CONSOL Energy Inc. CONSOL Coal Resources LP Investor Presentation - - PowerPoint PPT Presentation

SLIDE 1

CONSOL Energy Inc. CONSOL Coal Resources LP

Investor Presentation

August 2019

SLIDE 2

Disclaimer

2

This presentation contains statements, estimates and projections which are forward-looking statements (as defined in Section 21E of the Securities Exchange Act of 1934, as amended). Statements that are not historical are forward-looking, and include, without limitation, projections and estimates concerning the timing and success of specific projects and the future production, revenues, income and capital spending of CONSOL Energy, Inc. (“CEIX”) and CONSOL Coal Resources LP (“CCR,” and together with CEIX, “we,” “us,” or “our”). When we use the words “anticipate,” “believe,” “could,” “continue,” “estimate,” “expect,” “intend,” “may,” “plan,” “predict,” “project,” “should,” “will,” or their negatives, or other similar expressions, the statements which include those words are usually forward-looking statements. These forward-looking statements involve risks and uncertainties that could cause actual results and outcomes to differ materially from results and outcomes expressed in or implied by our forward-looking statements. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of future actual

• results. We have based these forward-looking statements on our current expectations and assumptions about future events. While our

management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond our

• control. Factors that could cause future actual results to differ materially from those made or implied by the forward-looking statements include

risks, contingencies and uncertainties that are described in detail under the captions “Forward-Looking Statements” and “Risk Factors” in our public filings with the Securities and Exchange Commission. The forward-looking statements in this presentation speak only as of the date of this presentation; we disclaim any obligation to update the statements, and we caution you not to rely on them unduly. This presentation includes unaudited “non-GAAP financial measures” as defined in Regulation G under the Securities Exchange Act of 1934, including EBIT, EBITDA, Adjusted EBITDA, Bank EBITDA, EBITDA per Affiliated Company Credit Agreement, PAMC Adjusted EBITDA, net leverage ratio, bank net leverage ratio, CONSOL Marine Terminal EBITDA, modified net leverage ratio, consolidated net debt, Consolidated Net Debt less Non-controlling Portion of CCR Affiliate Loan, Net Debt per Affiliated Company Credit Agreement, Return of Capital, Adjusted EBITDA Attributable to CONSOL Energy Shareholders, average cash cost per ton sold, average cash margin per ton sold, Organic Free Cash Flow, distribution coverage ratio and Organic Free Cash Flow Net to CEIX Shareholders. The presentation of non-GAAP financial measures is not intended to be a substitute for, and should not be considered in isolation from, the financial measures reported in accordance with GAAP.

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Continue to Execute our Strategy Through Balanced Approach to De-leveraging, Growth and Capital Returns To Drive Shareholder Returns 8 Proven Competitiveness in Domestic Markets Relative to Other Basins and Natural Gas 7 Seaborne Thermal Coal Fundamentals Supported by Continued Global Coal-fired Capacity Build Out and Strong Global Value Proposition of NAPP Coal 6 Stable, Diversified, Domestic Credit Worthy Customer Base that Minimizes Market Risk and Optimizes Margin 4

Investment Thesis

3

Proven Ability to Generate Material Free Cash Flow Leading to Significant Deleveraging with Continued Focus

• n Further Debt Paydown and Increasing Shareholder Returns

1 Base Assets with 1st Quartile Cost Position Sustains Margins through the Cycle and Provides Internal Funding to Execute Our Strategy 2 Secure Export Exposure Due to High Quality Coal, Attractive Netbacks, Contracted Position and CONSOL Marine Terminal Ownership 5 Committed to ESG Initiatives with Focus on Efficiency, Technology and Innovation 9 Opportunistically Growing Our Metallurgical Coal Footprint through Long-life Itmann Project (Low-Vol) 3

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56% 53%

• 5%
• 7%
• 6%
• 5%
• 4%
• 3%
• 2%
• 1%

0% 0% 10% 20% 30% 40% 50% 60% Net Debt / Enterprise Value Spin Today 2.1x 1.4x

• 0.8x
• 0.9x
• 0.8x
• 0.7x
• 0.6x
• 0.5x
• 0.4x
• 0.3x
• 0.2x
• 0.1x
• 0.5x

1.0x 1.5x 2.0x 2.5x Net Debt/Adjusted EBITDA $766 $599

• 22%
• 27%
• 22%
• 17%
• 12%
• 7%
• 2%
• 100.00

200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 Net Debt $357 $430 20% 0% 5% 10% 15% 20% 25%

• 50.00

100.00 150.00 200.00 250.00 300.00 350.00 400.00 450.00 500.00 LTM Adjusted EBITDA B1 / B B1 / B+ +1 S&P notch 0% 5% 10% 15% 20% 25% 30% 35%

• 5.00

10.00 15.00 20.00 25.00 Corporate Ratings Moody's / S&P Global Spin Today $100 $105 5% 0% 1% 2% 3% 4% 5% 6% 75.00 80.00 85.00 90.00 95.00 100.00 105.00 110.00 2nd Lien Notes Pricing 6.0% 4.5%

• 25%
• 300%
• 250%
• 200%
• 150%
• 100%
• 50%

0% 0.0% 1.0% 2.0% 3.0% 4.0% 5.0% 6.0% 7.0% Term Loan B Credit Spread $21.50 $19.13

• 11%
• 12%
• 10%
• 8%
• 6%
• 4%
• 2%

0%

• 10.00

20.00 30.00 40.00 50.00 Common Stock

Source: CONSOL Energy Inc. management Company filings. Note: “Today” is based on COB Aug 5, 2019 & “Spin” is based on November 28, 2017 unless otherwise noted. (1) LTM Adjusted EBITDA for “Spin” is based on initial 2018 Adjusted EBITDA spin forecast and “Today” is based on quarter-ended June 30, 2019. (2) “Spin” is CONSOL Mining Company pro forma 6/30/2017 and “Today” is as of quarter-ended June 30, 2019. (3) “Spin” figure is calculated as pro forma 6/30/2017 net debt of $766 million / $357 LTM adjusted EBITDA (spin forecast) and “Today” is as quarter-ended June 30, 2019.

CEIX Performance Since November 2017 Spin

4

Performance of Our Securities since the November 2017 Spin… …Driven by Improvements in Our Key Financial Metrics

(1) (3) (2)

SLIDE 5

Bailey(1) 163 12,890 2.61% 11.5 12.7 Enlow Fork(1) 334 12,935 2.07% 11.5 9.9 Harvey(1) 202 12,873 2.42% 5.5 5.0 Total 699 12,907 2.30% 28.5 27.6 Illinois Basin(2) 11,320 2.92% Other Napp(2) 12,446 3.34% Mine Total Recoverable Reserves* Average AR Gross Heat Content (Btu/lb) Average AR Sulfur Content

• Est. Annual

Production Capacity*(3) 2018A Production*

Pennsylvania Mining Complex Overview

5

Source: CONSOL management, ABB Velocity Suite, EIA Note: Data shown on a 100% basis for PAMC (1) For the fiscal year period ending and as of 12/31/2018 (2) Represent the average of power plant deliveries for the three years ending 12/31/2018 per EIA / ABB Velocity Suite. Excludes waste coal (3) Represents illustrative general capacity for each mine; actual production on a mine by mine basis can exceed illustrative capacity in order to maximize complex capacity of 28.5MM tons

◼

Three highly productive, well-capitalized underground coal mines

◼

Five longwalls and 15–17 continuous miner sections

◼

Largest central preparation plant in the United States

◼

~79% of reserves are owned and require no royalty payment

◼

Extensive logistics network served by two Class I railroads

◼

Access to seaborne markets through CONSOL Marine Terminal

◼

More than $2.0 billion invested in PAMC since 2009

◼

Non-union workforce at PAMC since 1982

◼

Continuously sealing off old mine works to reduce maintenance, improve safety

• f employees and maintain current operating footprint

*(MillionTons)

2018 PA Mining Complex Domestic Power Plant Customers

PA Mining Complex CONSOL Marine Terminal

Sealed Reserves Current Mining

SLIDE 6

1st Quartile Cost Position in NAPP and Globally

6

$0 $20 $40 $60 $80 $100 $120 – 100 200 300 400 500 600 700 800 900 US $/Tonne Cumulative Production (Million Tonnes) PAMC US Appalachia US Illinois Basin US Powder River US Western Bituminous

25 50 75 $100 10 20 30 40 50 60 70 Cumulative Production (Million Tons) Sulfur content $120 100 80 60 40 20

(Cash costs $ per ton)

Source: CONSOL management. Wood Mackenzie (1) Costs represent total cash costs as defined by Wood Mackenzie (2) Costs are BTU adjusted and include mining, preparation, transport, port and overhead costs. PAMC cash costs of coal sold are based on CONSOL management and peers based on Wood Mackenzie The PAMC’s 1st quartile cost position drives global competitiveness despite changes in seaborne thermal supply / demand fundamentals 1st Quartile 2nd Quartile 3rd Quartile 4th Quartile

2015 2017 2016 Thermal Coal Exports

1st Quartile 2nd Quartile 3rd Quartile 4th Quartile

(Cash costs $ per tonne) 1st quartile cost position in NAPP (2018)(1) 1st quartile position among global thermal coal production (2018)(2)

4.3% 2.5%

River market mine Rail market mine Minemouth mine

3.3% 2.7% 4.2% 3.3% 3.1% 4.1% 3.3%

SLIDE 7

CONSOL Marine Terminal Overview

7

Overview

◼

Coal export terminal strategically located in Baltimore, Maryland − 15.0 million tons per year throughput capacity − 1.1 million tons coal storage yard capacity − Only East Coast coal export terminal served by two railroads − Exports PAMC and third party coal

◼

Achieved significant service and operating cost efficiencies since 2016

◼

CMT achieved a record annual revenue of $65mm in 2018

◼

Take-or-pay agreement for $60mm annually in throughput revenue through 2020

◼

Growing non-PAMC volumes: 2.7mm tons in 2015 to 5.0mm tons in 2018

◼

Maintain flexibility to ship additional PAMC tons as needed

SLIDE 8

8

Source: S&P Global Market Intelligence, CONSOL Energy Inc. management. (1) Represents estimated ocean/rail rates to port terminals, exclusive of terminal throughput charges.

On-Site Key Logistics Infrastructure and Advantaged Export Access in a Growing Export Market

PAMC

Core Markets Battleground Markets

~$9 - $11/ton East Coast to EUR ~$12 - $15/ton ~$17/ton ~$16 - $19/ton ~$12 - $14/ ton Gulf Coast to EUR

Dual-served railroad access Eastern U.S. coal regions and points of thermal export(1)

Port of Baltimore

SLIDE 9

9 Permitting

◼ Anticipate mine permits to be issued by Q3 2019 ◼ Prep plant engineering/permitting underway;

targeting construction in 2020-2021

◼ Evaluating opportunities for third-party coal

• fftake while prep plant is constructed

Production Capacity

◼ Estimated capacity: 600,000+ tons/year

(3 CM sections)

◼ Full production expected by 2021

Projected Capital Cost

◼ $65-80 million (mine + preparation plant)

Product

◼ Low-vol met coal ◼ Pocahontas 3 seam

Volatile Matter Sulfur CSR 18.5% 60 Mine Life

◼ 18+ million tons life-of-mine production ◼ > 25 years of mine life at projected run rate

Projected Operating Cost

◼ $65-75/short ton cash operating cost

Location

◼ Wyoming County, WV

Logistics

◼ Access to export and domestic markets via

Norfolk Southern Railroad 0.9%

Itmann Project – High Returns & Measured Pace of Investment

SLIDE 10

10

Itmann Project Will Cater to Growing Market with Shrinking High Quality Supply

Source: Wood Mackenzie Coal Market Service.

◼

According to Wood Mackenzie:

◼

Global seaborne met coal demand will rise from 313 Mt in 2019 to 422 Mt by 2040.

◼

Indian imports increase to 142 Mtpa in 2040 vs 63 Mtpa in 2019; account for over 72% of net seaborne growth.

◼

Chinese demand increases by 16 Mtpa to 66 Mtpa by 2040.

◼

There is a shortage of low-vol projects in the supply pipeline and known projects are limited.

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11

Maximize sales to established customer base of rail-served power plants in the Eastern U.S., with a focus on top-performing environmentally- controlled plants Place approximately 2.0 – 2.5 million tons per annum in the seaborne met coal market Selectively place remaining tonnage in opportunities (export or domestic) that maximize FOB mine margins Capitalize on innovative marketing tactics and strategies to grow

• pportunities and realizations in all of the Company’s market areas

Illustrative portion of annual production

Source: CONSOL Energy Inc. management

1 2 3 4 ~60 – 80% ~10% ~10 – 30%

◼ Creative contract structures ◼ Technical marketing initiatives to gain

market share for PAMC by displacing other basins

◼ Development of crossover met markets for

PAMC

Multi-pronged PAMC Marketing Strategy

SLIDE 12

12

In 2018, the Company sold PAMC coal to 27 domestic power plants located in 13 states, and to thermal and metallurgical end-users located across five continents.

Highly-diversified Portfolio Provides Stability

53% 43% 4% Industrial/Met Customers Regulated Power Plants Merchant (Unregulated) Power Plants PJM Southeast MISO Industrial/Met Other Asia South America Europe Africa India Canada 2019E Guidance Range

Annual coal sales

2015A 2016A 2017A 2018A 2019E Domestic Export Thermal Export Met

27.8 22.9 24.6 26.1 27.7 26.8

2018A Export thermal 2018A Export met 2018A Domestic

(million tons)

SLIDE 13

Stable, Diversified, Credit Worthy Customer Base That Minimizes Market Risk and Optimizes Margin

13

Announced Coal Retirement 1% No Announced Coal Retirement 99%

0% 20% 40% 60% 80% PAMC Top Customer Plants Other NAPP Rail-Served Plants

12%

Delta %

5% 11% 14% 19% 17% 20% 17% 7% 11% 7% 5% 15% 5% 21% 5% 13% 14% 12% 7% 16% 11%

2018 domestic power plant shipments by unit retirement status

Source: CONSOL management, EIA, ABB Velocity Suite (1) Market data as of August 5, 2019 (2) PAMC top customer plants represent the thirteen domestic power plant customers to which PAMC shipped >500,000 tons of coal in 2017 and the twelve domestic power plant customers to which PAMC shipped >500,000 tons of coal in 2018. (3) Other NAPP Rail-Served Plants include all other power plants that took delivery of NAPP rail coal in January-December 2017 (for 2017 comparisons) and January-December 2018 (for 2018 comparisons)

Blue-chip customers(1) Limited volume at risk due to announced power plant retirements Average capacity factor (weighted by capacity)(2)(3)

13% 9%

From January 2017 to December 2018, CONSOL’s top customer plants’ average capacity factor has been 12 percentage points higher than other NAPP rail-served plants

Market cap: $59.8bn Baa2 / BBB+ Market cap: $23.3bn Baa1 / BBB+ Market cap: $62.9bn Baa1 / A- Market cap: $58.1bn Baa2 / A- Private

• / -

Private B2 / B+ Private

• / -

SLIDE 14

+3%

• 11%
• 40%
• 24%
• 20

40 60 80 100 120 140 160 4Q17 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19

Index

CEIX Average Revenue Per Ton Domestic NAPP Coal Average Prompt Month API#2 Spot Average PJM Western Hub Around-The-Clock

Premium Quality Coal and Differentiated Marketing Strategy Ensures Continued Participation in Seaborne Markets

14

8,000 9,000 10,000 11,000 12,000 13,000

Sulfur %

8,000 9,000 10,000 11,000 12,000 13,000 BTU Content (Btu/lb gross as-received) (Btu/lb gross as-received)

Best-in-class Btu content(1)

Source: CONSOL Energy Inc. management, ABB Velocity Suite, EIA, and S&P Global Platts (1) Other NAPP, CAPP, ILB and PRB represent the average of power plant deliveries for the three years ending 12/31/2018 per EIA / ABB Velocity Suite. Excludes waste coal. BTU content for

• ther countries from S&P Global Platts.

(2) Domestic NAPP is sourced from CoalDesk LLC’s forecast at 4.75lb sulfur and 13,000 mmBtu

Differentiated Marketing Strategy Provides Strong Revenue Visibility

◼

Entered into a three-year contract with a blue-chip domestic utility at prices above the then-prevailing market prices and capturing a contango in outer years.

◼

Extended previously disclosed export contract through December 31, 2020 and added 3.65 million tons (68% thermal and 32% crossover met coal) in 2H20.

• Increased our 2020 contracted exports position to 7.15 million

tons with an average floor price that is greater than our 2017 average revenue per ton of $45.52.

◼

Total portfolio contracted position now stands at 95+% in 2019, 80% in 2020, and 34% for 2021. Stable Pricing Profile(2)

SLIDE 15

• 10

20 30 40 50 60 70 80 90 China India Vietnam Indonesia Other Asia Remaining Plant Capacities (GW) Under Construction Planned Not Under Construction

+ 64MMt + 47MMt + 28MMt + 15MMt + 15MMt

• 109MMt

600 700 800 900 1,000 1,100 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 Million Tonnes (MMt) Rest of World India Vietnam Bangladesh Philippines Turkey

Solid Global Coal-Fired Generation Capacity Growth Continues

Thermal coal demand expected to grow driven by Asia

15

Total Global Thermal Coal Demand Growth 2018 – 2030 = 59MMt

Source: S&P Global Market Intelligence

• 10

20 30 40 50 60 70 80 90 2019 2020 2021 2022 2023 2024 Plant Capacities (GW) China India Vietnam Indonesia Other Asia Rest of World

Global coal power plant build outs – under construction by year

Total Global Under Construction 2019 – 2024 = 110.6 GW Total Global Planned (not under construction) 2019 & Beyond = 299.5 GW

Global coal power plant build outs – by country

SLIDE 16

6% 12% 0% 2% 4% 6% 8% 10% 12% 14% 2013 2014 2015 2016 2017 2018 2019 48% 44% 40% 42% 44% 46% 48% 50% 2013 2014 2015 2016 2017 2018 2019 $0 $20 $40 $60 $80 $100 $120 $140 Indonesia 3,800 kcal/kg GAR Newcastle 6,000 kcal/kg NAR

Global Demand for PAMC Products Continues to Strengthen

16 Premium import coal as a percentage of total(1) Quality spreads are widening Global coal supply quality is deteriorating… … meanwhile, India is demanding higher quality coals

Avg Price Ratio Aug 2012 to Dec 2017 = 242% Avg Price Ratio Jan 2018 to Jun 2019 = 313%

Source: IHS and S&P Global Market Intelligence (1) Premium coal defined as coal greater than or equal to 5,600 kcal/kg NAR.

SLIDE 17

$0.00 $2.00 $4.00 $6.00 $8.00 $10.00 $12.00 NAPP Coal Henry Hub Spot WTI Crude Oil API 2 Coal - Europe UK LNG Brent Crude Oil Newcastle Coal Japan LNG India LNG China LNG Dubai Crude Oil $/mmBtu

Global Value Proposition for Coal is Unparalleled

17

United States Europe Asia / Pacific

Source: Coaldesk LLC, World Bank, Doyle Trading Consultants, EIA, FERC

Spot / Prompt Prices – June 2019

SLIDE 18

Near-Term LNG Oversupply Expected to Become Shortfall after 2021

18

◼ We believe rising export capacity in US will help tighten the domestic natural gas markets – the linkage

• f natural gas to crude oil.

◼ Global LNG demand growth is expected to soak up the incremental supply around 2021. ◼ LNG demand is mostly based on long term contracts, which could challenge US supply to keep up. ◼ According to Wood Mackenzie, supply additions are expected to slow significantly after 2021 and some

new projects need upward of $7/mmbtu to breakeven.

SLIDE 19

30 50 70 90 110 130 1/2/2018 1/23/2018 2/13/2018 3/6/2018 3/27/2018 4/17/2018 5/8/2018 5/29/2018 6/19/2018 7/10/2018 7/31/2018 8/21/2018 9/11/2018 10/2/2018 10/23/2018 11/13/2018 12/4/2018 12/25/2018 1/15/2019 2/5/2019 2/26/2019 3/19/2019 4/9/2019 4/30/2019 5/21/2019 6/11/2019 7/2/2019 7/23/2019 Index

Stock Performance vs JKM LNG vs API#2

CEIX LNG API#2 30 40 50 60 70 80 9/1/2019 10/1/2019 11/1/2019 12/1/2019 1/1/2020 2/1/2020 3/1/2020 4/1/2020 5/1/2020 6/1/2020 7/1/2020 8/1/2020 9/1/2020 10/1/2020 11/1/2020 12/1/2020 1/1/2021 2/1/2021 3/1/2021 4/1/2021 5/1/2021 6/1/2021 7/1/2021 8/1/2021 9/1/2021 10/1/2021 11/1/2021 12/1/2021 Index

JKM LNG and API#2 Futures

LNG Forwards API#2 Forwards

Current Pullback in CEIX Shares Does Not Reflect Strong Contracted Position

19

Index value is relative to the corresponding actual value on 1/2/2018.

SLIDE 20

Solid Gas Export & Sea-Change in Domestic Production Growth Pace

However production growth has slowed… …driven by major gas shale plays reaching maturity LNG export demand has been positive… …supported by increased export capacity EIA’s upward revisions to export demand U.S. liquefied natural gas export capacity: 2016 – 2021, bn ft / day Public company gas production estimates Gas production by play

Source: Suntrust Robinson Humphrey, EIA Data as of February 2019

No major shale plays discovered since 2011 26 28 30 32 34 36 38 40 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19 3Q19 4Q19 1Q20 2Q20 3Q20 4Q20 Gas Production (BCF/D) Post-1Q18 Post-2Q18 Post-3Q18 Current 2 4 6 8 10 12 14 16 18 Year 1 Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12 Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Gas Production (BCF/D) Fayetteville Barnett Eagle Ford Utica Marcellus

0.0 1.0 2.0 3.0 4.0 5.0 6.0 7.0 8.0 9.0 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Net Exports (BCF/D) 2/19 11/18 8/18 5/18 2/18 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2016 2017 2018 2019 2020 2021 2 4 6 8 10 12

Freeport 1 Freeport 2 Freeport 3 Cameron 1 Cameron 2 Cameron 3 Cove Point Sabine Pass 1 Sabine Pass 2 Sabine Pass 3 Sabine Pass 4 Sabine Pass 5 Elba Island 1–6 Elba Island 7–10 Corpus Christi 1 Corpus Christi 2 Corpus Christi 3 Sabine Pass, Louisiana Cove Point, Maryland Corpus Christi, Texas Cameron, Louisiana Elba Island, Georgia Freeport, Texas

20

SLIDE 21

$1.90 $2.40 $2.90 $3.40 $3.90 $4.40 $30 $35 $40 $45 $50 $55 $60 $65 $70 Jan-15 Apr-15 Jul-15 Oct-15 Jan-16 Apr-16 Jul-16 Oct-16 Jan-17 Apr-17 Jul-17 Oct-17 Jan-18 Apr-18 Jul-18 Oct-18 Jan-19 Apr-19

Forward Gas Price ($/mmBtu) Forward Coal Price ($/ton)

Prompt Year NAPP Low-Sulfur Rail Prompt Year NYMEX Gas $1.32 $1.28 $1.30 $1.31 $1.38 $1.24 $1.32 $1.23 $1.38 $1.37 $1.34 $1.39 3Q16 4Q16 1Q17 2Q17 3Q17 4Q17 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19

With a Highly Competitive Position Versus Natural Gas

21

Source: ABB Velocity Suite, NYMEX, Coaldesk, EIA (1) Calculated as quarterly average cash cost per ton sold based on CEI’s historical SEC filings plus $5 per ton estimated maintenance capex; converted at 13,000Btu/lb and 2,000lbs/ton

Thermal coal price behavior vs. natural gas price PAMC operating cost competitiveness ($/mmbtu)(1)

PAMC’s average all-in cash cost position of ~$1.32/mmBtu versus average natural gas price of $3.00 over the same period has positioned CONSOL well and is expected to continue moving forward

All-in cash cost of coal sold ($/mmbtu)

Strong burn / Inventory drawdown Inventory imbalance ~$3/mmBtu forward gas supports >$45/ton forward coal Strong export market and falling inventories lift coal in spite of softer gas Forward coal and gas well-correlated

• Gas inventories remain low.
• Capital discipline is being

forced onto the E&P space.

SLIDE 22

91 78 2015A 2018A 124 103 2015A 2018A 405 332 2015A 2018A 118 105 2015A 2018A

PAMC Growing Share in Favored US Basin Despite Coal Power Plant Retirements

22

17.3 19.2 17.8 19.7 5.6 5.4 8.3 8.0 22.9 24.6 26.1 27.7 2015 2016 2017 2018 Domestic Tons Export Tons

PAMC has taken advantage of shifting domestic thermal coal demand PAMC sales have increased despite US coal plant retirements Production by basin (million tons) Annual US coal power plant capacity (GW) PAMC annual sales (tons, millions)

271 263 255 242 2015 2016 2017 2018

◼

High cost / unfavorable basin specific dynamics forcing coal production decline in other basins

◼

NAPP is better situated than other US basins − Lower renewable exposure across the region − Access to export seaborne markets − Mine depletion driving production decline

◼

Depleted coal inventories and reduction in supply improving coal pricing dynamics

◼

PAMC has gained market share due to low sulfur / high BTU product

22.8 27.6 2015A 2018A

NAPP PRB ILB CAPP

% change from peak production to 2018(1): (22%) (22%) (24%) (39%)

PAMC

N/A

Source: Bloomberg, SNL and Wood Mackenzie (1) Peak production per Wood Mackenzie between 2013 and 2018

(10.8%) decline in capacity since 2015

SLIDE 23

23

CEIX - Summary of Financial Policy

Deleveraging and targeted shareholder returns

◼

Expect to continue to de-lever the balance sheet through 2020.

◼

Consistent with historical trends, focused on reducing legacy costs and liabilities

◼

Long-term incentive compensation of executives tied to free cash flow generation and total shareholder returns

◼

Accelerate open market equity (CEIX common shares and CCR units) and debt repurchases under the $200 million repurchase authorization; $112mm remaining(1)

◼

Improve return on capital over time through disciplined capital allocation Maintain strong liquidity Disciplined use of capital

◼

Strong liquidity position of $497 million including $155 million of cash and cash equivalents provides flexibility in volatile commodity markets

◼

CEIX cash flow expected to be augmented by CCR via pro rata distributions to unitholders (on ~61%

• wnership interest), interest payments and principal paydowns on Affiliate Loan

◼

Expecting to further improve cash flows and liquidity through expanded surety bond program and expanded revolving credit facility

◼

Continue to operate assets with disciplined approach to capital expenditures

◼

Evaluate other investment opportunities in light of cost of capital, B/S deleveraging and commodity price outlook

◼

Ability to fund opportunistic and accretive growth investments through internally generated cash flows while continuing ongoing debt reduction program

◼

Measured approach to capital spending allows for consistent deleveraging and equity repurchases

(1) $112mm is based on the $25mm Board authorized increase plus the previous $110mm remaining at 3/31/2019 less 2Q19 repurchases of $23mm ($13.5mm second lien, $9.6mm CEIX common shares and $0.1mm CCR common units).

SLIDE 24

$26 $23 $1 $6 $117 $17 $1 $2 $8 $18 $10 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19

CEIX Repayment/Purchase Update

Debt Repayment CEIX Equity Purchases

Note: Chart values in millions. 1Q19 is pre-refinancing transaction. Debt repayment (in both charts) excludes finance lease principal payments of ~$15 million in 2018 and ~$9 million in 1H19. (1) Does not include Term-Loan A or Term-Loan B payments.

24 CCR Equity Purchases

CEIX Accelerating Debt/Equity Repurchases

$12 $26 $33 $57 $65 $88 $38 $24 $67 $43 $110 $112 $50 $50 $100 $100 $175 $200 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19

CEIX Repurchase Program Authorization(1)

Cumulative Repurchases Remaining Availability

• Total debt repayment of $190MM since the

beginning of 2018.

• Total CEIX and CCR share/unit repurchases
• f $39MM since the beginning of 2018.
• CEIX’s Board of Directors has increased the

repurchase authorization by $25MM to an aggregate amount of up to $200MM.

• Current availability of $112MM.
• Does not include finance lease payments of

~15 million in 2018 and ~9 million in 1H19.

SLIDE 25

For the Quarter Ended Guidance June 30, 2019 June 30, 2018 Change CEIX 2019(5) CCR 2019(5) Pennsylvania Mining Complex

Volumes (MM Tons) Production 7.2 7.7 (0.5) Sales 7.4 7.8 (0.4) 26.8 - 27.8 6.70 - 6.95 Operating Metrics ($/Ton) Average Revenue per Ton Sold $47.53 $47.34 $0.19 $47.00 - $48.00 $47.00 - $48.00 Average Cash Cost per Ton Sold(1) $31.07 $26.99 $4.08 $30.40 - $31.40 $30.40 - $31.40 Average Cash Margin per Ton Sold(1) $16.46 $20.35 ($3.89)

CONSOL Marine Terminal

Volumes (MM Tons) Throughput Volume 3.7 3.5 0.2 Financials ($MM) Terminal Revenue 17 17

• Operating and Other Costs

5 6 (1) CONSOL Marine Terminal Adjusted EBITDA(2) 11 10 1 $42 - $45

CEIX Financials ($MM)

Adjusted EBITDA(2) 113 136 (23) $390 - $420 Capital Expenditures(3) 49 34 15 $155 - $185 Organic Free Cash Flow Net to CEIX Shareholders(4) 29 123 (94) Dilutive Earnings per Share ($/share) $1.56 $1.58 ($0.02)

CCR Financials ($MM)

Adjusted EBITDA(2) 28 34 (6) $95 - $103 Capital Expenditures 10 7 3 $34 - $38 Organic Free Cash Flow(4) 12 42 (30)

Earnings Results

Second Quarter Results and 2019 Guidance

25

(1) “Average cash cost per ton sold” and “average cash margin per ton sold” are operating ratios derived from non-GAAP financial measures; each are reconciled to the most directly comparable GAAP financial measure in the appendix. (2) Adjusted EBITDA and CONSOL Marine Terminal Adjusted EBITDA are non-GAAP financial measures. Please see the appendix for a definition of Adjusted EBITDA and a reconciliation to net income. (3) The 2019 capital guidance figure now includes the recently approved Itmann project. (4) Organic Free Cash Flow Net to CEIX Shareholders, a non-GAAP financial measure, is defined as Net Cash Provided by Operations less Capital Expenditures, less Distributions to Noncontrolling Interest. Organic Free Cash Flow is a non-GAAP financial measure defined as Net Cash Provided by Operations less Capital Expenditures. Please see the appendix for a reconciliation. (5) CEIX & CCR are unable to provide a reconciliation of adjusted EBITDA guidance or CONSOL Marine Terminal Adjusted EBITDA guidance to net income, the most comparable financial measure calculated in accordance with GAAP, nor a reconciliation of average cash cost per ton sold, an operating ratio derived from non-GAAP financial measures, due to the unknown effect, timing and potential significance of certain income statement items.

SLIDE 26

CCR Financial Metrics ($MM except ratio) LTM 6/30/2019 Leverage

EBITDA per Affiliated Company Credit Agreement(1) $110 Net Debt per Affiliated Company Credit Agreement(3) 171 Net Leverage Ratio(1) 1.6x

Liquidity (as of 6/30/2019)

Cash and Cash Equivalents Affiliated Company Credit Agreement Less: Amount Drawn Total CCR Liquidity $0 275 (165) $110

Adjusted Method Bank Method LTM 6/30/2019 LTM 6/30/2019 Leverage

EBITDA(1)(2) $430 $345 Consolidated Net Debt(3) 599 599 Net Leverage Ratio(1) 1.4x 1.7x Adjusted EBITDA Attributable to CONSOL Energy Shareholders(1) $388 Consolidated Net Debt less Non-controlling Portion of CCR Affiliate Loan(4) 535 Modified Net Leverage Ratio(1) 1.4x

Liquidity (as of 6/30/2019)

Cash and Cash Equivalents less CCR Cash(5) Revolving Credit Facility Accounts Receivable Securitization (lesser of $100MM and A/R borrowing base) Restricted Cash - Securitization Less: Letters of Credit Outstanding Total CEIX Liquidity

CEIX Financial Metrics ($MM except ratios)

$155 400 34 (96) 4 $497

Leverage and Liquidity Analysis

26

(1) “EBITDA”, “Adjusted EBITDA”, “Bank EBITDA”, “Adjusted EBITDA Attributable to CONSOL Energy Shareholders” and “EBITDA per Affiliated Company Credit Agreement” are non-GAAP financial

• measures. Net leverage ratio and modified net leverage ratio are an operating ratios derived from non-GAAP financial measures. Please see the appendix for a reconciliation to net income.

(2) Adjusted Method is based on “Adjusted EBITDA” and Bank Method is based on “Bank EBITDA”. (3) See appendix for a reconciliation. (4) Calculated as consolidated net debt of $599 million less the 38.6% public ownership of CCR’s Affiliate Loan of ~$165 million. (5) Calculated as CEIX cash and equivalents of $156 million as of 6/30/2019 less CCR cash and equivalents of $0.5 million as of 6/30/2019. Some numbers may not foot due to rounding.

SLIDE 27

12% 3% 8% CEIX LTM 6/30/2019 E&P 2015A-2018A 27

Source: CONSOL Energy Inc. management and Factset (1) CEIX return on capital has been adjusted to exclude legacy liability expense in the numerator as it is already captured as a liability in the denominator. Return on capital is an operating ratio derived from a non-GAAP financial measure which is reconciled to the most directly comparable GAAP financial measure in the appendix. (2) CEIX EBIT has been adjusted to remove the effect of the 1Q19 refinancing transaction to remain consistent with prior period calculations. (3) Calculated as the weighted average interest expense for TLA, TLB, 2nd Lien Notes and Baltimore Bonds multiplied by their respective interest rates. Assumed LIBOR of 2.30% for TLA and TLB. (4) Return on capital for E&P is defined as EBIT/(Total Assets – Current Liabilities). No adjustment has been made to exclude E&P group companies’ legacy liability expense. (5) Comparable E&P universe = CHK, COG, RRC, SWN, EQT, REP, EOG, AR, and GPOR.

Return on Capital Highlights the Need for Rising Commodity Prices

Return on Capital(1)(2) Weighted Average Cost of Debt(3) Return on Capital(4)

(5)

◼ The goal is to raise CEIX’s Return on Capital(1) over time while lowering its WACC. ◼ Focused on margins and corporate returns instead of just growth. ◼ Low production decline for coal assets vs. very steep initial decline for natural gas shale assets. ◼ Ability to export a high percentage of production to capture the highest BTU value chain. ◼ Use our free cash flow generation to improve our cost of capital and increase returns to

shareholders over time.

CEIX’s weighted average cost of debt is ~1% lower vs YE2018 due to the recent 1Q19 refinancing

SLIDE 28

◼ PA Mining Complex’s MSHA reportable incident rate was 34% lower than the industry average from 2014- 2018.1 ◼ 2018 Marked 5th consecutive year with an environmental compliance record exceeding 99.9%.1 ◼ Board level HSE Committee oversees procedures for identifying, assessing, monitoring, and managing ESG risks.

Our Legacy is Built on Safety, Compliance, and Continuous Improvement Our Future is Based on Efficiency, Technology, and Innovation

Corporate Sustainability Approach

(1) CONSOL management and corporate sustainability report. (2) B Riley FBR, Can Coal Miners Weather the ESG Storm?, Industry Update, May 13, 2019. (3) Thomson Reuters, Transparency: The Pathway to Leadership for Carbon Intensive Businesses, February, 2019.

ESG Aspects of Greatest Stakeholder Concern and Impact to CONSOL

◼ Innovative technologies deployed at PA Mining Complex directly relate to ESG aspects of greatest impact to CONSOL. ◼ Partnerships with Komatsu Mining Corporation, Environmental Commodities Corporation, and OMNIS Bailey, LLC. ◼ Recently recognized for sector leadership in ESG disclosures, transparency, and strategic initiatives.2,3

28

SLIDE 29

ESG Priorities: Creating Shared Value

(1) U.S. Energy Information Administration, 2018 For more information, visit: www.consolenergy.com/responsibility

Environment Society Business

• Producing high-Btu bituminous coal; carbon intensity 5-20% below other ranks.1
• Marketing to low heat rate, environmentally controlled customers.
• Expanding methane destruction program to decrease direct emissions.
• Reducing water use intensity through focused reuse and recycling.

Shared Value

• Supporting the health, wellness, and professional development of our workforce.
• Developing community partnerships through the CONSOL Cares Foundation.
• Expanding global access to electricity, through participation in the export market.
• Providing a reliable, resilient, and affordable source of domestic energy.
• Integrating sound governance principals and strong operational performance.
• Incentivizing ESG performance at all levels with compensation awards.
• Maintaining transparency, disclosure, engagement, and risk management.
• Contributing more than $1B to the economy annually.

29

SLIDE 30

Appendix

30

SLIDE 31

Organizational Structure Overview

31

100%

• wnership

interest

CONSOL Energy Inc. NYSE: CEIX ~28 million shares outstanding

Pennsylvania Mining Complex CONSOL Coal Resources GP LLC (“our general partner”) General Partner Interest CONSOL Coal Resources LP NYSE: CCR 100%

• wnership interest

1.7% general partner interest 38.6% limited partner interest 25% undivided ownership interest and management and control rights 75% undivided

• wnership interest(1)

59.7% limited partner interest CONSOL Marine Terminal 1.6 billion tons of undeveloped reserves(2) Public and Private Placement 10,840,361 Common Units Source: CONSOL Energy Inc. filings and Management. (1) Owned through CONSOL Pennsylvania Coal Company LLC (“CPCC”) and Conrhein Coal Company (“Conrhein”). (2) Through various subsidiaries and associated entities.

SLIDE 32

$1,497 $1,362 $1,267 $1,163 $1,067 $1,050 $139 $133 $92 $73 $75 $72 2014 2015 2016 2017 2018 LTM 6/30/2019

Total Legacy Liabilities Total Annual Legacy Liabilities Cash Servicing Cost

Legacy liabilities ($mm) Balance Sheet Value Cash Servicing Cost LTM 6/30/2019 Long-term disability 11 2 Workers’ compensation 71 12 Coal workers’ pneumoconiosis 176 13 Other post-employment benefits 465 34 Pension obligations 59 1 Asset retirement obligations 267 9 Total legacy liabilities 1,050 72 6/30/2019

CEIX Balance Sheet Legacy Liabilities, Manageable and Declining

32 2022E Payments 2019E Payments

$62 $58

CEIX legacy liabilities and cash costs

($ mm)

CEIX employee-related liability projections

OPEB CWP Workers' Comp LTD NQ Pension

Significant legacy liability reductions over past three years

◼

The impact of administrative changes in 2016 & 2017 reduced our OPEB liability without impacting the level of benefits delivered to beneficiaries.

◼

Furthermore, the balance sheet reduction we’ve seen in 2018 vs 2017 is a result of a decreasing trend of actual claims over the prior 3 years.

◼

Cash payments related to legacy liabilities are declining over time.

◼

Considerable tax benefits are associated with legacy liability payments.

◼

Legacy liabilities could be viewed as payment obligations between unsecured debt and equity on a company’s balance sheet.

◼

Approximately 69% of all CEIX employee liabilities are closed classes.

−

Actuarial and demographic developments continue to drive medium- term reduction in liabilities.

−

Actively managing costs down.

◼

CEIX’s Qualified Pension Plan was 93% funded as of 12/31/2018 as compared to 85% for the S&P 1500 qualified plans.(1)

−

The investment performance over the 10 years ended 12/31/2018 has been in the top quartile of all corporate pension plans.

(1) Source: Mercer Some totals may not foot due to rounding.

SLIDE 33

Experienced Management with Enhanced Focus on Safety, Compliance and Financial Discipline

33

Jim McCaffrey Chief Commercial Officer

◼

CCO and SVP of Coal Marketing since 2017

◼

SVP – Energy Marketing for CNX from 2013 to 2016

◼

42 years in industry, all at CONSOL Kurt Salvatori Chief Administrative Officer

◼

VP– Administration for CEIX since 2017

◼

Previously served as VP Shared Services for CNX from 2016 – 2017

◼

Has held variety of HR positions at CONSOL

◼

27 years in industry all at CONSOL Jimmy Brock President and Chief Executive Officer

◼

President and CEO since 2017

◼

COO – Coal for CNX from 2010 – 2017

◼

Appointed CEO and Director of CCR in 2015

◼

40 years in coal industry, all at CONSOL David Khani EVP, Treasurer and Chief Financial Officer

◼

EVP and CFO of CEIX since 2017, held same positions at CNX from 2013 – 2017

◼

CCR CFO & Director; same roles at CONE Midstream Partners from 2014 – 2018

◼

25 years in metals & mining, oil & gas and coal industries, including 8 at CONSOL Eric Schubel VP – Operations

◼

VP – Operations, overseeing the Pennsylvania Mining Complex since 2017

◼

Served as General Superintendent at various mining operations for CONSOL

◼

34 years in industry, all at CONSOL Martha Wiegand General Counsel and Secretary

◼

General Counsel and Secretary of CEIX since 2017; has held same role at CCR since 2015

◼

Served as Associate General Counsel for CNX from 2012 – 2015

◼

Legal career spanning 19 years

◼

11 years of experience at CONSOL

◼

Significant expertise owning, developing, and managing coal and associated infrastructure assets − Reduced operating costs per ton sold by 21% from 2014–2018

◼

Strong focus on safety and compliance standards − PAMC's Mine Safety and Health Administration ("MSHA") reportable incident rate was ~34% lower than the industry average in 2014-2018 − PAMC’s MSHA significant and substantial citation rate was 36% lower than the industry average for YE 2018 − Executive and workforce compensation tied in part to environmental and safety performance

◼

Addressing environmental and legacy liabilities − Cash servicing costs reduced from $139mm in 2014 to $72mm LTM 6/30/2019

◼

Management incentivized to improve free cash flow and continue to de-leverage balance sheet

◼

Strong commitment to environmental responsibility − Environmental compliance rate of 99.9% − Taken action to reduce scope 1 (direct greenhouse gas) emissions by 50% since 2011

◼

CEIX’s management and operating teams have a long history in the coal industry − Proven track record of successfully building, enhancing and managing coal assets − Focus on growing return on capital through strategic capital allocation grounded in detailed commodity analysis

◼

CEIX management has a strong focus on financial discipline − Demonstrated ability to improve operating performance and maintain low cash costs − Primary use of organic FCF(1) will be to de-lever the balance sheet through 2020

Source: CONSOL management Note: Effective November 28, 2017, the company known as CONSOL Energy Inc. (NYSE: CNX) separated its natural gas business (GasCo or RemainCo) and its coal business (CoalCo or SpinCo) into two independent, publicly traded companies by means of a separation of CoalCo from RemainCo. CNX refers to former CONSOL Energy Inc. prior to spin. CEIX refers to current CONSOL Energy Inc. (CoalCo). CCR refers to the CONSOL Coal Resources, MLP, formerly CNX Coal Resources. “CONSOL” refers to current and prior CONSOL Energy Inc. entities. (1) Organic free cash flow is defined as operating cash flow less capital expenditures.

Key performance results Experienced management team

SLIDE 34

EBITDA Reconciliation LTM 2Q19 2Q18 6/30/2019 Net Income $48.8 $52.7 $124.3 Plus: Interest Expense, net 16.0 21.5 75.9 Interest Income (0.8) (0.5) (2.7) Income Tax (Benefit) Expense (1.8) 3.0 (3.0) Depreciation, Depletion and Amortization 46.2 55.0 193.7 EBITDA $108.5 $131.7 $388.1 Plus: Loss on Debt Extinguishment 1.5 1.7 25.4 Stock/Unit-Based Compensation 2.9 2.8 16.0 Total Pre-tax Adjustments 4.4 4.5 41.4 Adjusted EBITDA $112.9 $136.3 $429.5 Less: Adjusted EBITDA Attributable to Noncontrolling Interest (10.8) (13.1) (42.0) Adjusted EBITDA Attributable to CONSOL Energy Inc. Shareholders $102.1 $123.1 $387.5 Organic Free Cash Flow Net to CEIX Shareholders Reconciliation 2Q19 2Q18 Net Cash Provided by Operations $83.6 $162.5 Less: Capital Expenditures (48.8) (34.2) Organic Free Cash Flow $34.8 $128.2 Less: Distributions to Noncontrolling Interest (5.6) (5.6) Organic Free Cash Flow Net to CEIX Shareholders $29.3 $122.6

CEIX Adjusted EBITDA & Organic Free Cash Flow Net to CEIX Shareholders Reconciliations

34

Some totals may not foot due to rounding.

SLIDE 35

EBITDA Reconciliation 2Q19 2Q18 Net Income $14.4 $19.4 Plus: Interest Expense, Net 1.6 1.8 Depreciation, Depletion and Amortization 11.3 11.9 EBITDA $27.3 $33.1 Plus: Unit-Based Compensation 0.3 0.5 Adjusted EBITDA $27.6 $33.6 Organic Free Cash Flow Reconciliation 2Q19 2Q18 Net Cash Provided by Operations $21.9 $48.9 Less: Capital Expenditures (10.0) (7.3) Organic Free Cash Flow $11.9 $41.7

CCR Adjusted EBITDA & Organic Free Cash Flow Reconciliations

35

Some totals may not foot due to rounding.

SLIDE 36

CEIX Net Leverage Ratio Reconciliations

Adjusted Method Bank Method LTM 6/30/2019 LTM 6/30/2019

Net Income $124 $124 Plus: Interest Expense, net $76 $76 Interest Income ($3) ($3) Income Tax Expense ($3) ($3) EBIT $194 $194 Plus: Depreciation, Depletion and Amortization $194 $194 EBITDA $388 $388 Plus: Stock/Unit-Based Compensation $16 $16 Loss on Debt Extinguishment $25 $25 Total Pre-tax Adjustments $41 $41 Adjusted EBITDA $430 $430 Less: CCR EBITDA per Affiliated Company Credit Agreement, Net of Distributions Received

• ($75)

Employee Legacy Liability Payments, Net of Provision

• ($17)

Other Adjustments

• $8

Bank EBITDA

• $345

Total Long-Term Debt $713 $713 Plus: Current Portion of Long-Term Debt $38 $38 Plus: Debt Issuance Costs $12 $12 Less: CCR Finance Leases ($7) ($7) Less: Advanced Mining Royalties ($2) ($2) Less: CEIX Cash and Cash Equivalents ($155) ($155) Consolidated Net Debt 599 599 Net Leverage Ratios 1.4x 1.7x

CEIX Net Leverage Ratio Reconciliations

36

Some totals may not foot due to rounding.

SLIDE 37

CEIX Return on Capital Reconciliation LTM 6/30/2019 Net Income $124 Plus: Interest Expense, net $76 Interest Income ($3) Income Tax Expense ($3) EBIT $194 Add Legacy Liability Payments 72 Add Loss on Debt Extinguishment due to 1Q19 Refinancing Transaction(1) 19 EBIT less Legacy Liability Expense $286 Total Assets $2,765 Less Current Liabilities ($408) Total Capital Employed $2,357 Return on Capital 12%

Some totals may not foot due to rounding. (1) EBIT has been adjusted for the 1Q19 refinancing transaction to remain consistent with prior period calculations for CEIX.

CEIX Return on Capital Reconciliation

37

SLIDE 38

CCR Net Leverage Ratio Reconciliation LTM 6/30/2019 Net Income $54.8 Plus: Interest Expense, net 5.8 Depreciation, Depletion and Amortization 44.6 Unit-Based Compensation 1.7 Non-Cash Expense, Net of Cash Payments for Legacy Employee Liabilities 1.4 Other Adjustments to Net Income 2.0 EBITDA Per Affiliated Company Credit Agreement $110.3 Borrowings under Affiliated Company Credit Agreement $165.0 Finance Leases 6.7 Total Debt $171.7 Less: Cash on Hand 0.5 Net Debt per Affiliated Company Credit Agreement $171.2 Net Leverage Ratio (Net Debt/EBITDA) 1.6x

CCR Net Leverage Ratio Reconciliation

38

Some totals may not foot due to rounding.

SLIDE 39

(MM except per share data) 2Q19 2Q18 Net Income $49 $53 Plus: Adjustments to Net Income

• Plus: Tax Benefit of Adjustments to Net Income
• Adjusted Net Income

49 53 Less: Net Income Attributable to Noncontrolling Interest 6 8 Adjusted Net Income Attributable to CONSOL Energy Inc. Shareholders $43 $45 Weighted-Average Diluted Shares of Common Stock Outstanding 27.8 28.6 Earnings per Share: Dilutive Earnings per Share $1.56 $1.58 Plus: Adjustments to Net Income Attributable to CONSOL Energy Inc. Shareholders

• Adjusted Dilutive Earnings per Share

$1.56 $1.58

Adjusted Net Income and Adjusted Dilutive EPS Reconciliations

39

Some totals may not foot due to rounding.

SLIDE 40

($MM except per ton data) 2Q19 2Q18 Total Coal Revenue $351 $371 Operating and Other Costs 253 248 Less: Other Costs (Non-Production) (23) (36) Total Cash Cost of Coal Sold 230 212 Add: Depreciation, Depletion and Amortization 46 55 Less: Depreciation, Depletion and Amortization (Non-Production) (3) (10) Total Cost of Coal Sold $273 $258 Average Revenue per Ton Sold $47.53 $47.34 Average Cash Cost per Ton Sold $31.07 $26.99 Depreciation, Depletion and Amortization Costs per Ton Sold $6.00 $5.91 Average Cost per Ton Sold $37.07 $32.90 Average Margin per Ton Sold $10.46 $14.44 Add: Depreciation, Depletion and Amortization Costs per Ton Sold $6.00 $5.91 Average Cash Margin per Ton Sold $16.46 $20.35

Average Cash Margin and Average Cost per Ton Sold Reconciliations

40

Some totals may not foot due to rounding.

SLIDE 41

CMT Adjusted EBITDA Reconciliation

41

Some totals may not foot due to rounding.

CMT EBITDA Reconciliation 2Q19 2Q18 Net Income $8.2 $7.9 Plus: Interest Expense, net 1.5 1.5 Depreciation, Depletion and Amortization 1.4 1.0 EBITDA $11.2 $10.4 Plus: Stock/Unit-Based Compensation 0.1 0.1 Total Pre-tax Adjustments 0.1 0.1 Adjusted EBITDA $11.3 $10.5