Chesapeake Energy is focused on generating sustainable free cash flow through disciplined capital reinvestment and cost reductions. It has a diverse portfolio of natural gas and oil assets across multiple basins in the U.S. and is committed to industry-leading ESG performance including achieving net-zero direct greenhouse gas emissions by 2035. Through restructuring, Chesapeake has significantly improved its balance sheet, reducing debt and gaining flexibility. It has also renegotiated midstream contracts to lower annual costs by over $2 billion on a present value basis including an estimated $281 million reduction in 2021.
Chesapeake Energy is focused on generating sustainable free cash flow from a diverse, low-cost asset base while maintaining a strong balance sheet and leading ESG performance. The company plans to reinvest 60-70% of capital to produce over 400 MBoe/d and $2B in free cash flow over five years. Chesapeake also aims to achieve net-zero direct GHG emissions by 2035 by eliminating routine flaring and reducing methane and GHG intensities. This disciplined strategy targets a 30-40% free cash flow yield and debt leverage below 1x to enhance shareholder returns.
Chesapeake Energy is focused on generating sustainable free cash flow from a diverse, low-cost asset base while maintaining a strong balance sheet and leading ESG performance. The company plans to reinvest 60-70% of capital to produce over 400 MBoe/d and $2B in free cash flow over five years. Chesapeake also aims to achieve net-zero direct GHG emissions by 2035 by eliminating routine flaring and reducing methane and GHG intensities. This disciplined strategy targets a leverage ratio under 1x and 30-40% of EBITDAX as sustainable free cash flow yield.
The document provides an earnings summary for 1Q 2021. Key points include:
- The company has a strong balance sheet with low leverage of 0.6x net debt to EBITDA for 2021 and is focused on generating sustainable free cash flow.
- In 1Q 2021, the company reported $510 million in adjusted EBITDAX and $329 million in free cash flow.
- The company aims to reinvest 60-70% of capital to maintain production of 400+ MBOE/day while returning cash to shareholders through an initial $1.375 per share annual dividend.
- Operating costs were reduced significantly in 1Q 2021 compared to 1Q 2020 through cost restructuring.
The document provides an earnings summary for 1Q 2021. Key points include:
- The company has a strong balance sheet with low leverage of 0.6x net debt to EBITDA for 2021 and is focused on generating sustainable free cash flow.
- In 1Q 2021, the company reported $510 million in adjusted EBITDAX and $329 million in free cash flow.
- The company aims to reinvest 60-70% of capital to maintain production of over 400 MBOE/day on $700-750 million in annual capital expenditures.
- The portfolio includes high-quality assets in Appalachia, the Gulf Coast, and South Texas that provide diversification and opportunity for continued development
Chesapeake Energy is committed to generating sustainable free cash flow from a strong balance sheet and diverse low-cost asset base, while achieving top ESG performance. The company aims to preserve its balance sheet strength with less than 1x long-term leverage. It expects to reinvest 60-70% of annual capital expenditures of $700-750 million to produce over 400 thousand barrels of oil equivalent per day and achieve a 30-40% free cash flow yield. Chesapeake also targets net zero direct greenhouse gas emissions by 2035 by eliminating routine flaring and reducing methane and GHG intensities to lead the industry in ESG excellence and safety.
Chesapeake Energy has achieved several milestones in its Chapter 11 bankruptcy process and is on track to emerge from bankruptcy in February 2021 with a significantly deleveraged balance sheet. Upon emergence, Chesapeake will have a diverse, low-cost asset base, strong liquidity, and a disciplined capital allocation plan focused on generating sustainable free cash flow. Chesapeake has also negotiated over $4 billion in savings to its marketing contracts which will enhance its cash flows going forward.
This document provides an investor presentation for SemGroup's second quarter 2017 results. It discusses SemGroup's non-GAAP financial measure of Adjusted EBITDA, noting that it excludes certain items to increase comparability between reporting periods. It also contains forward-looking statements regarding SemGroup's prospects, financial performance, annual dividend growth, and other matters. Finally, it outlines SemGroup's strategy of transforming into a diversified energy infrastructure company through acquisitions in the Gulf Coast, STACK play, and Duvernay/Montney regions to generate stable cash flows under contracts with investment-grade counterparties.
- EnLink Midstream reported financial and operational results for the second quarter of 2017, delivering earnings and volume growth. Adjusted EBITDA was $209.7 million, up from $207.6 million in the previous quarter.
- Volume growth across their assets in key basins like the Permian Basin, Central Oklahoma and Louisiana was driven by ongoing drilling and completion activity from producers like Devon Energy.
- Rigs counts have remained consistent in EnLink's core basins, and existing well inventory is expected to support volume growth through 2017 to meet guidance targets.
Chesapeake Energy is focused on generating sustainable free cash flow from a diverse, low-cost asset base while maintaining a strong balance sheet and leading ESG performance. The company plans to reinvest 60-70% of capital to produce over 400 MBoe/d and $2B in free cash flow over five years. Chesapeake also aims to achieve net-zero direct GHG emissions by 2035 by eliminating routine flaring and reducing methane and GHG intensities. This disciplined strategy targets a 30-40% free cash flow yield and debt leverage below 1x to enhance shareholder returns.
Chesapeake Energy is focused on generating sustainable free cash flow from a diverse, low-cost asset base while maintaining a strong balance sheet and leading ESG performance. The company plans to reinvest 60-70% of capital to produce over 400 MBoe/d and $2B in free cash flow over five years. Chesapeake also aims to achieve net-zero direct GHG emissions by 2035 by eliminating routine flaring and reducing methane and GHG intensities. This disciplined strategy targets a leverage ratio under 1x and 30-40% of EBITDAX as sustainable free cash flow yield.
The document provides an earnings summary for 1Q 2021. Key points include:
- The company has a strong balance sheet with low leverage of 0.6x net debt to EBITDA for 2021 and is focused on generating sustainable free cash flow.
- In 1Q 2021, the company reported $510 million in adjusted EBITDAX and $329 million in free cash flow.
- The company aims to reinvest 60-70% of capital to maintain production of 400+ MBOE/day while returning cash to shareholders through an initial $1.375 per share annual dividend.
- Operating costs were reduced significantly in 1Q 2021 compared to 1Q 2020 through cost restructuring.
The document provides an earnings summary for 1Q 2021. Key points include:
- The company has a strong balance sheet with low leverage of 0.6x net debt to EBITDA for 2021 and is focused on generating sustainable free cash flow.
- In 1Q 2021, the company reported $510 million in adjusted EBITDAX and $329 million in free cash flow.
- The company aims to reinvest 60-70% of capital to maintain production of over 400 MBOE/day on $700-750 million in annual capital expenditures.
- The portfolio includes high-quality assets in Appalachia, the Gulf Coast, and South Texas that provide diversification and opportunity for continued development
Chesapeake Energy is committed to generating sustainable free cash flow from a strong balance sheet and diverse low-cost asset base, while achieving top ESG performance. The company aims to preserve its balance sheet strength with less than 1x long-term leverage. It expects to reinvest 60-70% of annual capital expenditures of $700-750 million to produce over 400 thousand barrels of oil equivalent per day and achieve a 30-40% free cash flow yield. Chesapeake also targets net zero direct greenhouse gas emissions by 2035 by eliminating routine flaring and reducing methane and GHG intensities to lead the industry in ESG excellence and safety.
Chesapeake Energy has achieved several milestones in its Chapter 11 bankruptcy process and is on track to emerge from bankruptcy in February 2021 with a significantly deleveraged balance sheet. Upon emergence, Chesapeake will have a diverse, low-cost asset base, strong liquidity, and a disciplined capital allocation plan focused on generating sustainable free cash flow. Chesapeake has also negotiated over $4 billion in savings to its marketing contracts which will enhance its cash flows going forward.
This document provides an investor presentation for SemGroup's second quarter 2017 results. It discusses SemGroup's non-GAAP financial measure of Adjusted EBITDA, noting that it excludes certain items to increase comparability between reporting periods. It also contains forward-looking statements regarding SemGroup's prospects, financial performance, annual dividend growth, and other matters. Finally, it outlines SemGroup's strategy of transforming into a diversified energy infrastructure company through acquisitions in the Gulf Coast, STACK play, and Duvernay/Montney regions to generate stable cash flows under contracts with investment-grade counterparties.
- EnLink Midstream reported financial and operational results for the second quarter of 2017, delivering earnings and volume growth. Adjusted EBITDA was $209.7 million, up from $207.6 million in the previous quarter.
- Volume growth across their assets in key basins like the Permian Basin, Central Oklahoma and Louisiana was driven by ongoing drilling and completion activity from producers like Devon Energy.
- Rigs counts have remained consistent in EnLink's core basins, and existing well inventory is expected to support volume growth through 2017 to meet guidance targets.
This document provides an overview of Crestwood Midstream Partners LP and Crestwood Equity Partners LP. It highlights key investor information including recent financial results, growth projects, and commercial contracts. The document summarizes recent execution on projects in various regions, and outlines a backlog of announced growth projects through 2018 that are expected to generate over $30 million in incremental annual cash flow. These projects focus on the Bakken, Delaware Basin, and Marcellus regions.
Sem group announces hfotco acquisition final presentationSemGroupCorporation
SemGroup acquired Houston Fuel Oil Terminal Company (HFOTCO) for $1.5 billion initially, with a second $600 million payment due by end of 2018. HFOTCO owns 330 acres and 16.8 million barrels of storage on the Houston Ship Channel with connections to major pipelines and refineries. The acquisition enhances SemGroup's scale and diversification with take-or-pay contracts from investment-grade customers. Growth projects are expected to increase HFOTCO's adjusted EBITDA to $180-190 million by 2019.
- The document provides EnLink Midstream's 3rd quarter 2017 operations report, which summarizes financial and operational results and reaffirms guidance.
- EnLink reported adjusted EBITDA at the high end of guidance for 3Q17, driven by strong volume growth. Organic projects are expected to generate significant cash flow going forward.
- Volumes on gas gathering and processing systems grew substantially in key areas like the Permian Basin and Louisiana year-over-year and quarter-over-quarter.
The document provides cautionary statements regarding forward-looking statements in the presentation. It notes that actual results can differ materially from expectations due to risks and uncertainties described in Chesapeake's SEC filings. It also defines terms used in the presentation like PV10, estimated ultimate recovery, and resource potential that are more speculative than proved reserves. The SEC prohibits including these estimates in filings.
The document provides details on Curtiss-Wright's 1Q 2018 earnings conference call, including financial results, business outlook, and guidance. Key points:
- 1Q 2018 diluted EPS increased 35% to $0.98 due to higher sales and profitability in commercial/industrial and defense segments.
- Net sales grew 5% overall with strong demand in aerospace and naval defense. Operating margin expanded 270 basis points to 11.8%.
- Full-year 2018 guidance was raised, expecting higher sales, operating income, margins and EPS, driven by improved outlook across all end markets. However, the Dresser-Rand acquisition reduces some metrics due to first-year purchase accounting costs.
This document provides an overview of Crestwood Midstream Partners LP and Crestwood Equity Partners LP. It discusses the company's 2016 outlook, key investor highlights, cost cutting measures, capital structure, core operations in the Bakken shale play, and its COLT Hub facility. The presentation aims to position Crestwood favorably in the current challenging energy market environment through stable cash flow, high contract coverage, expense reductions, and operations in top producing regions.
This document provides an overview of Crestwood Midstream Partners LP and Crestwood Equity Partners LP. It highlights their simplified structure following a merger, fixed-fee contract portfolio that provides revenue stability, cost reduction efforts, and core operations in strategic basins like the Marcellus and Bakken shale plays. The presentation outlines financial results, liquidity position, and growth opportunities while noting the companies' valuation disconnect compared to peers.
Denbury Resources presented at the Capital One Securities 12th Annual Energy Conference on December 6, 2017. Denbury has 254 million barrels of proved oil reserves and an estimated 900 million barrels of proved plus potential reserves recoverable through CO2 enhanced oil recovery. The company has a large CO2 supply and pipeline network across the Gulf Coast and Rocky Mountain regions. Denbury is focused on reducing costs by over $50 million in 2018, unlocking value from its asset base, and improving its balance sheet position through debt reduction and potential asset sales.
This document contains an investor presentation for Crestwood Midstream Partners LP and Crestwood Equity Partners LP. The presentation highlights the companies' diversified portfolio of midstream assets across major US basins, including the Bakken, Delaware Basin, PRB Niobrara, and Marcellus. Over 85% of forecasted 2017 EBITDA is supported by take-or-pay or fixed-fee contracts with investment grade customers. The presentation outlines Crestwood's organic growth strategy through 2018-2021 focused on high-return expansion projects around its core assets to drive distributable cash flow per unit growth.
Phillips 66 reported adjusted earnings of $569 million for the second quarter of 2017. Operating cash flow was $1.865 billion for the quarter. Midstream earnings decreased due to planned maintenance and the startup of the Bakken Pipeline. Refining earnings fell as realized margins declined compared to markets. Marketing and Specialties earnings rose on stronger global margins and higher volumes.
Celp investor presentation march 2017 finalCypressEnergy
Cypress Energy Partners provides pipeline inspection and integrity services as well as water and environmental services to midstream energy customers. Over 85% of its customers are investment grade companies. It inspects over 46,000 miles of pipelines annually using in-line inspection tools to identify anomalies, and performs over 12,000 excavations for further inspection or maintenance. Regulations require pipeline operators to inspect lines every 5-7 years, providing a recurring need for Cypress' inspection services over the 40-60 year lifespan of pipelines.
CONSOL Energy & Noble Energy Marcellus Shale Joint Venture SeparationMarcellus Drilling News
Presentation used during a conference call to announced that CONSOL Energy and Noble Energy's 669,000-acre joint venture in the Marcellus Shale is ending. CONSOL will retain rights to 306,000 acres (mostly in Pennsylvania) and Noble rights to 363,000 acres (mostly in West Virginia). The separation will allow CONSOL to do more Utica drilling. Noble plans to do less drilling, for now, in the Marcellus.
- Denbury Resources reported a net loss of $386 million for Q4 2016 and $976 million for the full year, primarily due to non-cash fair value adjustments and asset write-downs. However, when excluding these non-cash items, Denbury's adjusted net loss was only $7 million for Q4 2016 and adjusted net income was $14 million for the full year.
- For 2017, Denbury expects production to remain relatively flat at 60,000-62,000 barrels of oil equivalent per day, with a capital budget of $300 million focused on expanding existing CO2 flood projects and other infill opportunities.
- The company will prioritize stabilizing production, improving its balance sheet by reducing
Vulcan Materials reported first quarter 2013 earnings results. Key highlights included aggregates shipments and pricing in line with expectations, and improved profitability in non-aggregates segments. The outlook for 2013 anticipates continued recovery in private construction leading to 1-5% growth in aggregates volumes and 4% increase in aggregates pricing. Earnings improvement is expected across all business segments.
American Midstream Partners LP will merge with JP Energy Partners LP to form a larger diversified midstream company with a combined enterprise value of approximately $2 billion. The transaction will be executed through a unit-for-unit exchange where AMID will issue new units to JPEP unitholders at a 0.5775 exchange ratio. The merger is expected to deliver synergies of at least $10 million annually and provide benefits like increased scale, financial strength, and growth opportunities for the combined company. The transaction is anticipated to close in late 2016 or early 2017 pending required approvals.
Teck’s Q2 2019 Financial Results and Investors’ Conference CallTeckResourcesLtd
Teck released its second quarter 2019 earnings results on Thursday, July 25, 2019 before market open.
The company will hold an investor conference call to discuss the second quarter 2019 earnings results at 11:00 a.m. Eastern time / 8:00 a.m. Pacific time on Thursday, July 25, 2019. The conference call dial-in is 416.204.1547 or toll free 866.215.0058, no pass code required. Media are invited to attend on a listen-only basis.
The document discusses Morgan Stanley's MLP Bus Tour and provides an overview of EnLink Midstream. It notes that EnLink has stable cash flows from long-term fee-based contracts, including a significant portion from its sponsor Devon Energy. It is focused on executing in its core areas of Oklahoma, Permian Basin, and Louisiana. EnLink has a strong financial position as an investment grade company with a $1.5 billion credit facility and high-quality customers.
The document provides an earnings summary for 1Q 2021. Key points include:
- The company has a strong balance sheet with low leverage of 0.6x net debt to 2021 EBITDAX and projects $3 billion in free cash flow over the next five years.
- In 1Q 2021, the company reported adjusted EBITDAX of $510 million and free cash flow of $329 million.
- The company aims to reinvest 60-70% of capital to produce over 400 MBOE/day annually on $700-750 million in capital expenditures and launch an initial $1.375 per share annual dividend.
- The company has a diversified portfolio across multiple basins including Appal
This presentation contains forward-looking statements regarding the company's strategies, operations, development plans, production estimates, costs, reserves, hedging programs, and other factors. These statements are subject to risks and uncertainties outside the company's control. The company bases its forward-looking statements on current expectations and analyses but actual results may differ materially from expectations. All forward-looking statements are qualified by these risk factors. Estimates of unproved reserves referred to as "EUR" are prohibited in SEC filings due to greater risk of not being realized. For proved reserves calculated under SEC rules, see the company's 10-K filing.
This document provides an overview of Crestwood Midstream Partners LP and Crestwood Equity Partners LP. It highlights key investor information including recent financial results, growth projects, and commercial contracts. The document summarizes recent execution on projects in various regions, and outlines a backlog of announced growth projects through 2018 that are expected to generate over $30 million in incremental annual cash flow. These projects focus on the Bakken, Delaware Basin, and Marcellus regions.
Sem group announces hfotco acquisition final presentationSemGroupCorporation
SemGroup acquired Houston Fuel Oil Terminal Company (HFOTCO) for $1.5 billion initially, with a second $600 million payment due by end of 2018. HFOTCO owns 330 acres and 16.8 million barrels of storage on the Houston Ship Channel with connections to major pipelines and refineries. The acquisition enhances SemGroup's scale and diversification with take-or-pay contracts from investment-grade customers. Growth projects are expected to increase HFOTCO's adjusted EBITDA to $180-190 million by 2019.
- The document provides EnLink Midstream's 3rd quarter 2017 operations report, which summarizes financial and operational results and reaffirms guidance.
- EnLink reported adjusted EBITDA at the high end of guidance for 3Q17, driven by strong volume growth. Organic projects are expected to generate significant cash flow going forward.
- Volumes on gas gathering and processing systems grew substantially in key areas like the Permian Basin and Louisiana year-over-year and quarter-over-quarter.
The document provides cautionary statements regarding forward-looking statements in the presentation. It notes that actual results can differ materially from expectations due to risks and uncertainties described in Chesapeake's SEC filings. It also defines terms used in the presentation like PV10, estimated ultimate recovery, and resource potential that are more speculative than proved reserves. The SEC prohibits including these estimates in filings.
The document provides details on Curtiss-Wright's 1Q 2018 earnings conference call, including financial results, business outlook, and guidance. Key points:
- 1Q 2018 diluted EPS increased 35% to $0.98 due to higher sales and profitability in commercial/industrial and defense segments.
- Net sales grew 5% overall with strong demand in aerospace and naval defense. Operating margin expanded 270 basis points to 11.8%.
- Full-year 2018 guidance was raised, expecting higher sales, operating income, margins and EPS, driven by improved outlook across all end markets. However, the Dresser-Rand acquisition reduces some metrics due to first-year purchase accounting costs.
This document provides an overview of Crestwood Midstream Partners LP and Crestwood Equity Partners LP. It discusses the company's 2016 outlook, key investor highlights, cost cutting measures, capital structure, core operations in the Bakken shale play, and its COLT Hub facility. The presentation aims to position Crestwood favorably in the current challenging energy market environment through stable cash flow, high contract coverage, expense reductions, and operations in top producing regions.
This document provides an overview of Crestwood Midstream Partners LP and Crestwood Equity Partners LP. It highlights their simplified structure following a merger, fixed-fee contract portfolio that provides revenue stability, cost reduction efforts, and core operations in strategic basins like the Marcellus and Bakken shale plays. The presentation outlines financial results, liquidity position, and growth opportunities while noting the companies' valuation disconnect compared to peers.
Denbury Resources presented at the Capital One Securities 12th Annual Energy Conference on December 6, 2017. Denbury has 254 million barrels of proved oil reserves and an estimated 900 million barrels of proved plus potential reserves recoverable through CO2 enhanced oil recovery. The company has a large CO2 supply and pipeline network across the Gulf Coast and Rocky Mountain regions. Denbury is focused on reducing costs by over $50 million in 2018, unlocking value from its asset base, and improving its balance sheet position through debt reduction and potential asset sales.
This document contains an investor presentation for Crestwood Midstream Partners LP and Crestwood Equity Partners LP. The presentation highlights the companies' diversified portfolio of midstream assets across major US basins, including the Bakken, Delaware Basin, PRB Niobrara, and Marcellus. Over 85% of forecasted 2017 EBITDA is supported by take-or-pay or fixed-fee contracts with investment grade customers. The presentation outlines Crestwood's organic growth strategy through 2018-2021 focused on high-return expansion projects around its core assets to drive distributable cash flow per unit growth.
Phillips 66 reported adjusted earnings of $569 million for the second quarter of 2017. Operating cash flow was $1.865 billion for the quarter. Midstream earnings decreased due to planned maintenance and the startup of the Bakken Pipeline. Refining earnings fell as realized margins declined compared to markets. Marketing and Specialties earnings rose on stronger global margins and higher volumes.
Celp investor presentation march 2017 finalCypressEnergy
Cypress Energy Partners provides pipeline inspection and integrity services as well as water and environmental services to midstream energy customers. Over 85% of its customers are investment grade companies. It inspects over 46,000 miles of pipelines annually using in-line inspection tools to identify anomalies, and performs over 12,000 excavations for further inspection or maintenance. Regulations require pipeline operators to inspect lines every 5-7 years, providing a recurring need for Cypress' inspection services over the 40-60 year lifespan of pipelines.
CONSOL Energy & Noble Energy Marcellus Shale Joint Venture SeparationMarcellus Drilling News
Presentation used during a conference call to announced that CONSOL Energy and Noble Energy's 669,000-acre joint venture in the Marcellus Shale is ending. CONSOL will retain rights to 306,000 acres (mostly in Pennsylvania) and Noble rights to 363,000 acres (mostly in West Virginia). The separation will allow CONSOL to do more Utica drilling. Noble plans to do less drilling, for now, in the Marcellus.
- Denbury Resources reported a net loss of $386 million for Q4 2016 and $976 million for the full year, primarily due to non-cash fair value adjustments and asset write-downs. However, when excluding these non-cash items, Denbury's adjusted net loss was only $7 million for Q4 2016 and adjusted net income was $14 million for the full year.
- For 2017, Denbury expects production to remain relatively flat at 60,000-62,000 barrels of oil equivalent per day, with a capital budget of $300 million focused on expanding existing CO2 flood projects and other infill opportunities.
- The company will prioritize stabilizing production, improving its balance sheet by reducing
Vulcan Materials reported first quarter 2013 earnings results. Key highlights included aggregates shipments and pricing in line with expectations, and improved profitability in non-aggregates segments. The outlook for 2013 anticipates continued recovery in private construction leading to 1-5% growth in aggregates volumes and 4% increase in aggregates pricing. Earnings improvement is expected across all business segments.
American Midstream Partners LP will merge with JP Energy Partners LP to form a larger diversified midstream company with a combined enterprise value of approximately $2 billion. The transaction will be executed through a unit-for-unit exchange where AMID will issue new units to JPEP unitholders at a 0.5775 exchange ratio. The merger is expected to deliver synergies of at least $10 million annually and provide benefits like increased scale, financial strength, and growth opportunities for the combined company. The transaction is anticipated to close in late 2016 or early 2017 pending required approvals.
Teck’s Q2 2019 Financial Results and Investors’ Conference CallTeckResourcesLtd
Teck released its second quarter 2019 earnings results on Thursday, July 25, 2019 before market open.
The company will hold an investor conference call to discuss the second quarter 2019 earnings results at 11:00 a.m. Eastern time / 8:00 a.m. Pacific time on Thursday, July 25, 2019. The conference call dial-in is 416.204.1547 or toll free 866.215.0058, no pass code required. Media are invited to attend on a listen-only basis.
The document discusses Morgan Stanley's MLP Bus Tour and provides an overview of EnLink Midstream. It notes that EnLink has stable cash flows from long-term fee-based contracts, including a significant portion from its sponsor Devon Energy. It is focused on executing in its core areas of Oklahoma, Permian Basin, and Louisiana. EnLink has a strong financial position as an investment grade company with a $1.5 billion credit facility and high-quality customers.
The document provides an earnings summary for 1Q 2021. Key points include:
- The company has a strong balance sheet with low leverage of 0.6x net debt to 2021 EBITDAX and projects $3 billion in free cash flow over the next five years.
- In 1Q 2021, the company reported adjusted EBITDAX of $510 million and free cash flow of $329 million.
- The company aims to reinvest 60-70% of capital to produce over 400 MBOE/day annually on $700-750 million in capital expenditures and launch an initial $1.375 per share annual dividend.
- The company has a diversified portfolio across multiple basins including Appal
This presentation contains forward-looking statements regarding the company's strategies, operations, development plans, production estimates, costs, reserves, hedging programs, and other factors. These statements are subject to risks and uncertainties outside the company's control. The company bases its forward-looking statements on current expectations and analyses but actual results may differ materially from expectations. All forward-looking statements are qualified by these risk factors. Estimates of unproved reserves referred to as "EUR" are prohibited in SEC filings due to greater risk of not being realized. For proved reserves calculated under SEC rules, see the company's 10-K filing.
This presentation contains forward-looking statements regarding the company's strategies, operations, development plans, production estimates, costs, reserves, hedging programs, and other factors. These statements are subject to risks and uncertainties outside the company's control. The company bases its forward-looking statements on current expectations and analyses but actual results may differ materially from expectations. All forward-looking statements are qualified by these risk factors. Estimates of unproved reserves referred to as "EUR" are prohibited in SEC filings due to greater risk of not being realized. For proved reserves calculated under SEC rules, see the company's 10-K filing.
This presentation contains forward-looking statements regarding the company's strategies, operations, development plans, production estimates, costs, reserves, hedging programs, and other factors. These statements are subject to risks and uncertainties outside the company's control. The company bases its forward-looking statements on current expectations and analyses but actual results may differ materially from expectations. All forward-looking statements are qualified by these risk factors. Estimates of unproved reserves referred to as "EUR" are prohibited in SEC filings due to greater risk of not being realized. For proved reserves calculated under SEC rules, see the company's 10-K filing.
bp reported strong third quarter 2021 results with underlying replacement cost profit of $5.9 billion, up from $4.7 billion in the previous quarter. Operating cash flow was $6 billion including a $1.8 billion working capital build. bp executed a $1.25 billion share buyback from first half surplus cash flow and announced an additional buyback. The results were driven by higher oil and gas prices and strong performances across all segments.
This presentation contains forward-looking statements regarding the company's strategies, operations, development plans, production estimates, costs, reserves, hedging program, and infrastructure investments. Actual results may differ materially from projections due to risks including commodity price volatility, reserve estimation uncertainties, development costs, counterparty performance, credit market conditions, regulatory changes, and other factors beyond the company's control. All forward-looking statements are qualified by these risk factors.
This presentation contains forward-looking statements regarding the company's strategies, operations, development plans, production estimates, costs, reserves, hedging program, and infrastructure investments. Actual results may differ materially from projections due to risks including commodity price volatility, reserve estimation uncertainties, development costs, counterparty performance, credit market conditions, regulatory changes, and other factors beyond the company's control. All forward-looking statements are qualified by these risk factors.
This presentation discusses forward-looking statements regarding the company's strategies, operations, development plans, production estimates, costs, capital expenditures, and other financial metrics. Actual results may differ materially from projections due to risks including commodity price volatility, reserve estimates, development costs, competition, and regulatory changes. All forward-looking statements are qualified by these risk factors.
The document is the 2019 Annual Meeting of Shareholders presentation. It summarizes Chesapeake Energy's business strategy, near-term priorities, and key performance metrics. The strategy is to focus on financial discipline, profitable and efficient growth from captured resources, exploration, business development, and margin enhancement to generate free cash flow and reduce net debt. Metrics shown include reductions in leverage, increases in adjusted EBITDAX and margins, improvements in production and overhead costs, and highlights of core asset positions and recent record well results.
The operations report discusses first quarter 2017 execution across EnLink's asset portfolio. Key highlights include expansion projects in Central Oklahoma bringing total processing capacity to nearly 1 Bcf/d by year-end. In the Delaware Basin, the Lobo system is expanding its capacity to 185 MMcf/d. The Ascension pipeline began operations in Louisiana. In the Midland Basin, the Chickadee crude oil gathering system became operational. Overall, EnLink continues focused execution across its integrated asset base.
bp reported strong financial results for 1Q 2021, achieving its $35 billion net debt target and commencing share buybacks. Key highlights included exceptional gas marketing performance, significantly higher oil prices, and higher refining margins compared to 4Q 2020. bp also made disciplined strategic progress across its businesses, including major project delivery and partnerships to advance its EV charging and renewable strategies.
The document provides an update on Chesapeake Energy Corporation for June 2019. It discusses forward-looking statements and risk factors that could impact actual results. The business strategy remains focused on financial discipline, profitable growth from captured resources, exploration and business development. Strategic goals include margin enhancement, free cash flow generation, and reducing net debt. In the first quarter of 2019, adjusted oil production increased 13% year-over-year while cash costs declined 14% resulting in the highest EBITDAX margin in four years. Brazos Valley is projected to be cash flow positive at the asset level in 2019.
LNG AS VIRTUAL PIPELINE FUEL FEED TO SAND MINE AND PROCESSING PLANTSiQHub
The document discusses Stabilis Solutions, an energy company that provides liquefied natural gas (LNG) and hydrogen solutions. It notes that the world is undergoing an energy transition from fossil fuels to cleaner sources like natural gas and hydrogen. Stabilis has recently acquired a new LNG production facility in Louisiana and delivered over 250 million gallons of LNG to customers across industries. The presentation also discusses Stabilis' role in frac sand drying and provides safety tips for operating in different weather conditions.
This presentation contains forward-looking statements regarding the company's strategies, operations, development plans, production estimates, reserve estimates, pricing, costs, and capital expenditures. These statements are qualified by risks and uncertainties around oil and gas prices, reserve estimates, development costs, regulatory changes, and other factors beyond the company's control. All forward-looking statements are qualified by these risk factors. The actual results may differ from projections. The SEC permits reporting of only proved, probable and possible reserves and the company uses other estimates like EUR which the SEC prohibits in filings.
This presentation contains forward-looking statements regarding the company's strategies, operations, development plans, production estimates, reserve estimates, pricing, costs, and capital expenditures. Actual results may differ materially from projections due to risks including commodity price volatility, reserve estimation uncertainties, development costs, access to capital, and regulatory changes. All forward-looking statements are qualified by these risk factors. The SEC limits oil and gas disclosures to proved, probable and possible reserves whereas the company may refer to unproved estimated ultimate recoveries, which are more speculative.
The document summarizes EnLink's operations report for August 2016. Key points include:
- EnLink revised 2016 guidance, increased adjusted EBITDA to $750-800 million.
- Q2 2016 results showed adjusted EBITDA of $187.4 million and cash available for distribution of $49.8 million.
- EnLink continues focus on core strategies of maximizing cash flows, executing growth projects, and providing best-in-basin service.
The document provides an operations report for August 3, 2016 that contains forward-looking statements and non-GAAP financial measures. It discusses key risks and uncertainties that could impact financial and operational results. It also contains disclaimers around the use of non-SEC compliant resource estimates and non-GAAP measures, urging investors to consider disclosures in SEC filings.
bp reported its fourth quarter and full year 2020 financial results. Key points include:
- Underlying replacement cost loss of $100 million for Q4 2020 and $5.7 billion for full year 2020.
- Net debt of $38.9 billion as of December 31, 2020, down from $51.4 billion a year earlier.
- Capital expenditure was reduced by around 40% in 2020 compared to 2019 and is expected to be around $13 billion in 2021.
- Cash costs were reduced by 12% in 2020 and further reductions are expected through 2023.
August 2016 corporate_presentation_final Eclipse resourcesSteve Wittrig
Eclipse Resources is an oil and gas company focused on developing its 115,000 net acres in the core of the Utica Shale and 13,000 net acres in the Marcellus Shale. The presentation highlights Eclipse's strong operational performance, including increasing lateral lengths by 200% while decreasing drilling costs by 50% per foot. Eclipse plans to resume drilling activities in mid-2016 and grow production over 30% year-over-year in 2017 through completing DUCs and operating a one-rig program. The company also discusses its super-lateral drilling program aimed to significantly improve well returns through extending lateral lengths.
Chesapeake Energy reported its 1Q 2019 earnings. It highlighted operational and financial strategies to enhance margins and generate free cash flow through profitable and efficient growth from captured resources. Key highlights included a 13% year-over-year increase in adjusted oil production, $15.50/boe EBITDAX margin which was the highest in four years, and the Brazos Valley asset projected to be cash flow positive at the asset level in 2019. Chesapeake is focusing investments in its highest-margin oil-growth assets and cash-generating gas assets to deliver transformational oil growth and improved cash flow.
Similar to February 9 2021 Investor Presentation (20)
Chesapeake Energy reported earnings for the fourth quarter of 2019. The presentation includes forward-looking statements and discusses key risks and uncertainties. It outlines Chesapeake's business strategy of financial discipline, profitable growth, and exploration. Key 2019 accomplishments included reducing capex by 30% year-over-year, reducing costs, growing oil production by 30%, and increasing adjusted EBITDAX. Priorities for 2020 include further reducing costs and targeting free cash flow. The presentation provides details on Chesapeake's asset portfolio and 2020 plans across its core regions.
Chesapeake Energy reported 3Q 2019 earnings. The presentation discusses the company's financial discipline and profitable growth strategy focused on capturing resources. Key highlights included establishing an oil production record in the Brazos Valley, improving well economics in the Powder River Basin, and the Marcellus asset generating an estimated $300 million in free cash flow. Chesapeake also summarized recent drilling results and operational improvements across its assets.
- Chesapeake Energy reported 2Q 2019 earnings and provided an operational and financial update.
- The company is executing on its strategy of financial discipline, profitable growth from captured resources, and exploration through focused investment in highest margin opportunities.
- Chesapeake has significantly improved its debt maturity outlook through refinancing activities and aims to achieve a net debt to EBITDAX ratio of 2x.
- The company is committed to safety, environmental stewardship, and reducing its environmental footprint through initiatives like its enhanced leak detection and repair program.
This document summarizes the effects of converting from the full cost accounting method to the successful efforts method. Some key points include:
- Exploration costs, impairments of unproved properties, geological and geophysical costs, and unsuccessful exploration wells will be expensed under successful efforts instead of capitalized. This results in a $12.4 billion decrease to retained earnings.
- Depletion and impairment expenses will generally be lower under successful efforts, resulting in a $10.8 billion increase to retained earnings. However, significant impairments could occur under successful efforts from writing down full cost capitalized amounts.
- Gains of $5 billion will be recognized from asset sales under successful efforts instead of the losses recognized under full
This document provides an earnings summary and overview of Chesapeake Energy Corporation's business strategies and accomplishments in 4Q 2018. It discusses the company's focus on financial discipline, profitable growth from captured resources, exploration, and business development. The company achieved margin enhancement in 2018 by generating its highest margins since 2014, optimizing its portfolio, and growing oil production. It also accelerated its transition to positive free cash flow. Chesapeake further reduced its long-term net debt to EBITDA ratio and maintained industry-leading safety performance. The document outlines the company's highest margin asset positions and investment plans across its diverse portfolio of basins for 2019.
The document provides an update on Chesapeake Energy's proposed acquisition of WildHorse Resource Development Corporation. It discusses how the acquisition will accelerate Chesapeake's strategic plan by increasing margins, cash flow generation, and oil production. The acquisition adds a significant Eagle Ford asset to Chesapeake's portfolio and is expected to improve the company's financial and operational metrics. Cost savings of $200-280 million annually from operational and capital efficiencies are estimated to total $1-1.5 billion over five years. The combined company will have a diversified portfolio of oil and gas assets across multiple basins with significant high-margin oil growth potential.
This document provides an update on the proposed acquisition of WildHorse Resource Development Corporation by Chesapeake Energy Corporation from December 2018. It outlines that the transaction value is $3.977 billion, with WildHorse shareholders receiving either Chesapeake stock or stock plus cash per WildHorse share. The acquisition is expected to accelerate Chesapeake's strategic plan by enhancing margins from high-value oil production, accelerating the transition to positive free cash flow, and accelerating debt reduction. The combined company will have a premier Eagle Ford asset base and increased production. Chesapeake shareholders will own 55% and WildHorse shareholders 45% of the combined company.
Doug Lawler discusses the transformation of Chesapeake Energy Corporation over the past several years. Chesapeake has simplified its business, reduced costs and debt, and optimized its portfolio. The acquisition of WildHorse Resource Development will accelerate Chesapeake's strategic plan by increasing margins, free cash flow, and profitability through high-value oil production. The combined company will be a premier diversified independent with significant high-margin oil growth opportunities.
1) Chesapeake Energy Corporation is acquiring WildHorse Resource Development Corporation to accelerate its strategic plan and transition to positive free cash flow.
2) The acquisition enhances Chesapeake's margins through WildHorse's high-value oil production and is expected to increase Chesapeake's oil production and percentage of oil.
3) The combined company will benefit from operational efficiencies projected to save $200-280 million annually, accelerating Chesapeake's deleveraging target of 2x net debt to EBITDA by 2020.
This document provides an update on Chesapeake Energy's proposed acquisition of WildHorse Resource Development Corporation. It discusses the benefits of the transaction, including increasing Chesapeake's oil production and margins. It also highlights opportunities to realize cost savings and capture additional marketing synergies through the combined Eagle Ford asset base. The acquisition accelerates Chesapeake's strategic plan to transition to positive free cash flow and improve its financial and operational profile.
1) Chesapeake Energy Corporation announced the acquisition of WildHorse Resource Development Corporation for total consideration of approximately $3.977 billion.
2) The acquisition accelerates Chesapeake's strategic plan by increasing oil production and margins from WildHorse's high-quality Eagle Ford assets.
3) The combination is expected to generate annual cost savings of $200-280 million per year and $1.0-1.5 billion in total savings over five years, improving Chesapeake's financial profile.
The document provides an update on Chesapeake Energy's business strategies and operations for September 2018. It discusses restoring the company's balance sheet through applying $1.9 billion in proceeds from an asset sale to debt reduction. It highlights the company's diverse portfolio across five basins and focuses on growth in the Powder River Basin, where production is ramping ahead of schedule led by the Turner opportunity. The company is improving drilling efficiencies to enhance returns in the Powder River Basin.
The document provides an August 2018 update on Chesapeake Energy Corporation's business strategies and operations. It discusses plans to use proceeds from an asset sale to reduce debt, goals of achieving a net debt to EBITDA ratio of 2x and free cash flow neutrality. Production from the Powder River Basin is growing rapidly and is expected to increase 90% in 2018 and 100% in 2019, driven largely by oil growth from the Turner area where 18 wells are currently producing. Drilling and completion costs in the Turner area have improved. The company has a diverse portfolio across five basins with an inventory of potential locations.
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
The document summarizes the 2018 annual meeting of Chesapeake Energy Corporation shareholders. It discusses Chesapeake's strategic goals of reducing debt by $2-3 billion to ultimately reach a net debt to EBITDA ratio of 2x, achieving free cash flow neutrality, enhancing margins through efficiency gains, and growing oil production while maintaining low costs. Chesapeake has transformed its business by reducing leverage, improving capital efficiency and environmental performance, and is on track to achieve free cash flow neutrality through continued financial discipline and high-returning projects from its portfolio of assets.
This document provides an overview of an energy conference presentation. It includes the following key points:
1) The presentation discusses strategic goals of reducing debt by $2-3 billion and achieving a net debt to EBITDA ratio of 2x. It also aims for free cash flow neutrality and margin enhancement.
2) Operational highlights from the first quarter of 2018 include a 16% increase in oil production and an 11% increase in total production compared to the same period last year.
3) The Powder River Basin is identified as a core asset with the potential to recover over 2.6 billion barrels of oil equivalent of resources from the Turner zone, where the company plans to increase drilling activity throughout 2018
Chesapeake Energy reported financial and operational results for Q1 2018. Net production increased 16% year-over-year to 527,000 boe/d. Adjusted EBITDA increased 11% year-over-year to $740 million. Cash costs increased 5% year-over-year to $6.25/boe. The company expects to continue improving well productivity in its Powder River Basin, South Texas, and Mid-Continent assets through drilling and completion optimizations.
UnityNet World Environment Day Abraham Project 2024 Press ReleaseLHelferty
June 12, 2024 UnityNet International (#UNI) World Environment Day Abraham Project 2024 Press Release from Markham / Mississauga, Ontario in the, Greater Tkaronto Bioregion, Canada in the North American Great Lakes Watersheds of North America (Turtle Island).
Cleades Robinson, a respected leader in Philadelphia's police force, is known for his diplomatic and tactful approach, fostering a strong community rapport.
World economy charts case study presented by a Big 4
World economy charts case study presented by a Big 4
World economy charts case
World economy charts case study presented by a Big 4
World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4
World economy charts case study presented by a Big 4
World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4World economy charts case study presented by a Big 4study presented by a Big 4
The E-Way Bill revolutionizes logistics by digitizing the documentation of goods transport, ensuring transparency, tax compliance, and streamlined processes. This mandatory, electronic system reduces delays, enhances accountability, and combats tax evasion, benefiting businesses and authorities alike. Embrace the E-Way Bill for efficient, reliable transportation operations.
Methanex is the world's largest producer and supplier of methanol. We create value through our leadership in the global production, marketing and delivery of methanol to customers. View our latest Investor Presentation for more details.
ZKsync airdrop of 3.6 billion ZK tokens is scheduled by ZKsync for next week.pdfSOFTTECHHUB
The world of blockchain and decentralized technologies is about to witness a groundbreaking event. ZKsync, the pioneering Ethereum Layer 2 network, has announced the highly anticipated airdrop of its native token, ZK. This move marks a significant milestone in the protocol's journey, empowering the community to take the reins and shape the future of this revolutionary ecosystem.
2. Disclaimers
FORWARD-LOOKING STATEMENTS
This document includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements other than statements
of historical fact are, or may be deemed to be, forward-looking statements. In some cases, forward-looking statements can be identified by the use of forward-looking terms such as “anticipate,” “estimate,” “believe,” “continue,” “could,”
“intend,” “may,” “plan,” “potential,” “predict,” “should,” “will,” “expect,” “objective,” “projection,” “forecast,” “goal,” “guidance,” “outlook,” “effort,” “target,” “trajectory” or the negative of these terms or other comparable terms. However, the
absence of these words does not mean that the statements are not forward-looking. These forward-looking statements are based on certain assumptions and analyses made by us in light of our experience and our perception of historical
trends, current conditions and expected future developments, as well as other factors we believe are appropriate in the circumstances. These forward-looking statements are subject to known and unknown risks, uncertainties and
assumptions that may cause actual results, levels of activity, performance or achievements to be materially different from any future results, levels of activity, performance or achievements expressed or implied by such forward-looking
statements. Factors that might cause or contribute to a material difference include the risks discussed in our filings with the SEC and the following: our ability to successfully consummate the restructuring of our existing debt, existing equity
interests, and certain other obligations, and emerge from the chapter 11 in bankruptcy court; the impact of the COVID-19 pandemic and its effect on our business, financial condition, employees, contractors and vendors, and on the global
demand for oil and natural gas and U.S. and world financial markets; the effects of chapter 11 on our business and the interests of various constituents; risks associated with assumption of contracts in chapter 11, our ability to comply with
the covenants under our exit facility and the related impact on our ability to continue as a going concern; the volatility of oil, natural gas and natural gas liquids prices, which are affected by general economic and business conditions, as well
as increased demand for (and availability of) alternative fuels and electric vehicles; 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 replace reserves and sustain production; drilling and operating risks and resulting liabilities; our ability to generate profits or achieve targeted results in drilling and well operations; 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; adverse developments or losses from pending or future litigation and regulatory proceedings, including royalty claims; legislative and regulatory initiatives addressing environmental concerns, including initiatives addressing the
impact of global climate change or further regulating hydraulic fracturing, methane emissions, flaring or water disposal; terrorist activities and/or cyber-attacks adversely impacting the our operations; effects of acquisitions and dispositions
and our ability to realize related synergies and cost savings; and effects of purchase price adjustments and indemnity obligations. Additional factors that could affect our future results or events are described under the heading “Risk Factors”
in our Annual Report on Form 10-K for the fiscal year ended December 31, 2019 (the “2019 10-K”) and our Quarterly Reports on Form 10-Q for the quarters ended March 31, June 30, and September 30, 2020, and in other reports we file
with the U.S. Securities and Exchange Commission from time to time. Readers are cautioned not to place undue reliance on forward-looking statements. All forward-looking statements set forth in this document are qualified by these
cautionary statements and there can be no assurance that the actual results or developments anticipated by us will be realized or, even if substantially realized, that they will have the expected consequences to, or effects on, us or our
business or operations. Forward-looking statements set forth in this document speak only as of the date hereof, and we do not undertake any obligation to update forward-looking statements to reflect subsequent events or circumstances,
changes in expectations or the occurrence of unanticipated events, except to the extent required by law.
NON-GAAP FINANCIAL MEASURES
Certain financial information included herein, including Adjusted EBITDA and Adjusted EBITDAX, are not presentations made in accordance with U.S. GAAP, and use of such terms varies from others in the same industry. Non-GAAP
financial measures should not be considered as alternatives to net income (loss), total operating expenses or any other performance measures derived in accordance with U.S. GAAP as measures of operating performance or cash flows as
measures of liquidity. Non-GAAP financial measures have important limitations as analytical tools, and you should not consider them in isolation or as substitutes for results as reported under U.S. GAAP. See the Appendix to this
presentation for a reconciliation of certain non-GAAP financial measures to the most directly comparable financial measures calculated in accordance with U.S. GAAP.
NATURAL GAS, OIL & NATURAL GAS LIQUIDS RESERVES
The Company’s proved reserves and adjusted proved reserves are those quantities of natural gas, oil, and natural gas liquids, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be
economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire,
unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation.
The Company’s estimate of its total proved reserves is based on reports prepared by LaRoche Petroleum Consultants, Ltd., independent petroleum engineers, and internal estimates. Factors affecting ultimate recovery include the scope of
the Company’s ongoing drilling program, which will be directly affected by the availability of capital, drilling and production costs, availability of drilling services and equipment, drilling results, lease expirations, transportation constraints,
regulatory approvals, actual drilling results, including geological and mechanical factors affecting recovery rates, and other factors. Estimates may change significantly as development of the Company’s natural gas, oil and natural gas liquids
assets provide additional data. The Company’s production forecasts and expectations for future periods are dependent upon many assumptions, including estimates of production decline rates from existing wells and the undertaking and
outcome of future drilling activity, which may be affected by significant commodity price declines or drilling cost increases.
Consistent Returns, Sustainable Future – February 9, 2021 2
4. Chesapeake Today: A Fundamentally Different Company
Low-cost operator built to generate sustainable free cash flow from a strong balance sheet,
diverse asset base and leading ESG performance.
Committed to ESG and
safety excellence
World-class natural gas
assets, oil optionality
and scale to win
Strong balance sheet
with low leverage profile
Disciplined capital
reinvestment strategy
Built to generate
sustainable free cash flow
Low-cost operator with
top-quartile cash costs
Consistent Returns, Sustainable Future – February 9, 2021 4
5. Disciplined capital
reinvestment rate targeting
60% – 70%
to yield positive FCF and 400+
mboe/d on $700mm – $750mm
of annual capex
Achieve net-zero direct
GHG emissions by 2035
• Eliminate routine flaring on all new wells
completed from 2021 forward, and
enterprise-wide by 2025
• Reduce methane intensity(4)
to 0.09%
and GHG intensity(5)
to 5.5 by 2025
Our Pledge: Consistent Returns, Sustainable Future
Consistent Returns, Sustainable Future – February 9, 2021 5
Focus on
cost reduction
Targets 30% – 40%
of EBITDAX as FCF yield
Cash cost leadership
~$1B
annual cash costs(3)
removed
vs. 2019, a permanent reduction
>$2B of FCF
projected over next five years provides
flexibility to enhance returns through
debt reduction, dividends, share
buybacks, redeployment or M&A
(2)
Preserve balance
sheet strength
Targeting
<1X long-term
leverage(1)
(1) Defined as net debt / EBITDAX. Net debt = principal of debt + revolving facility balance - cash on hand. EBITDAX is a non-GAAP financial measure and is defined as earnings before interest, taxes, depreciation and amortization and exploration cost. See the appendix for a
reconciliation of Net Cash from Operating Activities to EBITDAX. (2) Free cash flow (FCF) is a non-GAAP financial measure and is defined as net cash flow from all activities excluding financing transactions and restructuring costs. Estimated based on 1/22/2021 strip pricing from
2021 to 2025. (3) Total cash costs = LOE + GP&T + G&A + operating taxes (excluding income taxes) + interest. (4) Defined as volume methane emissions / volume gross gas produced. (5) Defined as tCO2e/gross boe produced.
6. Deep Portfolio: Diversified Positions Across Multiple Basins
Consistent Returns, Sustainable Future – February 9, 2021 6
Note: Net acres and projected WI and NRI estimates as of 12/31/2020.
(1) Capex inclusive of D&C, workover, land/G&G, facilities and capitalized G&A but excludes capitalized interest
4Q’20E Production
~435 mboe/d
Appalachia: 1,110 mmcf/d Brazos Valley: 41 mboe/d
Gulf Coast: 558 mmcf/d Powder River Basin: 22 mboe/d
South Texas: 84 mboe/d Mid-Continent: 10 mboe/d
Projected $700mm – $750mm
Annual Sustaining Capex(1)
Divested in
Dec. 2020
2021E Asset Development Detail
(~$650mm Development Capex)
Gulf Coast
40%
South Texas
8%
Powder River
2%
Appalachia
45%
Brazos Valley
5%
GULF COAST
~225,000 Net acres
~80% WI // 65% NRI
~$260mm Capex (1)
2 – 3 Active Rigs // ~30 Wells Drilled
APPALACHIA
~540,000 Net acres
~40% WI // 35% NRI
~$300mm Capex (1)
~3 Active Rigs // ~65 Wells Drilled
BRAZOS VALLEY
~420,000 Net acres
~95% WI // 75% NRI
~$30mm Capex (1)
0 Active Rigs // 0 Wells Drilled
SOUTH TEXAS
~220,000 Net acres
~60% WI // 45% NRI
~$50mm Capex (1)
~0.5 Active Rigs // ~10 Wells Drilled
POWDER RIVER BASIN
~190,000 Net acres
~80% WI // 65% NRI
~$10mm Capex (1)
0 Active Rigs // 0 Wells Drilled
MID-CONTINENT
Sold December 2020
4Q’20E Production Mix
NGL
6%
Oil
20%
Gas
74%
7. Notes Credit Facility
$500 $500
$50
(3)
$221
(4)
2021 2022 2023 2024 2025 2026 2027 2028 2029
Post-petition ($mm)
Restored Balance Sheet
Significant liquidity
• $2.5B borrowing base at exit
• $1.7B(1)
available at emergence
Expected substantial FCF targeted to result
in revolver undrawn by year end 2021
Cash flow projections substantially de-risked
through robust hedging program
(1) Borrowing base currently supporting up to $1.97B of Tranche A and B credit facility commitments assuming. (2) As of 6/28/2020. (3) Current balance upon exit from Ch. 11 proceedings (excludes letters of credit).
(4) Represents $221mm of CA-CIB and Natixis Tranche B. (5) Share range dependent upon method of warrant exercise elected by holders (method of exercise is for cash or cashless).
Expected to issue 100mm – 138mm of common
shares upon emergence
• Inclusive of Rights Offerings, Backstop Agreement
and Warrants, depending on exercise(5)
$0
$500
$1,000
$1,500
$2,000
$2,500
2020 2021 2022 2023 2024 2025 2026 2027
Pre-petition(2)
$294 $272
$2,096 $2,124
$2,578
$1,229
$253
$249
7
Consistent Returns, Sustainable Future – February 9, 2021
8. Balance Sheet Improved vs. IG Peers
Consistent Returns, Sustainable Future – February 9, 2021 8
Source: Capital IQ, Eikon and Bloomberg; peer estimates per IBES market data as of 1/18/2021.
Note: Data based on strip prices as of 1/18/2021. COP and PXD estimates are pro forma for announced mergers. FANG shown pro forma for announced acquisition based on research estimates, exclusive of announced synergies.
(1) CHK at emergence calculated as net debt at emergence over LTM Q1 2021 EBITDA. (2) 2019 CHK calculated as YE 2019 net debt over 2019 EBITDA.
0.8x
3.5x
0.0 x
0.5 x
1.0 x
1.5 x
2.0 x
2.5 x
3.0 x
3.5 x
4.0 x
EOG PF CHK COG PXD COP XEC DVN MRO CLR SWN FANG EQT OVV AR APA RRC CHK 2019
Significant reduction
Targeting <0.5x by YE 2021
(1)
Indicates IG Credit Rating
CHK
2019(2)
CHK at
emergence(1)
9. Investment-Grade Scale
Consistent Returns, Sustainable Future – February 9, 2021 9
Source: Company disclosure and SEC filings
445
0
200
400
600
800
1,000
1,200
COP EOG EQT AR OVV CHK SWN COG APA MRO RRC PXD DVN HES CXO CLR FANG XEC WPX PDCE CRK PE MUR SM CPE LPI
Q3
2020
Production
(mboe/d)
1 Basin 2 Basins 3+ Basins
Chesapeake is one of the largest U.S.
independent E&Ps by production,
with a geographically diversified,
top-tier asset base
Indicates IG Credit Rating
445
CHK
10. Marketing Contract Negotiations
POWDER RIVER BASIN
$58mm GP&T reduction
No savings in 2021
4-year PDP MVC
GULF COAST
$980mm GP&T reduction
$100mm in 2021
Reduced FT commitments
APPALACHIA
$196mm GP&T reduction
$4mm in 2021
Reduced FT commitments
MID-CONTINENT
Successful divestment
SOUTH TEXAS
$525mm GP&T reduction
$115mm in 2021
Removed Processing and Crude MVCs
BRAZOS VALLEY
$337mm GP&T reduction
$62mm in 2021
Eliminated all MVCs
(1) All figures compared vs Chapter 11 commencement in May 2020 and current as of January 2021.
$4B in Contract Savings
($2.2B PV-10, $281mm in 2021)
~$5.15/boe 2021 GP&T
(Down >20% from 2020, 40% from 2015)
Long term commitments reduced
by 55% (~$3.0B)(1)
Reduced contracts from
over 2,000 to approximately 800
Successfully renegotiated or
rejected ~$15B in contracts
Consistent Returns, Sustainable Future – February 9, 2021 10
11. Reset, Competitive Midstream Contracts
Consistent Returns, Sustainable Future – February 9, 2021 11
Source: Chesapeake Filings, Management Projections
Note: 2021E and 2022E excludes Mid-Continent.
$ 0.00
$ 1.00
$ 2.00
$ 3.00
$ 4.00
$ 5.00
$ 6.00
$ 7.00
$ 0
$ 200
$ 400
$ 600
$ 800
$ 1,000
$ 1,200
2019 2020E 2021E 2022E
$/boe
$
mm
Appalachia Gulf Coast South Texas Brazos Valley Rockies Other $/Boe
Total GP&T ($mm & $/boe)
Appalachia Gulf Coast South Texas
Brazos Valley Rockies Other $/boe
>20%
>5%
12. Significant Improvement in Cost Structure to Support
Sustainable Free Cash Flow Generation
Source: Public filings, Management Guidance
Note: Implied revenue per boe calculated as illustrative 2021E revenues at each price deck and including the effect of hedges in place divided by 2021E projected production.
Meaningful Cost Reduction ($/boe)
Confirmed Cost Reduction Efforts
Rationalized drilling program to target highest return locations
At emergence debt burden will be reduced by ~$7.7B from
pre-bankruptcy levels
Reduction of cash G&A expenses of ~$125mm compared to YE 2019
Successfully renegotiated GP&T agreements in all operating areas
Continued efforts to reduce LOE including reducing SWD costs,
optimizing repairs and maintenance expense and workover
2021 Cost Guidance
$mm per/boe
Capex $670 – $740 $4.35 – $4.80
Interest Expense $60 – $70 $0.40 – $0.45
G&A $180 – $200 $1.15 – $1.30
Production Tax $130 – $150 $0.85 – $0.95
GP&T $760 – $830 $4.90 – $5.40
LOE $300 – $330 $1.95 – $2.15
TOTAL $2,100 – $2,320 $13.60 – $15.05
~50%
Reduction
Opportunity
for Free
Cash Flow
FY2019 2021E
Capex:
$12.71
WTI: $50.00; HH: $3.00
WTI: $40.00; HH:$2.50
$ 18.98
$ 17.78
G&A: $1.78
Interest Expense:
$3.69
LOE
$2.94
GP&T
$6.13
Production Tax: $1.27
Implied
Revenue /
boe
(Realized)
GP&T:
$6.13
LOE:
$2.94
$28.52
Consistent Returns, Sustainable Future – February 9, 2021 12
13. $0
$2
$4
$6
$8
$10
$12
$14
$16
$18
COG SWN CRK XEC CHK
2021
EQT FANG PXD CLR RRC CPE EOG APA AR DVN SM MRO OVV COP WPX CHK
2019
Total Cash Costs/boe
Top-Quartile Cost Structure
Source: Peer figures based on company 2020 Third Quarter 10-Q filings, quarter-to-date (3 month) results only. CHK 2021E based on midpoints of 2021 guidance.
Note: Total cash costs = LOE + GP&T + G&A + operating taxes (excluding income taxes) + interest
~40% reduction
and still working…
CHK
2021
CHK
2021
CHK
2019
484 mboe/d
410 – 420 mboe/d
$15.81
$9.75
Consistent Returns, Sustainable Future – February 9, 2021 13
14. Meaningful Shift to Delivering Free Cash Flow
Consistent Returns, Sustainable Future – February 9, 2021 14
Source: Capital IQ, Eikon and Bloomberg; peer estimates per IBES, market data as of 1/18/2021.
Note: Data based on IBES estimates as adjusted for strip prices as of 1/18/2021. COP and PXD estimates are pro forma for announced mergers. FANG shown pro forma for announced acquisition based on research estimates, exclusive of announced synergies.
(1) CHK excludes financing transaction and restructuring cost.
0 %
5 %
10 %
15 %
20 %
25 %
30 %
35 %
40 %
45 %
50 %
55 %
COG COP XEC EOG CHK PXD APA DVN MRO CLR RRC EQT FANG OVV AR SWN
2021E
FCF
(%
EBITDA)
CHK(1)
15. Leading a Responsible Energy Future
Our path to achieving net-zero direct GHG emissions by 2035
Environmental Stewardship
• Eliminate routine flaring on all wells completed from 2021 forward,
and enterprise-wide targeted by 2025
• Targeted reduction of GHG intensity and methane intensity by 2025
• Intend to initiate first electric frac in 2021, opportunity to implement
enterprise-wide
Social Engagement
• One CHK culture and company core values promote a diverse,
inclusive and productive workplace
• Commitment to increased I&D education and training
Governance Reform
• Forming Board committee dedicated to ESG oversight
Source: Company disclosure
0
20
40
60
MRO
APA
CPE
DVN
COP
WPX
XEC
CLR
PXD
EOG
OVV
SM
FANG
AR
CHK
CNX
SWN
COG
CRK
EQT
RRC
2019 GHG Emissions Intensity
metric tons CO2e/gross mboe produced
8.2
16.1
FLIGHT Peer Avg 2019
0.0%
0.4%
0.8%
1.2%
CPE
COP
APA
MRO
WPX
PXD
DVN
CLR
XEC
FANG
CHK
OVV
EOG
CNX
SM
COG
CRK
EQT
AR
SWN
RRC
2019 Methane Intensity
volume methane emissions/volume gross gas produced
0.17% 0.25%
0.20%
FLIGHT Peer Avg 2019 2025 OGCI ambition
Consistent Returns, Sustainable Future – February 9, 2021 15
16. CHK Scope 1 and 2 GHG Metrics
2019 GHG and methane intensity increased due to the
WRD acquisition
Post-acquisition, CHK initiated a concerted effort to
high-grade the BV asset to CHK standards by adding
• Emission controls
• Emission monitoring programs
• Reducing programs
We expect 2020 GHG metrics will show that methane
intensity decreased compared to 2019
(1) Volume methane emissions/volume gross gas produced. (2) Metric tons methane emissions / gross oil and gas production, mboe.
GHG: Greenhouse Gas as carbon dioxide, methane, and nitrous oxide; Scf: Standard cubic feet; MMscf: Million standard cubic feet; mboe: Thousand barrels of crude oil equivalent. 6 thousand scf = 1 boe;
CO2e: Carbon dioxide equivalent. 1 metric ton methane = 25 CO2e and 1 metric ton nitrous oxide = 298 CO2e
Scope 1
Methane intensity(1)
GHG intensity(2)
2019 0.17% 8.2
2018 0.16% 7.2
2017 0.19% 9.1
Total GHG Intensity(2)
Scope 1
97%
Scope 2
3%
Consistent Returns, Sustainable Future – February 9, 2021 16
17. 2019 Emissions by Operator
Consistent Returns, Sustainable Future – February 9, 2021 17
Source: Enverus December 2020 Play by Play Conference. PXD and MGY assumes 2018 data.
18. Chesapeake Today: A Fundamentally Different Company
Low-cost operator built to generate sustainable free cash flow from a strong balance sheet,
diverse asset base and leading ESG performance.
Committed to ESG and
safety excellence
World-class natural gas
assets, oil optionality
and scale to win
Strong balance sheet
with low leverage profile
Disciplined capital
reinvestment strategy
Built to generate
sustainable free cash flow
Low-cost operator with
top-quartile cash costs
Consistent Returns, Sustainable Future – February 9, 2021 18
20. Board of Directors
MICHAEL WICHTERICH, Chairman
• Founder and CEO of Three Rivers Operating Company LLC
• Most recently served as CFO of Texas American Resources
• Previous experience includes CFO at New Braunfels Utilities and
Mariner Energy, and energy audit at PwC
• Currently serving on the boards of Grizzly Energy, Bruin E&P
Operating and Extraction Oil and Gas
TIMOTHY S. DUNCAN
• Founder, President and CEO of Talos Energy Inc.
• Served as a director at Talos since April 2012
• Prior to Talos, served as Senior Vice President of Business
Development and a founder of Phoenix Exploration Company LP
BENJAMIN C. DUSTER, IV
• Founder and Chief Executive Officer of Cormorant IV Corporation,
LLC, a consulting firm specializing in operational turnarounds and
organizational transformations
• A 30-year veteran of Wall Street with extensive experience in
M&A and Strategic Advisory Services in both developed and
emerging markets
• Currently serving on the boards of Weatherford International, Plc
and Alaska Communications Systems Group, Inc.
SARAH EMERSON
• President and managing principal at ESAI Energy, LLC, an
energy consulting firm
• Currently serving as a Senior Associate at the Center for
Strategic and International Studies and has been a Senior Fellow
at the Kennedy School at Harvard University
MATTHEW M. GALLAGHER
• Former President and CEO of Parsley Energy Inc.
• Prior to serving as CEO, served as Parsley’s COO from 2014
to 2019
• Currently serving on the board of Pioneer Natural Resources
ROBERT D. LAWLER
• President, CEO and Director of Chesapeake Energy Corporation
since 2013
• Prior to Chesapeake, has held multiple engineering and
leadership positions at Anadarko Petroleum Corporation and
Kerr-McGee
BRIAN STECK
• Currently the Chairman of Bonanza Creek Energy, Inc.
• Previously served as a Partner at Mangrove Partners since 2011
• Currently serving on boards of Bonanza Creek and California
Resources Corporation
Consistent Returns, Sustainable Future – February 9, 2021 20
21. Hedging Program Reduces Risk, Protects Returns
Consistent Returns, Sustainable Future – February 9, 2021 21
Note: Hedged volumes and hedged prices reflect hedges as of 2/4/2021.
Average Hedged Price 2021 2022
Gas ($/mcf) $ 2.69 $ 2.53
Oil ($/bbl) $ 42.69 $ 44.30
75%
34%
77%
67%
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
2021 2022
% of Gas Vol % of Oil Vol
Locked in
>75%
of forecasted
volumes for 2021
22. Gas Assets: Appalachia and Gulf Coast
($0.50)/mcf annual average
in-basin to NYMEX pricing
Premium realizations in
winter months
~40% of 4Q’20E production
Marketing fee excluded. Basis based on periods 2021E – 2025E.
($0.18)/mcf annual average
in-basin to NYMEX pricing
~20% of 4Q’20E production
$0.90
$0.76 $0.74
$0.70 $0.72
$0.66
$0.56
$0.00
$0.20
$0.40
$0.60
$0.80
$1.00
2018 2019 2020E 2021E 2022E
Appalachia: Gas GP&T ($/mcf)
$0.90
$0.95 $0.93
$0.69 $0.72
$0.42 $0.42
$0.00
$0.20
$0.40
$0.60
$0.80
$1.00
$1.20
2018 2019 2020E 2021E 2022E
Gulf Coast: Gas GP&T ($/mcf)
Pre-Restructuring
4Q’20E Production:
558 mmcf/d
Gas 100%
4Q’20E Production:
1,110 mmcf/d
Gas 100%
Consistent Returns, Sustainable Future – February 9, 2021 22
23. 54% Oil
Gas 26%
NGL 19%
South Texas
+$0.15/mcf, +$0.30/bbl oil, and +$0.15/bbl NGL annual average in-basin to NYMEX pricing
Eliminated processing and crude MVCs, only gas gathering MVCs remain
~20% of 4Q’20E production
Marketing fee excluded. Basis based on periods 2021E – 2025E.
$5.25
$4.56
$6.37
$6.69
$7.48
$6.29
$7.07
$0.00
$2.00
$4.00
$6.00
$8.00
2018 2019 2020E 2021E 2022E
Gas GP&T ($/mcf)
$5.09
$5.37
$6.27 $6.42 $6.39
$3.97 $4.15
$0.00
$2.00
$4.00
$6.00
$8.00
2018 2019 2020E 2021E 2022E
Oil GP&T ($/bbl)
$3.84
$4.16
$3.98
$2.95 $2.98
$1.44 $1.48
$0.00
$1.00
$2.00
$3.00
$4.00
$5.00
2018 2019 2020E 2021E 2022E
NGL GP&T ($/bbl)
4Q’20E Production:
84 mboe/d
Pre-Restructuring
Consistent Returns, Sustainable Future – February 9, 2021 23
24. Brazos Valley
($0.50)/mcf, ($0.75)/bbl oil, and ($8.30)/bbl NGL annual average in-basin to NYMEX pricing
Eliminated all MVCs
~10% of 4Q’20E production
Marketing fee excluded. Basis based on periods 2021E – 2025E.
$0.03
$0.05 $0.05 $0.05
$0.04 $0.04
$0.00
$0.01
$0.02
$0.03
$0.04
$0.05
$0.06
2018 2019 2020E 2021E 2022E
Gas GP&T ($/mcf)
$1.14
$1.58
$1.29 $1.33
$0.55
$0.74
$0.00
$0.50
$1.00
$1.50
$2.00
2018 2019 2020E 2021E 2022E
Oil GP&T ($/bbl)
Pre-Restructuring
4Q’20E Production:
41 mboe/d
74% Oil
Gas 16%
NGL 10%
Consistent Returns, Sustainable Future – February 9, 2021 24
25. Powder River Basin
($0.05)/mcf, ($2.25)/bbl oil, and ($4.15)/bbl NGL annual average in-basin to NYMEX pricing
MVC/EBITDAX recoupment converted to straight MVC, four years, 90% of PDP
~5% of 4Q’20E production
Marketing fee excluded. Basis based on periods 2021E – 2025E.
$3.02
$2.58
$3.15
$3.48
$4.22
$3.28
$4.35
$0.00
$1.00
$2.00
$3.00
$4.00
$5.00
2018 2019 2020E 2021E 2022E
Gas GP&T ($/mcf)
$3.26
$1.92
$2.53
$1.67 $1.70
$1.46 $1.54
$0.00
$1.00
$2.00
$3.00
$4.00
2018 2019 2020E 2021E 2022E
Oil GP&T ($/bbl)
$16.05
$15.00
$17.14 $16.70
$20.17
$14.27
$18.90
$0.00
$5.00
$10.00
$15.00
$20.00
$25.00
2018 2019 2020E 2021E 2022E
NGL GP&T ($/bbl)
Pre-Restructuring
4Q’20E Production:
22 mboe/d
45% Oil
Gas 39%
NGL 16%
Consistent Returns, Sustainable Future – February 9, 2021 25
26. Reconciliation of Net Cash from Operating Activities to Adj. EBITDAX
CHESAPEAKE ENERGY CORPORATION
RECONCILIATION OF NET CASH PROVIDED BY OPERATING ACTIVITIES TO
ADJUSTED EBITDAX
($ in millions) (unaudited)
Years Ended December 31,
2019
NET CASH PROVIDED BY OPERATING ACTIVITIES (GAAP) $1,623
Adjustments:
Changes in assets and liabilities 254
Other revenue (59)
Interest expense 651
Exploration 35
Income tax benefit (26)
Stock-based compensation (30)
Restructuring and other termination costs 12
Losses on investments 7
Losses on purchases or exchanges of debt 5
Net income attributable to noncontrolling interests —
Other items 58
Adjusted EBITDAX
(a)
(Non-GAAP) $2,530
*Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting.
(a) Adjusted EBITDAX is not a measure of financial performance under GAAP, and should not be considered as an alternative to, or more meaningful than, cash flow provided by operating activities prepared in accordance with GAAP. Adjusted EBITDAX excludes certain
items that management believes affect the comparability of operating results. The company believes this non-GAAP financial measure is a useful adjunct to cash flow provided by operating activities because:
(i) Management uses adjusted EBITDAX to evaluate the company's operational trends and performance relative to other oil and natural gas producing companies.
(ii) Adjusted EBITDAX is more comparable to estimates provided by securities analysts.
(iii) Items excluded generally are one-time items or items whose timing or amount cannot be reasonably estimated. Accordingly, any guidance provided by the company generally excludes information regarding these types of items.
Because adjusted EBITDAX excludes some, but not all, items that affect net income (loss), our calculations of adjusted EBITDAX may not be comparable to similarly titled measures of other companies.
Consistent Returns, Sustainable Future – February 9, 2021 26