Location via proxy:   [ UP ]  
[Report a bug]   [Manage cookies]                
SlideShare a Scribd company logo

Utica Shale Divestiture and PRB Update

•Download as PPTX, PDF•
•
Chesapeake Energy Corporation
Chesapeake Energy Corporation

The document provides an overview of Chesapeake Energy's Utica Shale divestiture and an update on its Powder River Basin operations. Key points include: - Chesapeake sold its Utica Shale assets for $2 billion in net proceeds, reducing its debt and focusing on its highest return Powder River Basin assets. - The sale included over 300,000 net acres and 107,000 boe/d of net production in Ohio's Utica Shale, transferring future midstream commitments. - In the Powder River Basin, production is growing rapidly through development in the Turner area, with over 90% oil growth year-to-date and 100% expected growth in

1 of 8
UTICA SHALE DIVESTITURE AND POWDER RIVER BASIN UPDATE July 26, 2018
FORWARD-LOOKING STATEMENTS This presentation includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements are statements other than statements of historical fact. They include statements that give our current expectations, management's outlook guidance or forecasts of future events, production and well connection forecasts, effects and results of the Utica divestiture, estimates of operating costs, anticipated capital and operational efficiencies, planned development drilling and expected drilling cost reductions, anticipated timing of wells to be placed into production, general and administrative expenses, capital expenditures, the timing of anticipated asset sales and proceeds to be received therefrom, the expected use of proceeds of anticipated asset sales, projected cash flow and liquidity, our ability to enhance our cash flow and financial flexibility, plans and objectives for future operations, the ability of our employees, portfolio strength and operational leadership to create long-term value, and the assumptions on which such statements are based. Although we believe the expectations and forecasts reflected in the forward- looking statements are reasonable, we can give no assurance they will prove to have been correct. They can be affected by inaccurate or changed assumptions or by known or unknown risks and uncertainties. Factors that could cause actual results to differ materially from expected results include those described under “Risk Factors” in Item 1A of our annual report on Form 10-K and any updates to those factors set forth in Chesapeake’s subsequent quarterly reports on Form 10-Q or current reports on Form 8-K (available at http://www.chk.com/investors/sec- filings). These risk factors include, satisfaction of closing conditions, actions by the buyer, the volatility of oil, natural gas and NGL prices; the limitations our level of indebtedness may have on our financial flexibility; our inability to access the capital markets on favorable terms; the availability of cash flows from operations and other funds to finance reserve replacement costs or satisfy our debt obligations; downgrade in our credit rating requiring us to post more collateral under certain commercial arrangements; write-downs of our oil and natural gas asset carrying values due to low commodity prices; our ability to replace reserves and sustain production; uncertainties inherent in estimating quantities of oil, natural gas and NGL reserves and projecting future rates of production and the amount and timing of development expenditures; our ability to generate profits or achieve targeted results in drilling and well operations; leasehold terms expiring before production can be established; commodity derivative activities resulting in lower prices realized on oil, natural gas and NGL sales; the need to secure derivative liabilities and the inability of counterparties to satisfy their obligations; adverse developments or losses from pending or future litigation and regulatory proceedings, including royalty claims; charges incurred in response to market conditions and in connection with our ongoing actions to reduce financial leverage and complexity; drilling and operating risks and resulting liabilities; effects of environmental protection laws and regulation on our business; legislative and regulatory initiatives further regulating hydraulic fracturing; our need to secure adequate supplies of water for our drilling operations and to dispose of or recycle the water used; impacts of potential legislative and regulatory actions addressing climate change; federal and state tax proposals affecting our industry; potential OTC derivatives regulation limiting our ability to hedge against commodity price fluctuations; competition in the oil and gas exploration and production industry; a deterioration in general economic, business or industry conditions; negative public perceptions of our industry; limited control over properties we do not operate; pipeline and gathering system capacity constraints and transportation interruptions; terrorist activities and cyber-attacks adversely impacting our operations; an interruption in operations at our headquarters due to a catastrophic event; certain anti-takeover provisions that affect shareholder rights; and our inability to increase or maintain our liquidity through debt repurchases, capital exchanges, asset sales, joint ventures, farmouts or other means. In addition, disclosures concerning the estimated contribution of derivative contracts to our future results of operations are based upon market information as of a specific date. These market prices are subject to significant volatility. Our production forecasts are also dependent upon many assumptions, including estimates of production decline rates from existing wells and the outcome of future drilling activity. Expected asset sales may not be completed in the time frame anticipated or at all. We caution you not to place undue reliance on our forward-looking statements, which speak only as of the date of this presentation, and we undertake no obligation to update any of the information provided in this presentation, except as required by applicable law. In addition, this presentation contains time-sensitive information that reflects management's best judgment only as of the date of this presentation. We use certain terms in this presentation such as “Resource Potential,” “Net Reserves” and similar terms that the SEC’s guidelines strictly prohibit us from including in filings with the SEC. These terms include reserves with substantially less certainty, and no discount or other adjustment is included in the presentation of such reserve numbers. U.S. investors are urged to consider closely the disclosure in our Form 10-K for the year ended December 31, 2017, File No. 1-13726 and in our other filings with the SEC, available from us at 6100 North Western Avenue, Oklahoma City, Oklahoma 73118. These forms can also be obtained from the SEC by calling 1-800-SEC-0330. 2July 26, 2018 – Update
UNLOCKING OUR FUTURE UTICA SHALE DIVESTITURE (1) Assumes flat 2018 commodity prices and basis differentials (2) Estimated at 1/1/2019 July 26, 2018 – Update 3
UTICA DIVESTMENT OVERVIEW July 26, 2018 – Update 4 (1) For calendar year 2017 (2) At 12/31/2017 Buyer Encino Acquisition Partners Purchase price $2.0 billion Net proceeds for debt $1.9 billion Potential commodity price adjustment (expires 12/31/2019) $100 million Net core acres 320,000 Well count (operated and non-operated) 920 Net production(1) 107,000 boe/d Gas / NGL / Oil 67% / 24% / 9% YE2017 Reserves(2) 480 mmboe Future midstream and downstream commitments (assumed by buyer) $2.4 billion 2017 EBITDA $455 million 2017 Capex $471 million CHK UTICA ACREAGE POSITION OHIO CHK Core Leasehold CHK Non-Core Leasehold ASSETSTATSDEAL
TRANSFORMING INTO A MORE COMPETITIVE COMPANY(1) July 26, 2018 – Update 5 (1) Gives effect to Utica Shale divestiture (2) Production expense, G&A and stock-based compensation
0 10 20 30 40 50 60 70 80 Q1 2017 Q2 2017 Q3 2017 Q4 2017 Q1 2018 Q2 2018 Q3 2018 Q4 2018 Q1 2019 Q2 2019 Q3 2019 Q4 2019 NetProduction(mboe/d) Liquids Gas Analyst Day 2016 POWDER RIVER BASIN PRODUCTION GROWING RAPIDLY ~90% OIL GROWTH YTD, ~100% EXPECTED IN 2019 (1) July 26, 2018 – Update 6 (1) Projected annual growth in 2019 compared to 2018 projected annual volumes (2) As of 7/24/2018, net volume (3) Forecast presented at Analyst Day 2016 1 – 3 Rigs 4 – 5 Rigs 32 mboe/d Current field rate (2)
TURNER LEADING THE WAY THE PREMIER PRB OPPORTUNITY • Progress to date ˃ De-risking acreage ˃ 18 Turner producers to date ˃ TIL pace accelerating ˃ Infrastructure upgrades ˃ Testing spacing assumptions ˃ ~$25/bbl breakeven(1) (1) Breakeven assumes a flat $2.75/mcf gas curve and a discount rate of 10% July 26, 2018 – Update 7 300,000 250,000 200,000 150,000 100,000 50,000 0 0 50 150 150 200 GrossCumulativeProduction(boe) CHK Turner Industry Turner 1 1 1 3 1 9 8 16 0 5 10 15 20 Q1 2017 Q2 2017 Q3 2017 Q4 2017 Q1 2018 Q2 2018 Q3 2018E Q4 2018E Turner TILs Current Rig Location Turner Producing Well Planned TIL 2018 Future Well Turner
July 26, 2018 – Update 8 Reducing leverage o $2 – $3 billion of debt reduction o Ultimate goal of 2x debt/EBITDA Enhancing margins o Attacking all areas of cash costs o Funding our highest returning projects Achieving free cash flow neutrality o Improved year over year free cash flow due to reduced cash interest expense EHS excellence o Continued commitment to improving environmental and safety performance EXECUTING ON OUR STRATEGY

More Related Content

Utica Shale Divestiture and PRB Update

  • 1. UTICA SHALE DIVESTITURE AND POWDER RIVER BASIN UPDATE July 26, 2018
  • 2. FORWARD-LOOKING STATEMENTS This presentation includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements are statements other than statements of historical fact. They include statements that give our current expectations, management's outlook guidance or forecasts of future events, production and well connection forecasts, effects and results of the Utica divestiture, estimates of operating costs, anticipated capital and operational efficiencies, planned development drilling and expected drilling cost reductions, anticipated timing of wells to be placed into production, general and administrative expenses, capital expenditures, the timing of anticipated asset sales and proceeds to be received therefrom, the expected use of proceeds of anticipated asset sales, projected cash flow and liquidity, our ability to enhance our cash flow and financial flexibility, plans and objectives for future operations, the ability of our employees, portfolio strength and operational leadership to create long-term value, and the assumptions on which such statements are based. Although we believe the expectations and forecasts reflected in the forward- looking statements are reasonable, we can give no assurance they will prove to have been correct. They can be affected by inaccurate or changed assumptions or by known or unknown risks and uncertainties. Factors that could cause actual results to differ materially from expected results include those described under “Risk Factors” in Item 1A of our annual report on Form 10-K and any updates to those factors set forth in Chesapeake’s subsequent quarterly reports on Form 10-Q or current reports on Form 8-K (available at http://www.chk.com/investors/sec- filings). These risk factors include, satisfaction of closing conditions, actions by the buyer, the volatility of oil, natural gas and NGL prices; the limitations our level of indebtedness may have on our financial flexibility; our inability to access the capital markets on favorable terms; the availability of cash flows from operations and other funds to finance reserve replacement costs or satisfy our debt obligations; downgrade in our credit rating requiring us to post more collateral under certain commercial arrangements; write-downs of our oil and natural gas asset carrying values due to low commodity prices; our ability to replace reserves and sustain production; uncertainties inherent in estimating quantities of oil, natural gas and NGL reserves and projecting future rates of production and the amount and timing of development expenditures; our ability to generate profits or achieve targeted results in drilling and well operations; leasehold terms expiring before production can be established; commodity derivative activities resulting in lower prices realized on oil, natural gas and NGL sales; the need to secure derivative liabilities and the inability of counterparties to satisfy their obligations; adverse developments or losses from pending or future litigation and regulatory proceedings, including royalty claims; charges incurred in response to market conditions and in connection with our ongoing actions to reduce financial leverage and complexity; drilling and operating risks and resulting liabilities; effects of environmental protection laws and regulation on our business; legislative and regulatory initiatives further regulating hydraulic fracturing; our need to secure adequate supplies of water for our drilling operations and to dispose of or recycle the water used; impacts of potential legislative and regulatory actions addressing climate change; federal and state tax proposals affecting our industry; potential OTC derivatives regulation limiting our ability to hedge against commodity price fluctuations; competition in the oil and gas exploration and production industry; a deterioration in general economic, business or industry conditions; negative public perceptions of our industry; limited control over properties we do not operate; pipeline and gathering system capacity constraints and transportation interruptions; terrorist activities and cyber-attacks adversely impacting our operations; an interruption in operations at our headquarters due to a catastrophic event; certain anti-takeover provisions that affect shareholder rights; and our inability to increase or maintain our liquidity through debt repurchases, capital exchanges, asset sales, joint ventures, farmouts or other means. In addition, disclosures concerning the estimated contribution of derivative contracts to our future results of operations are based upon market information as of a specific date. These market prices are subject to significant volatility. Our production forecasts are also dependent upon many assumptions, including estimates of production decline rates from existing wells and the outcome of future drilling activity. Expected asset sales may not be completed in the time frame anticipated or at all. We caution you not to place undue reliance on our forward-looking statements, which speak only as of the date of this presentation, and we undertake no obligation to update any of the information provided in this presentation, except as required by applicable law. In addition, this presentation contains time-sensitive information that reflects management's best judgment only as of the date of this presentation. We use certain terms in this presentation such as “Resource Potential,” “Net Reserves” and similar terms that the SEC’s guidelines strictly prohibit us from including in filings with the SEC. These terms include reserves with substantially less certainty, and no discount or other adjustment is included in the presentation of such reserve numbers. U.S. investors are urged to consider closely the disclosure in our Form 10-K for the year ended December 31, 2017, File No. 1-13726 and in our other filings with the SEC, available from us at 6100 North Western Avenue, Oklahoma City, Oklahoma 73118. These forms can also be obtained from the SEC by calling 1-800-SEC-0330. 2July 26, 2018 – Update
  • 3. UNLOCKING OUR FUTURE UTICA SHALE DIVESTITURE (1) Assumes flat 2018 commodity prices and basis differentials (2) Estimated at 1/1/2019 July 26, 2018 – Update 3
  • 4. UTICA DIVESTMENT OVERVIEW July 26, 2018 – Update 4 (1) For calendar year 2017 (2) At 12/31/2017 Buyer Encino Acquisition Partners Purchase price $2.0 billion Net proceeds for debt $1.9 billion Potential commodity price adjustment (expires 12/31/2019) $100 million Net core acres 320,000 Well count (operated and non-operated) 920 Net production(1) 107,000 boe/d Gas / NGL / Oil 67% / 24% / 9% YE2017 Reserves(2) 480 mmboe Future midstream and downstream commitments (assumed by buyer) $2.4 billion 2017 EBITDA $455 million 2017 Capex $471 million CHK UTICA ACREAGE POSITION OHIO CHK Core Leasehold CHK Non-Core Leasehold ASSETSTATSDEAL
  • 5. TRANSFORMING INTO A MORE COMPETITIVE COMPANY(1) July 26, 2018 – Update 5 (1) Gives effect to Utica Shale divestiture (2) Production expense, G&A and stock-based compensation
  • 6. 0 10 20 30 40 50 60 70 80 Q1 2017 Q2 2017 Q3 2017 Q4 2017 Q1 2018 Q2 2018 Q3 2018 Q4 2018 Q1 2019 Q2 2019 Q3 2019 Q4 2019 NetProduction(mboe/d) Liquids Gas Analyst Day 2016 POWDER RIVER BASIN PRODUCTION GROWING RAPIDLY ~90% OIL GROWTH YTD, ~100% EXPECTED IN 2019 (1) July 26, 2018 – Update 6 (1) Projected annual growth in 2019 compared to 2018 projected annual volumes (2) As of 7/24/2018, net volume (3) Forecast presented at Analyst Day 2016 1 – 3 Rigs 4 – 5 Rigs 32 mboe/d Current field rate (2)
  • 7. TURNER LEADING THE WAY THE PREMIER PRB OPPORTUNITY • Progress to date ˃ De-risking acreage ˃ 18 Turner producers to date ˃ TIL pace accelerating ˃ Infrastructure upgrades ˃ Testing spacing assumptions ˃ ~$25/bbl breakeven(1) (1) Breakeven assumes a flat $2.75/mcf gas curve and a discount rate of 10% July 26, 2018 – Update 7 300,000 250,000 200,000 150,000 100,000 50,000 0 0 50 150 150 200 GrossCumulativeProduction(boe) CHK Turner Industry Turner 1 1 1 3 1 9 8 16 0 5 10 15 20 Q1 2017 Q2 2017 Q3 2017 Q4 2017 Q1 2018 Q2 2018 Q3 2018E Q4 2018E Turner TILs Current Rig Location Turner Producing Well Planned TIL 2018 Future Well Turner
  • 8. July 26, 2018 – Update 8 Reducing leverage o $2 – $3 billion of debt reduction o Ultimate goal of 2x debt/EBITDA Enhancing margins o Attacking all areas of cash costs o Funding our highest returning projects Achieving free cash flow neutrality o Improved year over year free cash flow due to reduced cash interest expense EHS excellence o Continued commitment to improving environmental and safety performance EXECUTING ON OUR STRATEGY

Editor's Notes

  1. 10% discount rate and a $2.75