EARNINGS RESULTS FIRST QUARTER 2017
Cautionary Language 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 our operational and strategic plans; estimates of coal and gas reserves and resources; the projected timing and rates of return of future investments; and projections and estimates of future production, revenues, income and capital spending. These forward-looking statements involve risks and uncertainties that could cause actual results to differ materially from those statements, plans, estimates and projections. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of future actual results. Factors that could cause future actual results to differ materially from the forward-looking statements include risks, contingencies and uncertainties that relate to, among other matters, the following: we may not receive the prices we expect to receive for our natural gas, natural gas liquids, and coal, including due to oversupply relative to the demand available for our products; we may not obtain on a timely basis the permits required for drilling and mining; we may not accurately estimate the volume of hydrocarbons that are recoverable from our oil and natural gas assets; we may encounter unexpected operational issues or disruptions when we drill and mine, including equipment failures, geological conditions, and higher than expected costs for equipment, supplies, services and labor, including with respect to third-party contractors; we may not achieve the efficiencies we expect to realize in our drilling and completion operations, and as a result, our projected cost savings may not be fully realized; our participation in joint ventures may restrict our operational and corporate flexibility, and actions taken by a joint venture partner may impact our financial position and operational results; we may not be able to sell non-core assets on acceptable terms; acquisitions and divestitures that we anticipate making or have made may not occur or produce anticipated benefits, or may cause disruptions to our business operations; we may be subject to environmental and other government regulations that adversely impact our operating costs and the market for our natural gas and coal; failure by Murray Energy to satisfy liabilities it acquired from us, or failure to perform its obligations under various arrangements, which we guaranteed, could materially or adversely affect our results of operations, financial position, and cash flows; we may be unable to incur indebtedness on reasonable terms; provisions in our multi-year coal sales contracts may provide limited protection and may result in economic penalties to us or permit the customer to terminate the contract; the majority of our common units in CNX Coal Resources LP are subordinated, and we may not receive related distributions; there is no assurance that the potential dropdowns, spin-off or sale of the coal business will occur, or if it does occur that we will be able to negotiate favorable terms; and other factors, many of which are beyond our control. Additional factors are described in detail under the captions "Forward Looking Statements" and "Risk Factors" in CONSOL Energy Inc.’s annual report on Form 10 -K for the year ended December 31, 2016 filed with the Securities and Exchange Commission (SEC), as updated by any subsequent quarterly reports on Form 10-Qs. 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. Currently, the SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable and possible oil and gas reserves that a company anticipates as of a given date to be economically and legally producible and deliverable by application of development projects to known accumulations. We may use certain terms in this presentation, such as EUR (estimated ultimate recovery), unproved reserves and total resource potential, that the SEC's rules strictly prohibit us from including in filings with the SEC. We caution you that the SEC views such estimates as inherently unreliable and these estimates may be misleading to investors unless the investor is an expert in the natural gas industry. These measures are by their nature more speculative than estimates of reserves prepared in accordance with SEC definitions and guidelines and accordingly are less certain. We also note that the SEC strictly prohibits us from aggregating proved, probable and possible reserves in filings with the SEC due to the different levels of certainty associated with each reserve category. Except for proved reserve data, the information included in this presentation is based on a summary review of the title to the gas rights we hold. As is customary in the gas industry, prior to the commencement of natural gas drilling operations on our properties, we conduct a thorough title examination and perform curative work with respect to significant defects. We are typically responsible for curing any title defects at our expense. As a result of our title review or otherwise, we may be required to acquire property rights from third parties at our expense in order to effectively drill and produce the gas rights we control and third parties may participate in the wells we drill, thereby reducing our working interest in those wells. This presentation does not constitute an offer to sell or a solicitation of offers to buy securities of CONSOL Energy Inc. or CNX Coal Resources LP. 2
Q1 2017 Highlights Continue to expect annual production growth and free cash flow Free Cash Flow generation Raising 2017 and 2018 production guidance based on improved cycle times Production and optimized type curves EBITDA Raising 2017 EBITDA guidance by 7% Repurchased approximately $100 million of debt in Q1 2017; have paid Debt down ~$1.3 billion since 2015 when total debt peaked at ~$3.7 billion Leverage Ratio Expect to reach our target leverage ratios quicker than our 4Q16 forecast 3
Operations: E&P Results Summary Y/Y Q/Q 1Q 2017 (1) Change 1Q 2017 (1) 1Q 2016 4Q 2016 Change Average Sales Price (1) ($/Mcfe) $2.85 $2.73 $0.12 $2.85 $2.77 $0.08 Total Production Costs (2) ($/Mcfe) $2.32 $2.41 ($0.09) $2.32 $2.27 $0.05 Sales Volumes (Bcfe) 95.0 97.5 (2.5) 95.0 101.3 (6.3) Sales Volumes (Bcfe) by Category Marcellus 58.0 51.2 6.8 58.0 56.5 1.5 Utica 15.3 22.9 (7.6) 15.3 22.2 (6.9) CBM 16.7 17.6 (0.9) 16.7 17.4 (0.7) Other 5.0 5.8 (0.8) 5.0 5.2 (0.2) (1) Average Sales Prices for 1Q2017, 1Q2016, and 4Q2016 include gains/(loss) on commodity derivative instruments (cash settlements) of ($0.55), $0.98, and $0.46, respectively. (2) Average Costs for 1Q2017, 1Q2016, and 4Q2016 include DD&A of $1.01, $1.08, and $1.05, respectively. • Adjusted earnings before income tax for E&P Division of $19.9 million (3) • Marcellus Shale total production costs were $2.18 per Mcfe in the first quarter, a decrease of $0.27 from $2.45 per Mcfe in the year-earlier quarter, or an 11% improvement - Driven primarily by reductions to lease operating expense and DD&A rates • Utica Shale total production costs were $2.16 per Mcfe in the first quarter, an increase of $0.37 from $1.79 per Mcfe in the year-earlier quarter, or a 21% impairment - Driven by an increase in firm transportation and processing costs, property taxes, and DD&A rates (3) Adjusted earnings before income tax for the E&P Division of $19.9 million for the three months ended March 31, 2017 is calculated as GAAP loss before income tax of $93.5 million plus total pre-tax adjustments of $113.4 million. The $113.4 million adjustment is a $24.6 million pre-tax gain related to the unrealized gain on commodity derivative instruments, a pre-tax loss of $137.9 million related to the impairment of exploration and production assets and a pre-tax loss of $0.1 million related to severance expense. 4
Operations: Operations Summary SWPA SWPA WV OH Q1 2017 Summary Marcellus Upper Devonian Marcellus Dry Utica TOTAL Horizontal Rigs 1 - - 1 2 Drilled 2 - - 7 9 Completed 5 - 2 4 11 Turned In Line (TIL) 5 1 - - 6 Avg. TIL Lateral Length (ft) 9,417 10,663 - - 9,625 Production Efficiency Highlights Two-Year TIL Schedule • OPEX Efficiencies: Reduced Q1 2017 LOE by 2018 2017 $6.1 million, improving unit costs by TD TIL TD TIL $0.05/Mcfe Y/Y Marcellus 8 31 33-41 15-20 • Production Surveillance: Improved Utica production surveillance yielded a 72% Y/Y 17 26 26-31 21-25 reduction in lost volume due to downtime, Upper Devonian - 3 - - driving production improvements of ~1.2 CBM 63 63 20-25 25-30 Bcfe and incremental revenue of $3.8 million • Production Facilities: Additional focus on TOTAL ex. CBM 25 60 59-72 36-45 production facilities optimization resulted in • Total E&P and Midstream CapEx guidance a ~3% reduction in CAPEX and a five-day remains unchanged: reduction in installation cycle time - 2017E: $555 million - 2018E: $600 million 5
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