics for the year ended December 31, 2021. 2. Total Recordable Incident Frequency Rate (“TRIFR”) equals recordable incidents per 200,000 hours worked; MSHA reported total U.S. TRIFR for 2020 of 2.69. 3. Adjusted EBITDA is a non-GAAP financial measure. Refer to the definitions and reconciliations to the nearest GAAP measure in the appendix. TRIFR(2) 1.18 Employees ~4,900 Acres Restored ~2,400 Countries Served 15 2021 Revenue $3.3 Billion 2021 Adjusted EBITDA(3) $917 Million Tons Sold 130 Million Seaborne Thermal – 17 Million Tons Seaborne Met – 5.5 Million Tons US Thermal – 105 Million Tons
4 The Coal Producer of Choice Resilient in All Cycles Growing with Stakeholders Diversity of Products Financial Strength Operational Excellence ESG Champion The Coal Producer of Choice
5 Financial Strength • Adjusted EBITDA of $917 million in 2021 with $444 million in the fourth quarter driven by strong seaborne market pricing • Exposure to growing seaborne markets provides outsized margins in favorable market conditions • U.S. operations consistently deliver positive cash flows • First quarter 2022 Adjusted EBITDA of $328 million impacted by lower volumes • Revenue from coal sales to customers increased by 58% in the first quarter 2022 to over $1 billion as compared to the prior year due to higher realized prices in all segments • Projecting increasingly strong Adjusted EBITDA and cash flows in 2022, capitalizing on strong seaborne margins Seaborne Thermal $353 Seaborne Met $178 Middlemount $48 PRB $135 Other US Thermal $164 Other $38 2021 Adjusted EBITDA ($ in millions) Note: Adjusted EBITDA and Free Cash Flow are non-GAAP financial measures. Refer to the definitions and reconciliations to the nearest GAAP measure in the appendix.
6 • PRB Thermal • Other US Thermal Mining Operations • Seaborne Met • Seaborne Thermal Peabody Snapshot Surface Mine Underground Mine
7 Portfolio Diversity Makes Peabody Unique Coal delivered primarily to Asia Pacific market Australian operations anchored by low cost Wilpinjong Mine Consistently high margins throughout price cycle Adjusted EBITDA of $353 million in 2021 Seaborne Thermal Seaborne Met U.S. Thermal Coal delivered to Asia Pacific and Atlantic markets Diversity of supply and sourcing from U.S. and Australia Positioned to benefit across price cycles with sustainable cost structure Adjusted EBITDA of $178 million in 2021 Coal delivered to U.S. customers in 20+ states Lowest cost PRB & Other U.S. Thermal mines location advantage Maximizing cash generation from baseload demand Adjusted EBITDA of $299 million in 2021 Note: Adjusted EBITDA is a non-GAAP financial measure. Refer to the definitions and reconciliations to the nearest GAAP measure in the appendix. Significant scale, offering diversity in markets, geography and products
8 Operational Excellence • Commitment to Safe, Sustainable operations drives all activities – 1st to achieve CoreSafety Certification – Award winning Mine Rescue teams – Sentinels of Safety Award 2017 & 2018 – 1.18 TRIFR(1) vs industry average of 2.69 • Operate cost-competitive mines by driving operational efficiencies through application of continuous improvement and technology-driven solutions – 8% decrease in Operating Costs and Expenses per ton sold(2) • Risk-informed, investment optimal, strategic plans provide operational flexibility and ensure resiliency against uncertain coal price and demand cycles 1. Total Recordable Incident Frequency Rate (“TRIFR”) equals recordable incidents per 200,000 hours worked; Peabody 2021 TRIFR of 1.18; MSHA reported total U.S. TRIFR for 2020 of 2.69 2. Operating costs and Expenses per ton sold is a non-GAAP statistical measure and is equal to Operating Costs and Expenses divided by Total Tons Sold for the year ended Dec 2021 as compared to the year ended Dec. 2019.
9 Seaborne Thermal: Tier One Assets with Strong Margins • Wilpinjong is one of Australia’s lowest-cost coal mining operations with approximately six million tons of annual export volumes • Wambo UG and OC achieve Newcastle benchmark pricing while Wilpinjong export prices at a discount to the API5 • Stronger margins and cash flows anticipated in 2022 with volume exposed to current and forward prices $50 $37 $54 $50 $33 $29 $34 $37 20 Mt 19 Mt 17 Mt 17 - 18 Mt 2019 2020 2021 2022E Seaborne Thermal Volumes, Revenue per Ton and Costs per Ton Wilpinjong Domestic Wilpinjong Export Wambo UG and OC Revenue per Ton Costs per Ton Priced Volume Revenue per Ton, Costs per Ton and Adjusted EBITDA Margin per Ton are non-GAAP operating/statistical measures. Revenue per Ton and Adjusted EBITDA Margin per Ton are equal to revenues by segment and Adjusted EBITDA by segment, respectively, divided by segment tons sold. Costs per Ton is equal to Revenue per Ton less Adjusted EBITDA Margin per Ton. Refer to the definitions and reconciliations to the nearest GAAP measures in the appendix. Certain forward-looking measures and metrics presented are non-GAAP financial and operating/statistical measures. Due to the volatility and variability of certain items needed to reconcile these measures to their nearest GAAP measure, no reconciliation can be provided without unreasonable cost or effort. 2022 costs per ton represent mid-point of guidance.
10 Seaborne Metallurgical: Delivering Increased Volumes into Robust Markets • Improvement initiatives at met operations for sustainability across market cycles • Shoal Creek ramping up production in H1 2022 • Moorvale South at CMJV, expected production in mid-22 • Middlemount JV provides additional two million tons of PCI / SHCC exposure (FY21 Adjusted EBITDA of $48 million) • Strong margins and cash flows anticipated in 2022 with volume exposed to current and forward prices $128 $86 $132 $270 $110 $109 $100 $105 8 Mt 6 Mt 5 Mt 6.5 - 7.5 Mt 2019 2020 2021 2022E Seaborne Met Volumes, Revenue per Ton and Costs per Ton CMJV Metropolitan Shoal Creek Millennium Revenue per Ton Costs per Ton Priced Volume Adjusted EBITDA is a non-GAAP financial measure, Revenue per Ton, Costs per Ton and Adjusted EBITDA Margin per Ton are non-GAAP operating/statistical measures. Revenue per Ton and Adjusted EBITDA Margin per Ton are equal to revenues by segment and Adjusted EBITDA by segment, respectively, divided by segment tons sold. Costs per Ton is equal to Revenue per Ton less Adjusted EBITDA Margin per Ton. Refer to the definitions and reconciliations to the nearest GAAP measures in the appendix. Certain forward-looking measures and metrics presented are non-GAAP financial and operating/statistical measures. Due to the volatility and variability of certain items needed to reconcile these measures to their nearest GAAP measure, no reconciliation can be provided without unreasonable cost or effort. 2022 costs per ton represent mid-point of guidance.
11 Powder River Basin: Operates as a Complex to Maximize Returns • Three operations provide diversity of products and sourcing options • Lowest cost producer in the basin; most competitive against natural gas • Focused on multi-year sales agreements and expanding margins • Incremental 2022 production open to currently much higher spot prices • 3-year cumulative Segment Free Cash Flow of $453 million $11.37 $11.37 $10.99 $12.93 $9.32 $9.14 $9.46 $10.25 108 Mt 87 Mt 88 Mt 88 - 95 Mt 2019 2020 2021 2022E Powder River Basin Volumes, Revenue per Ton and Costs per Ton NARM Caballo Rawhide Revenue per Ton Costs per Ton Priced Volume Revenue per Ton, Costs per Ton and Adjusted EBITDA Margin per Ton are non-GAAP operating/statistical measures. Revenue per Ton and Adjusted EBITDA Margin per Ton are equal to revenues by segment and Adjusted EBITDA by segment, respectively, divided by segment tons sold. Costs per Ton is equal to Revenue per Ton less Adjusted EBITDA Margin per Ton. Segment Free Cash Flow is a non-GAAP measure and is equal to Segment Adjusted EBITDA less Segment Additions to property, plant, equipment and mine development. Refer to the definitions and reconciliations to the nearest GAAP measures in the appendix. Certain forward-looking measures and metrics presented are non-GAAP financial and operating/statistical measures. Due to the volatility and variability of certain items needed to reconcile these measures to their nearest GAAP measure, no reconciliation can be provided without unreasonable cost or effort. 2022 costs per ton represent mid-point of guidance.
12 $47 $39 $41 $45.73 $34 $30 $31 $32.50 28 Mt 18 Mt 17 Mt 18 - 19 Mt 2019 2020 2021 2022E Other U.S. Thermal Volumes, Revenue per Ton and Costs per Ton Illinois Basin Kayenta El Segundo Twentymile Revenue per Ton Costs per Ton Other U.S. Thermal: Supplies Regional Demand with Strong Margins • Ramping up volumes in 2022 to meet near-term demand while supporting long-term agreements • Proximity to customers provides competitive advantage and delivers high margins • Increased margins expected in 2022 and 2023 on strong book of sales • 3-year cumulative Segment Free Cash Flow of $593 million Priced Volume Revenue per Ton, Costs per Ton and Adjusted EBITDA Margin per Ton are non-GAAP operating/statistical measures. Revenue per Ton and Adjusted EBITDA Margin per Ton are equal to revenues by segment and Adjusted EBITDA by segment, respectively, divided by segment tons sold. Costs per Ton is equal to Revenue per Ton less Adjusted EBITDA Margin per Ton. Segment Free Cash Flow isa non-GAAP measure and is equal to Segment Adjusted EBITDA less Segment Additions to property, plant, equipment and mine development. Refer to the definitions and reconciliations to the nearest GAAP measures in the appendix. Certain forward-looking measures and metrics presented are non-GAAP financial and operating/statistical measures. Due to the volatility and variability of certain items needed to reconcile these measures to their nearest GAAP measure, no reconciliation can be provided without unreasonable cost or effort. 2022 costs per ton represent mid-point of guidance.
13 Emphasis on ESG to Create Long-Term Stakeholder Value • Responsible coal mining, reducing impact from operations and making best use of natural resources • Targets for greenhouse gas reduction, water conservation, waste management and land reclamation • Collaborating with stakeholders on a pipeline of projects aimed at reducing emissions and creating future carbon offsets Environmental Social • Safety is our first value and leading measure of excellence • Strive for diversity of backgrounds, thoughts and experiences with inclusive workplaces • Significant contributions to regions through taxes, fees and royalties • Member of U.N. Global Compact • Signatory to CEO Action for Diversity & Inclusion pledge Governance • Focus on good governance, strategy and management, with integrity embedded in culture • Independent Board Chair and committees • Management compensation aligns management with stockholders, and incorporates ESG metrics
14 Commitment to Sustainability and ESG Goals as the “Coal Producer of Choice” • We are embracing the world’s transition to net-zero emissions as an opportunity to create further value for our stakeholders by reducing emissions at our operations and developing ways to support our customers’ ESG commitments • We have established near-term Scope 1 and 2 emissions reduction targets as our first, incremental step toward our long-term ambition of net-zero emissions by 2050 • We are taking action with a pipeline of projects targeted to meet emission reduction goals by leveraging existing assets and new technology 15% GHG emission reduction by 2026(1) Net- Zero Emissions aspiration by 2050 1. 15% GHG Emission reduction target by 2026 as compared to 2018 base
15 Opportunities to create additional value with our existing assets Organic Growth Opportunities to Accomplish Net-Zero Emissions Aspiration 1. Measured and Indicated Resources per Peabody 10-K for the year ended December 31, 2021. • Met Coal Resources: 724 million tons of resources(1) - Opportunity: Reweight investments towards met coal developments such as North Goonyella • Land: 185,000+ acres in US alone - Opportunity to develop renewable projects - Generates value and supports our customers needs • Water: 38 million gallons managed per day - Opportunity for pump storage generation - Potential sale of water • Methane Gas: 60,000+ tons per year - Opportunity to capture, sell or use Methane from underground facilities • Operational Efficiencies: - Fuel usage, haul optimization, process water recycling, equipment electrification, employee commute reduction
16 ESG Pipeline Highlight: R3 Renewables Reclaim, Reimagine, Repower • 50% ownership in R3 Renewables to develop utility scale projects on reclaimed mining properties • Creates value while utilizing Peabody’s core competencies in environmental management and permitting, in addition to monetizing existing Midwest land assets • Ability to serve customer ESG ambitions and demand for renewables by potentially delivering credits with coal supply contracts to achieve net- zero achieve emissions • Joint venture partners bring expertise in renewable project development and capital market capabilities Joint venture in collaboration with Riverstone Holdings and Summit Partners Pursue development of up to 3.3 GW of utility-scale solar PV and 1.6 GW of battery storage Six potential sites on large tracts of land on or near previous coal mining operations in Indiana and Illinois
17 Global Demand for Coal – Strong Economies Need Affordable Energy • Our customers must balance transition to renewables with the continued need for coal generation to supply reliable, low-cost energy • While western countries have begun transition to net-zero emissions, this is costly, and renewable reliability is questionable • Developing Asian countries continue to increase coal consumption • Technology, experimentation and innovation is needed, including carbon capture and related carbon offset accounting frameworks Source: IEA. 0 4,000 5,000 6,000 7,000 9,000 8,000 7,456 20242021 7,906 2019 2020 7,801 8,031 North America Europe ROW Other Asia India China Coal Consumption (tons in millions)
18 -25% 75% 175% 275% 375% Apr-21 Jul-21 Oct-21 Jan-22 Apr-22 Thermal Coal Price Performance Thermal - NEWC (prompt) Thermal - PRB (prompt) Market Dynamics • Robust price indices and demand for each of our market segments • Supply challenges coincide with period of elevated demand • High barriers to entry and lack of global investment limit ability for supply response • Positioned to benefit from market with near-term price exposure to both seaborne and U.S. markets -25% 100% 225% 350% 475% 600% Apr-21 Jul-21 Oct-21 Jan-22 Apr-22 Met Coal Price Performance Met - LV HCC (spot) Met - LV PCI (spot) Source: Platts and ICE Futures.
19 Building on Current Strength to Enhance Financial Resiliency • Positioning balance sheet to be resilient across market cycles through debt and other liability reductions • Reduced principal amount of debt by over $460 million or ~30% since 2020 • Reduced total liabilities by ~$600 million since 2020 • Gross Leverage of 0.9x, Net Leverage of 0.2x Adjusted EBITDA for the trailing twelve months ended March 31, 2022 • Approximately $500 million of operating cash margin posted in support of coal hedges at March 31, 2022 1,548 1,138 1,098 728 720 725 443 233 230 $2.7B $2.1B $2.1B 0 500 1,000 1,500 2,000 2,500 3,000 2020 2021 Q1 2022 Debt and Legacy Liabilities (USD in millions, unless noted) Total Debt ARO Retiree Benefits Note: Adjusted EBITDA is a non-GAAP financial measure. Net Leverage and Gross Leverage are non-GAAP operating/statistical measures. Refer to the definitions and reconciliations to the nearest GAAP measure in the appendix.
20 Recent Convertible Offering Compliments Debt Reduction Strategy • Convertible offering transformed the Company’s maturity profile with $320 million extended to 2028 • Each dollar of proceeds from the convertible offering were used to repay existing senior secured debt - Fully redeemed the $63 million of outstanding 8.500% Senior Notes due 2024, plus $257 million of the 6.375% Senior Notes due 2025 • Cash interest expense reduced by approximately $10 million annually • Company plans to continue to retire debt over time, both at the corporate level and Wilpinjong subsidiary level 194 322 189 78 $383 20272024 20282022 2023 2025 2026 $400 $320 PIC AU (Wilpinjong) TL due 2024 PEC Term Loan due 2025 PEC 6.375% Notes due 2025 PIC AU (Wilpinjong) Notes due 2024 PEC 3.25% Convertible due 2028 Debt Maturity Snapshot (USD in millions, as of March 31, 2022) Subsidiary Level: $383M Corporate Level: $720M
21 Coal Producer of Choice – Building Brighter Futures Providing essential products for the production of affordable, reliable energy and steel Positioned to be the Coal Producer of Choice • Resilient in all markets • Growing with our stakeholders Remain committed to coal as foundation for the future while embracing the world’s transition to net-zero emissions
2 22 Appendix Materials
23 Investment Highlights Financial strength from strong projected cash flows and liability reductions Cost competitive assets, resilient across markets Diversified portfolio of assets, makes Peabody unique amongst peers and provides competitive advantage Strategically positioned to serve growing Asia-Pacific and most competitive U.S. thermal coal markets Operational excellence: drives safety, productivity, cost efficiency, reclamation Commitment to ESG and to be the Coal Producer of Choice Organic growth opportunities
24 Peabody’s Business Segments Mines Full Year 2021 Seaborne Thermal • Wilpinjong • Wambo Underground • Wambo OC JV • Tons Sold (millions) • Revenue per Ton • Costs per Ton • Adjusted EBITDA Margin per Ton 17.3 $54.09 $33.64 $20.45 Seaborne Metallurgical • Shoal Creek • Metropolitan • Coppabella / Moorvale (CMJV) • Tons Sold (millions) • Revenue per Ton • Costs per Ton • Adjusted EBITDA Margin per Ton 5.5 $131.83 $99.55 $32.28 Powder River Basin • North Antelope Rochelle • Caballo • Rawhide • Tons Sold (millions) • Revenue per Ton • Costs per Ton • Adjusted EBITDA Margin per Ton 88.4 $10.99 $9.46 $1.53 Other U.S. Thermal • Bear Run • Francisco Underground • Wild Boar • Gateway North • Twentymile • El Segundo • Tons Sold (millions) • Revenue per Ton • Costs per Ton • Adjusted EBITDA Margin per Ton 16.9 $40.75 $31.04 $9.71 Note: Revenue per Ton, Costs per Ton and Adjusted EBITDA Margin per Ton are non-GAAP operating/statistical measures. Revenue per Ton and Adjusted EBITDA Margin per Ton are equal to revenues by segment and Adjusted EBITDA by segment, respectively, divided by segment tons sold. Costs per Ton is equal to Revenue per Ton less Adjusted EBITDA Margin per Ton. Refer to the definitions and reconciliations to the nearest GAAP measures in the appendix. .
25 Review of Recent Operating Initiatives Seaborne Thermal Seaborne Metallurgical Powder River Basin Other U.S. Thermal • Completed development at Wilpinjong Extension and Wambo Open-Cut • Completed ramp up of Metropolitan longwall production • Ramping up longwall production at Shoal Creek • Advancing development work at Moorvale South • Increasing production at Middlemount • Reviewing potential restart of North Goonyella • Adding underground production units in the Illinois Basin and increasing production at our Wild Boar Complex • Refurbishing and relocating equipment in the PRB, making expenditures to capture near term demand and add flexibility to the mine plan
26 2022 Guidance Table Certain forward-looking measures and metrics presented are non-GAAP financial and operating/statistical measures. Due to the volatility and variability of certain items needed to reconcile these measures to their nearest GAAP measure, no reconciliation can be provided without unreasonable cost or effort. Segment Performance Total Volume (millions of short tons) Priced Volume (millions of short tons) Priced Volume Pricing per Short Ton Average Cost per Short Ton 88 - 95 92 $12.93 $9.75 - $10.75 18 - 19 18.6 $45.73 $31.50 - $33.50 9.5 - 10.5 4.7 $98.27 NA 17 - 18 12.5 $50.36 $35.00 - $39.00 6.5 - 7.5 1.3 $270.00 $100.00 - $110.00 Total Volume (millions of short tons) Priced Volume (millions of short tons) Priced Volume Pricing per Short Ton Average Cost per Short Ton 5.5 - 6 1.8 $87.51 NA 7.5 - 8 7.8 $21.38 NA 13 - 14 9.6 $33.75 $24.50 - $27.50 2022 Full Year $85 $140 $80 $190 $60 $25 Seaborne Thermal Seaborne Metallurgical PRB and Other U.S. Thermal volumes reflect volumes priced as of March 31, 2022. Weighted average quality for the PRB segment 2022 volume is approximately 8670 BTU. Seaborne Thermal volumes reflect volumes priced as of March 31, 2022. Realized seaborne thermal export pricing varies based on sales timing and product quality as well as optimization strategies. In general, the Wambo unpriced products are expected to price with reference to Globalcoal “NEWC” levels and Wilpinjong, with a higher ash content is anticipated to price at a 5-20% discount to API 5 price levels. On average, Peabody's total metallurgical sales are anticipated to price at a 15-20% discount to the premium hard-coking coal index price (FOB Australia). Peabody's total metallurgical sales are expected to be comprised of ~25% HVA coal and ~75% PCI / SHCC coals. Total Capital Expenditures ARO Cash Spend Postretirement benefits cash spend Supplemental Information PRB and Other U.S. Thermal 2022 Full Year Major Project / Growth Capital Expenditures 2022 Full Year Wilpinjong (Export) PRB – Total Other U.S. Thermal – Total Seaborne Thermal (Export) Seaborne Thermal – Total Seaborne Metallurgical – Total Wilpinjong Performance Wilpinjong (Domestic) Wilpinjong – Total Other Annual Financial Metrics ($ in millions) SG&A Net Cash Interest Payments
27 Reconciliation of Non-GAAP Measures Note: Refer to definitions and footnotes on slides 31. Year Ended Year Ended Quarter Ended Quarter Ended Quarter Ended Quarter Ended Year Ended Quarter Ended Twelve Months Ended Dec. 31, 2019 Dec. 31, 2020 Mar. 31, 2021 Jun. 30, 2021 Sept. 30, 2021 Dec. 31, 2021 Dec. 31, 2021 Mar. 31, 2022 Mar. 31, 2022 Tons Sold (In Mill ions) Seaborne Thermal Mining Operations 19.5 19.0 4.1 4.1 4.5 4.6 17.3 3.8 17.0 Seaborne Metallurgical Mining Operations 8.1 5.6 1.0 1.4 1.5 1.6 5.5 1.2 5.7 Powder River Basin Mining Operations 108.1 87.2 20.7 22.5 22.7 22.5 88.4 20.6 88.3 Other U.S. Thermal Mining Operations 27.9 18.3 3.9 3.9 4.5 4.6 16.9 4.2 17.2 Total U.S. Thermal Mining Operations 136.0 105.5 24.6 26.4 27.2 27.1 105.3 24.8 105.5 Corporate and Other 1.9 2.5 0.5 0.9 0.5 0.1 2.0 0.1 1.6 Total 165.5 132.6 30.2 32.8 33.7 33.4 130.1 29.9 129.8 Revenue Summary (In Mill ions) Seaborne Thermal Mining Operations 971.7$ 711.8$ 176.4$ 194.1$ 260.7$ 302.8$ 934.0$ 251.2$ 1,008.8$ Seaborne Metallurgical Mining Operations 1,033.1 486.5 87.5 121.0 179.5 339.7 727.7 321.3 961.5 Powder River Basin Mining Operations 1,228.7 991.1 228.4 248.6 247.1 247.1 971.2 251.2 994.0 Other U.S. Thermal Mining Operations 1,309.4 707.3 149.3 162.1 184.6 193.1 689.1 203.1 742.9 Total U.S. Thermal Mining Operations 2,538.1 1,698.4 377.7 410.7 431.7 440.2 1,660.3 454.3 1,736.9 Corporate and Other (1) 80.5 (15.6) 9.7 (2.4) (192.9) 181.9 (3.7) (335.4) (348.8) Total 4,623.4$ 2,881.1$ 651.3$ 723.4$ 679.0$ 1,264.6$ 3,318.3$ 691.4$ 3,358.4$ Total Reporting Segment Costs Summary (In Mill ions) (2) Seaborne Thermal Mining Operations 642.3$ 548.6$ 147.9$ 122.7$ 156.3$ 154.0$ 580.9$ 160.7$ 593.7$ Seaborne Metallurgical Mining Operations 892.9 616.7 109.9 147.4 122.1 170.1 549.5 140.3 579.9 Powder River Basin Mining Operations 1,007.5 796.3 198.3 203.1 210.1 224.8 836.3 243.6 881.6 Other U.S. Thermal Mining Operations 948.0 538.9 113.1 117.8 139.5 154.5 524.9 153.1 564.9 Total U.S. Thermal Mining Operations 1,955.5 1,335.2 311.4 320.9 349.6 379.3 1,361.2 396.7 1,446.5 Corporate and Other 49.2 37.9 (1.8) 11.6 14.4 (4.2) 20.0 (6.9) 14.9 Total 3,539.9$ 2,538.4$ 567.4$ 602.6$ 642.4$ 699.2$ 2,511.6$ 690.8$ 2,635.0$ Adjusted EBITDA (In Mill ions) (3) Seaborne Thermal Mining Operations 329.4$ 163.2$ 28.5$ 71.4$ 104.4$ 148.8$ 353.1$ 90.5$ 415.1$ Seaborne Metallurgical Mining Operations 140.2 (130.2) (22.4) (26.4) 57.4 169.6 178.2 181.0 381.6 Powder River Basin Mining Operations 221.2 194.8 30.1 45.5 37.0 22.3 134.9 7.6 112.4 Other U.S. Thermal Mining Operations 361.4 168.4 36.2 44.3 45.1 38.6 164.2 50.0 178.0 Total U.S. Thermal Mining Operations 582.6 363.2 66.3 89.8 82.1 60.9 299.1 57.6 290.4 Middlemount (4) (9.8) (29.2) (2.3) (4.1) 9.3 45.3 48.2 45.1 95.6 Resource Management Results (5) 8.2 15.3 0.4 3.9 (0.4) 3.0 6.9 3.5 10.0 Sell ing and Administrative Expenses (145.0) (99.5) (21.7) (21.4) (21.1) (20.7) (84.9) (23.1) (86.3) Other Operating Costs, Net (6) (22.6) (24.0) 12.3 8.9 57.4 37.5 116.1 (27.1) 76.7 Adjusted EBITDA (3) 883.0$ 258.8$ 61.1$ 122.1$ 289.1$ 444.4$ 916.7$ 327.5$ 1,183.1$
28 Reconciliation of Non-GAAP Measures Note: Refer to definitions and footnotes on slides 31. Three Year Year Ended Year Ended Year Ended Cumulative Dec. 31, 2019 Dec. 31, 2020 Dec. 31, 2021 2019-2021 Segment Free Cash Flow (In Mill ions) Seaborne Thermal Mining Operations Adjusted EBITDA 329.4$ 163.2$ 353.1$ 845.7$ Less: Segment additions to property, plant, equipment and mine development (42.1) (100.7) (88.6) (231.4) Total 287.3 62.5 264.5 614.3 Seaborne Metallurgical Mining Operations Adjusted EBITDA 140.2 (130.2) 178.2 188.2 Less: Segment additions to property, plant, equipment and mine development (143.4) (50.8) (25.1) (219.3) Total (3.2) (181.0) 153.1 (31.1) Powder River Basin Mining Operations Adjusted EBITDA 221.2 194.8 134.9 550.9 Less: Segment additions to property, plant, equipment and mine development (42.8) (13.2) (41.4) (97.4) Total 178.4 181.6 93.5 453.5 Other U.S. Thermal Mining Operations Adjusted EBITDA 361.4 168.4 164.2 694.0 Less: Segment additions to property, plant, equipment and mine development (54.0) (23.3) (24.2) (101.5) Total 307.4 145.1 140.0 592.5 Corporate and Other Adjusted EBITDA (169.2) (137.4) 86.3 (220.3) Less: Segment additions to property, plant, equipment and mine development (3.1) (3.4) (3.8) (10.3) Total (172.3) (140.8) 82.5 (230.6) Consolidated Adjusted EBITDA 883.0 258.8 916.7 2,058.5 Less: Segment additions to property, plant, equipment and mine development (285.4) (191.4) (183.1) (659.9) Total 597.6$ 67.4$ 733.6$ 1,398.6$
29 Reconciliation of Non-GAAP Measures Note: Refer to definitions and footnotes on slides 31. Year Ended Year Ended Quarter Ended Quarter Ended Quarter Ended Quarter Ended Year Ended Quarter Ended Twelve Months Ended Dec. 31, 2019 Dec. 31, 2020 Mar. 31, 2021 Jun. 30, 2021 Sept. 30, 2021 Dec. 31, 2021 Dec. 31, 2021 Mar. 31, 2022 Mar. 31, 2022 Reconcil iation of Non-GAAP Financial Measures (In Mill ions) (Loss) Income from Continuing Operations, Net of Income Taxes (188.3)$ (1,859.8)$ (77.7)$ (23.0)$ (59.6)$ 507.7$ 347.4$ (119.8)$ 305.3$ Depreciation, Depletion and Amortization 601.0 346.0 68.3 77.1 77.9 85.4 308.7 72.9 313.3 Asset Retirement Obligation Expenses 58.4 45.7 15.9 15.1 14.3 (0.6) 44.7 15.0 43.8 Restructuring Charges 24.3 37.9 2.1 2.1 1.7 2.4 8.3 1.6 7.8 Transaction Costs Related to Business Combinations and Joint Ventures 21.6 23.1 - - - - - - - Gain on Formation of United Wambo Joint Venture (48.1) - - - - - - - - Asset Impairment 270.2 1,487.4 - - - - - - - Provision for North Goonyella Equipment Loss 83.2 - - - - - - - - North Goonyella Insurance Recovery - Equipment (7) (91.1) - - - - - - - - Changes in Deferred Tax Asset Valuation Allowance and Reserves and - Amortization of Basis Difference Related to Equity Affi l iates (18.8) 30.9 (1.5) (0.5) (6.4) (25.4) (33.8) (0.6) (32.9) Interest Expense 144.0 139.8 52.4 45.4 45.5 40.1 183.4 39.4 170.4 Net Loss (Gain) on Early Debt Extinguishment 0.2 - (3.5) (11.8) (16.0) (1.9) (33.2) 23.5 (6.2) Interest Income (27.0) (9.4) (1.5) (1.3) (1.4) (2.3) (6.5) (0.5) (5.5) Net Mark-to-Market Adjustment on Actuarially Determined Liabil ities 67.4 (5.1) - - - (43.4) (43.4) - (43.4) Unrealized (Gains) Losses on Derivative Contracts Related to Forecasted Sales (42.2) 29.6 1.9 23.7 238.4 (148.9) 115.1 301.0 414.2 Unrealized (Gains) Losses on Foreign Currency Option Contracts (1.2) (7.1) 7.6 1.2 (0.6) (0.7) 7.5 (3.3) (3.4) Take-or-Pay Contract-Based Intangible Recognition (16.6) (8.2) (1.1) (1.1) (1.0) (1.1) (4.3) (0.7) (3.9) Income Tax Provision (Benefit) 46.0 8.0 (1.8) (4.8) (3.7) 33.1 22.8 (1.0) 23.6 Adjusted EBITDA (3) 883.0$ 258.8$ 61.1$ 122.1$ 289.1$ 444.4$ 916.7$ 327.5$ 1,183.1$ Operating Costs and Expenses 3,536.6$ 2,524.9$ 582.6$ 611.4$ 649.4$ 709.7$ 2,553.1$ 699.0$ 2,669.5$ Unrealized Gains (Losses) on Foreign Currency Option Contracts 1.2 7.1 (7.6) (1.2) 0.6 0.7 (7.5) 3.3 3.4 Take-or-Pay Contract-Based Intangible Recognition 16.6 8.2 1.1 1.1 1.0 1.1 4.3 0.7 3.9 North Goonyella Insurance Recovery - Cost Recovery and Business Interruption (7) (33.9) - - - - - - - - Net Periodic Benefit Costs (Credit), Excluding Service Cost 19.4 (1.8) (8.7) (8.7) (8.6) (12.3) (38.3) (12.2) (41.8) Total Reporting Segment Costs (2) 3,539.9$ 2,538.4$ 567.4$ 602.6$ 642.4$ 699.2$ 2,511.6$ 690.8$ 2,635.0$ Net Cash Provided By (Used In) Operating Activities 677.4$ (9.7)$ 71.0$ (93.8)$ 4.4$ 438.4$ 420.0$ (273.7)$ 75.3$ Net Cash (Used In) Provided By Investing Activities (261.3) (206.7) (93.2) 10.6 (37.1) (11.8) (131.5) 35.2 (3.1) Add Back: Amount Attributable to Acquisition of Shoal Creek Mine 2.4 - - - - - - - - Free Cash Flow (8) 418.5$ (216.4)$ (22.2)$ (83.2)$ (32.7)$ 426.6$ 288.5$ (238.5)$ 72.2$ .
30 Reconciliation of Non-GAAP Measures Note: Refer to definitions and footnotes on slide 31. Mar. 31, 2022 Reconcil iation of Non-GAAP Financial Measures (In Mill ions) Current Portion of Long-Term Debt 19.1$ Long-Term Debt, Less Current Portion 1,079.0 Less: Cash and Cash Equivalents (823.3) Net Debt (9) 274.8$ Calculation of Non-GAAP Financial Measures Gross Leverage (10) 0.9 Net Leverage (11) 0.2
31 Reconciliation of Non-GAAP Measures: Definitions (1) Year Ended Year Ended Quarter Ended Quarter Ended Quarter Ended Quarter Ended Year Ended Quarter Ended Twelve Months Ended Dec. 31, 2019 Dec. 31, 2020 Mar. 31, 2021 Jun. 30, 2021 Sept. 30, 2021 Dec. 31, 2021 Dec. 31, 2021 Mar. 31, 2022 Mar. 31, 2022 Net unrealized gain (loss) 50.6$ (34.5)$ (4.9)$ (19.9)$ (238.4)$ 149.5$ (113.7)$ (290.2)$ (399.0)$ (2) (3) (4) Year Ended Year Ended Quarter Ended Quarter Ended Quarter Ended Quarter Ended Year Ended Quarter Ended Twelve Months Ended Dec. 31, 2019 Dec. 31, 2020 Mar. 31, 2021 Jun. 30, 2021 Sept. 30, 2021 Dec. 31, 2021 Dec. 31, 2021 Mar. 31, 2022 Mar. 31, 2022 Tons sold 1.5 1.6 0.6 0.5 0.5 0.4 2.0 0.5 1.9 23.1$ 30.0$ 6.7$ 6.9$ 8.2$ 8.0$ 29.8$ 8.2$ 31.3$ Net interest expense 9.1 14.2 5.1 5.0 4.9 4.8 19.8 18.8 33.5 Income tax (benefit) provision (7.1) (14.3) (0.1) (0.8) 4.8 20.3 24.2 18.0 42.3 - - - - - 12.5 12.5 - 12.5 (5) (6) (7) (8) (9) (10) (11) Gross Leverage is equal to current portion of long-term debt plus long-term debt, less current portion divided by Adjusted EBITDA for the twelve months ended March 31, 2022. Net Leverage is equal to Net Debt divided by Adjusted EBITDA for the twelve months ended March 31, 2022. Includes gains (losses) on certain surplus coal reserve and surface land sales and property management costs and revenue. Includes trading and brokerage activities, costs associated with post-mining activities, minimum charges on certain transportation-related contracts, costs associated with suspended operations including the North Goonyella Mine beginning in Q1 2020 and the Q3 2021 gain of $26.1 mill ion recognized on the sale of the Millennium Mine. We recorded a $125.0 mill ion insurance recovery during the year ended December 31, 2019 related to losses incurred at our North Goonyella Mine. Of this amount, Adjusted EBITDA excludes an allocated amount applicable to total equipment losses recognized at the time of the insurance recovery settlement, which consisted of $24.7 mill ion and $66.4 mill ion recognized during the years ended December 31, 2019 and 2018, respectively. The remaining $33.9 mill ion, applicable to incremental costs and business interruption losses, is included in Adjusted EBITDA for the year ended December 31, 2019. Free Cash Flow is defined as net cash provided by (used in) operating activities less net cash (used in) provided by investing activities and excludes cash outflows related to business combinations. Free Cash Flow is used by management as a measure of our financial performance and our abil ity to generate excess cash flow from our business operations. Net Debt is defined as current portion of long-term debt plus long-term debt, less current portion less cash and cash equivalents. Net Debt is reviewed by management as an indicator of our overall financial flexibil ity, capital structure and leverage. Depreciation, depletion and amortization and asset retirement obligation expenses Insurance settlement attributable to 2019 business interruption and property damage claim (In Mill ions) (In Mill ions) Note: Management believes that non-GAAP performance measures are used by investors to measure our operating performance and lenders to measure our abil ity to incur and service debt. These measures are not intended to serve as alternatives to U.S. GAAP measures of performance and may not be comparable to similarly-titled measures presented by other companies. Includes net gains (losses) related to unrealized mark-to-market adjustments on derivatives related to forecasted sales and other financial trading activity of: Total Reporting Segment Costs is defined as operating costs and expenses adjusted for the discrete items that management excluded in analyzing each of our segment's operating performance as displayed in the reconcil iation above. Total Reporting Segment Costs is used by management as a metric to measure each of our segment's operating performance. Adjusted EBITDA is defined as (loss) income from continuing operations before deducting net interest expense, income taxes, asset retirement obligation expenses and depreciation, depletion and amortization. Adjusted EBITDA is also adjusted for the discrete items that management excluded in analyzing each of our segment's operating performance as displayed in the reconcil iation above. Adjusted EBITDA is used by management as the primary metric to measure each of our segment's operating performance and allocate resources. We account for our 50% equity interest in Middlemount Coal Pty Ltd. (Middlemount), which owns the Middlemount Mine, under the equity method. Middlemount's standalone results exclude the impact of related changes in deferred tax asset valuation allowance and reserves and amortization of basis difference recorded by the Company in applying the equity method. Middlemount's standalone results include (on a 50% attributable basis):