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.
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.
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 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 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.
- 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.
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.
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.
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.
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 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 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.
- 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.
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.
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 OUTFRONT Media's assets and business model as a REIT. It details the company's primary asset types which include billboards, digital displays, posters, and transit assets. It also summarizes the company's top market locations and timeline of becoming a publicly-traded REIT after its split from CBS Corporation in 2014.
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.
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.
This document provides an overview of SemGroup's non-GAAP financial measures, forward-looking statements, and strategy for creating shareholder value. It discusses SemGroup's stable cash flows derived from long-term contracts and investment-grade counterparties. The presentation also outlines SemGroup's crude oil and natural gas assets located in key North American basins and its strategy to pursue organic growth and strategic acquisitions.
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.
Jp energy mlpa conference jun2016-finalir_jpenergy
MLPA Investor Conference held in June 2016. The presentation discusses JP Energy Partners LP (JPEP), a publicly traded MLP that operates in crude oil pipelines and storage, refined products terminals and storage, and NGL distribution and sales. It provides an overview of each segment's assets and operations. The presentation also notes that JPEP has achieved growth through acquisitions and expansion projects since its inception in 2013.
EnLink Midstream provides an overview of its business including its financial and operational highlights for 3Q 2016. Key points include refined 2016 Adjusted EBITDA guidance of $760-790 million, 3Q 2016 Adjusted EBITDA before non-controlling interest of ~$201 million, and distribution coverage ratios of 1.05x for ENLK and 1.07x for ENLC. EnLink also discusses its growth strategy, positioned across multiple basins and services, and commitment to financial strength with leverage of 3.75x debt to Adjusted EBITDA.
1) EnLink Midstream provides guidance for 2017 including adjusted EBITDA of $815-885 million and distributable cash flow of $590-650 million.
2) Capital expenditures are projected to be $590-750 million focused on growth projects in core areas like Central Oklahoma, Delaware Basin, and Louisiana.
3) Volume growth is expected across all segments, especially in Central Oklahoma where volumes are projected to increase 180% year-over-year.
Management Investor Presentation - Year End 2015RioCan
This document provides an investor presentation for RioCan Real Estate Investment Trust for the year ending 2015. It discusses RioCan's portfolio metrics including properties, market capitalization, and tenant profile. It also summarizes recent corporate developments including the planned sale of RioCan's US portfolio for $1.9 billion US to focus on the Canadian market. Finally, it highlights RioCan's financial results for 2015, including increased funds from operations and improved payout ratios compared to 2014.
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.
- The document is an investor presentation that provides forward-looking statements and information about risks and uncertainties that could impact financial performance.
- It notes that statements in the presentation regarding prospects, financial performance, dividend growth, management plans and other matters are forward-looking.
- The presentation directs investors to SEC filings for additional information about the proposed merger between SemGroup and Rose Rock Midstream.
This document provides an overview of RioCan's third quarter 2016 results and financial position:
- Funds from operations increased year-over-year driven by growth in net operating income. Occupancy rates also improved across the portfolio.
- RioCan acquired over $1.2 billion in properties in Canada since last year and completed a debenture offering at a historically low interest rate.
- Financial metrics like interest coverage and leverage remain conservative and RioCan maintains a staggered debt maturity schedule with low floating rate exposure.
- 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 investor presentation for Crestwood Midstream Partners LP and Crestwood Equity Partners LP. It summarizes the companies' strategic pivot to improve processes and efficiencies, reduce costs, simplify operations, and deleverage the balance sheet. Going forward, the companies plan to focus on executing existing projects, high-grading growth opportunities, and pursuing disciplined growth through joint ventures to enhance their strategic position while preserving financial strength. Key regions for potential long-term growth include the Marcellus Shale, Bakken, and Delaware Permian areas.
The document provides an overview of Brink's, a global secure logistics company, ahead of investor meetings in August 2017. It discusses Brink's leadership position in the cash management market, growth strategy focused on profitable growth, operational excellence and introducing differentiated services, and strategic execution through organic initiatives and acquisitions. Brink's targets revenue of $3.3 billion and operating profit margin of 12.5% by 2019 through this strategy. Recent acquisitions are expected to contribute $175 million in additional revenue and $45 million in operating profit to the 2019 targets.
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.
This presentation provides an overview of Advanced Emissions Solutions, Inc. It discusses the company's transformation from focusing on refined coal and equipment sales to developing recurring revenue streams from emissions control technologies. The presentation highlights that the company expects to generate $50-60 million annually in stable cash flows from its refined coal business through 2021. It also discusses opportunities to commercialize emissions control intellectual property and generate incremental cash flows. The presentation provides an overview of the refined coal and emissions control markets and outlines the company's strategic priorities for 2017.
This document provides an overview of SemGroup's non-GAAP financial measures, forward-looking statements, and strategic growth plan. It discusses SemGroup's Adjusted EBITDA measure and why certain items are excluded. It also notes key limitations of non-GAAP measures and that management compensates for these limitations. An overview is then provided of SemGroup's crude and natural gas assets, operations, and strategic growth areas. Key performance metrics and asset details are highlighted for SemGroup's crude and natural gas businesses.
The document provides an overview of JP Energy Partners LP and discusses its three business segments: crude oil pipelines and storage, refined products terminals and storage, and NGL distribution and sales. It also discusses JP Energy's Q3 2016 financial results, balance sheet and liquidity position, and its planned merger with American Midstream Partners to create a larger, more diversified midstream company.
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.
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 an overview of OUTFRONT Media's assets and business model as a REIT. It details the company's primary asset types which include billboards, digital displays, posters, and transit assets. It also summarizes the company's top market locations and timeline of becoming a publicly-traded REIT after its split from CBS Corporation in 2014.
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.
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.
This document provides an overview of SemGroup's non-GAAP financial measures, forward-looking statements, and strategy for creating shareholder value. It discusses SemGroup's stable cash flows derived from long-term contracts and investment-grade counterparties. The presentation also outlines SemGroup's crude oil and natural gas assets located in key North American basins and its strategy to pursue organic growth and strategic acquisitions.
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.
Jp energy mlpa conference jun2016-finalir_jpenergy
MLPA Investor Conference held in June 2016. The presentation discusses JP Energy Partners LP (JPEP), a publicly traded MLP that operates in crude oil pipelines and storage, refined products terminals and storage, and NGL distribution and sales. It provides an overview of each segment's assets and operations. The presentation also notes that JPEP has achieved growth through acquisitions and expansion projects since its inception in 2013.
EnLink Midstream provides an overview of its business including its financial and operational highlights for 3Q 2016. Key points include refined 2016 Adjusted EBITDA guidance of $760-790 million, 3Q 2016 Adjusted EBITDA before non-controlling interest of ~$201 million, and distribution coverage ratios of 1.05x for ENLK and 1.07x for ENLC. EnLink also discusses its growth strategy, positioned across multiple basins and services, and commitment to financial strength with leverage of 3.75x debt to Adjusted EBITDA.
1) EnLink Midstream provides guidance for 2017 including adjusted EBITDA of $815-885 million and distributable cash flow of $590-650 million.
2) Capital expenditures are projected to be $590-750 million focused on growth projects in core areas like Central Oklahoma, Delaware Basin, and Louisiana.
3) Volume growth is expected across all segments, especially in Central Oklahoma where volumes are projected to increase 180% year-over-year.
Management Investor Presentation - Year End 2015RioCan
This document provides an investor presentation for RioCan Real Estate Investment Trust for the year ending 2015. It discusses RioCan's portfolio metrics including properties, market capitalization, and tenant profile. It also summarizes recent corporate developments including the planned sale of RioCan's US portfolio for $1.9 billion US to focus on the Canadian market. Finally, it highlights RioCan's financial results for 2015, including increased funds from operations and improved payout ratios compared to 2014.
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.
- The document is an investor presentation that provides forward-looking statements and information about risks and uncertainties that could impact financial performance.
- It notes that statements in the presentation regarding prospects, financial performance, dividend growth, management plans and other matters are forward-looking.
- The presentation directs investors to SEC filings for additional information about the proposed merger between SemGroup and Rose Rock Midstream.
This document provides an overview of RioCan's third quarter 2016 results and financial position:
- Funds from operations increased year-over-year driven by growth in net operating income. Occupancy rates also improved across the portfolio.
- RioCan acquired over $1.2 billion in properties in Canada since last year and completed a debenture offering at a historically low interest rate.
- Financial metrics like interest coverage and leverage remain conservative and RioCan maintains a staggered debt maturity schedule with low floating rate exposure.
- 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 investor presentation for Crestwood Midstream Partners LP and Crestwood Equity Partners LP. It summarizes the companies' strategic pivot to improve processes and efficiencies, reduce costs, simplify operations, and deleverage the balance sheet. Going forward, the companies plan to focus on executing existing projects, high-grading growth opportunities, and pursuing disciplined growth through joint ventures to enhance their strategic position while preserving financial strength. Key regions for potential long-term growth include the Marcellus Shale, Bakken, and Delaware Permian areas.
The document provides an overview of Brink's, a global secure logistics company, ahead of investor meetings in August 2017. It discusses Brink's leadership position in the cash management market, growth strategy focused on profitable growth, operational excellence and introducing differentiated services, and strategic execution through organic initiatives and acquisitions. Brink's targets revenue of $3.3 billion and operating profit margin of 12.5% by 2019 through this strategy. Recent acquisitions are expected to contribute $175 million in additional revenue and $45 million in operating profit to the 2019 targets.
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.
This presentation provides an overview of Advanced Emissions Solutions, Inc. It discusses the company's transformation from focusing on refined coal and equipment sales to developing recurring revenue streams from emissions control technologies. The presentation highlights that the company expects to generate $50-60 million annually in stable cash flows from its refined coal business through 2021. It also discusses opportunities to commercialize emissions control intellectual property and generate incremental cash flows. The presentation provides an overview of the refined coal and emissions control markets and outlines the company's strategic priorities for 2017.
This document provides an overview of SemGroup's non-GAAP financial measures, forward-looking statements, and strategic growth plan. It discusses SemGroup's Adjusted EBITDA measure and why certain items are excluded. It also notes key limitations of non-GAAP measures and that management compensates for these limitations. An overview is then provided of SemGroup's crude and natural gas assets, operations, and strategic growth areas. Key performance metrics and asset details are highlighted for SemGroup's crude and natural gas businesses.
The document provides an overview of JP Energy Partners LP and discusses its three business segments: crude oil pipelines and storage, refined products terminals and storage, and NGL distribution and sales. It also discusses JP Energy's Q3 2016 financial results, balance sheet and liquidity position, and its planned merger with American Midstream Partners to create a larger, more diversified midstream company.
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.
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.
A copy of Chesapeake Energy's PowerPoint presentation at the Heikkinen Energy Conference in August 2016. Several slides show Chesapeake's shale drilling strategy, which will focus on the Eagle Ford and Haynesville Shale plays in the near-term.
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 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.
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 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.
Teck’s Q4 2019 Financial Results and Investors’ Conference CallTeckResourcesLtd
Teck Resources Limited (TSX: TECK.A and TECK.B, NYSE: TECK) (“Teck”) will release its fourth quarter 2019 earnings results on Friday, February 21, 2020 before market open.
The latest PowerPoint slide deck Chessy pushed out to investors and analysts recapping 2014 results and looking forward to 2015. The company is slashing its budget in 2015 and curtailing production in some regions like the Marcellus.
Q4 2023 Conference Call Presentation - February 22, 2024TeckResourcesLtd
The document provides an overview and summary of Teck Resources Limited's Global Metals and Mining Conference call for the fourth quarter of 2023. It discusses Teck's strong financial performance in Q4 2023 and full year 2023, with record adjusted EBITDA and profit. It also provides an operational update on Teck's major projects and businesses, including the ongoing ramp up of the QB copper mine which is progressing on schedule. Guidance is provided for 2024 production and costs across Teck's copper, zinc and steelmaking coal operations.
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 earnings PowerPoint slide deck used during an earnings call for NFG to highlight their fourth quarter and full year performance. NFG includes Seneca Resources (drilling subsidiary) and Empire Pipeline (midstream subsidiary).
- SemGroup reported third quarter 2016 results with Adjusted EBITDA of $71.3 million, down from $77.7 million in the first quarter of 2016. Net income was a loss of $7.4 million.
- For full year 2016, SemGroup updated capital expenditures guidance to $350 million, a $100 million reduction due to timing of the Maurepas pipeline project.
- SemGroup has a strong balance sheet with $1.1 billion in liquidity and a leverage ratio of 3.0x at the end of the third quarter, within its target leverage of below 4.5x.
QTS Realty Trust presented its fourth quarter and full year 2020 earnings results. Key highlights included:
- Signed leasing activity in Q4 2020 was the highest on record for QTS and 40% higher than the prior year annual level.
- Full year 2020 revenue increased 12% year-over-year to $539 million.
- Adjusted EBITDA for 2020 was $299 million, an increase of 12% compared to 2019.
- 2021 guidance projects revenue growth of 12% and adjusted EBITDA growth also of 12% compared to 2020.
QTS' results demonstrated strong leasing momentum with record backlog entering 2021 to support continued growth.
QTS Realty Trust presented its fourth quarter and full year 2020 earnings results. Key highlights included:
- Signed leasing activity in Q4 2020 was the highest on record for QTS and 40% higher than the prior year annual level.
- Full year 2020 revenue increased 12% year-over-year to $539 million.
- Adjusted EBITDA for 2020 was $299 million, an increase of 12% compared to the previous year.
- 2021 guidance projects revenue growth of 12% and adjusted EBITDA growth also of 12% compared to 2020 results.
- QTS' development pipeline includes over 300 megawatts of new and expansion capital projects in 2021, primarily tied to signed le
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.
The latest PowerPoint presentation issued by Chesapeake on Jan. 2 2014 recapping what they believe will be the end results from 2013 (subject to the usual and customary revisions, of course). The presentaiton shows that all of the firings (over 1,200 people) in 2013 had their effect--capital expenditures were down 48% for the year. Income and profits were up (150% and 33% respectively) for the year.
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
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 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 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
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.
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Cleades Robinson, a respected leader in Philadelphia's police force, is known for his diplomatic and tactful approach, fostering a strong community rapport.
ZKsync airdrop of 3.6 billion ZK tokens is scheduled by ZKsync for next week.pdfSOFTTECHHUB
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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).
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.
2. FORWARD-LOOKING STATEMENT
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, 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/secfilings).
These risk factors include the volatility of oil, natural gas and NGL prices; 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; effects of environmental protection laws and regulation on our business;
terrorist activities and/or cyber-attacks adversely impacting our operations; effects of acquisitions and dispositions, including our acquisition of WildHorse and our ability to realize
related synergies; effects of purchase price adjustments and indemnity obligations; a potential 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; 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; 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; 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; 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 Resource,” “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, 2018, 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.
June 2019 Update 2
3. BUSINESS STRATEGY
Our strategy remains unchanged –
resilient to commodity price volatility
Financial discipline
Profitable and efficient growth
from captured resources
Exploration
Business development
STRATEGIC GOALS
Margin enhancement
Free cash flow
Net debt to EBITDAX of 2X
Excellence in HSER
June 2019 Update 3
4. (1) Adjusted for asset purchases and sales
(2) Cash costs defined as production, general and administrative and gathering, processing and transportation expenses
(3) Cash flow positive defined as net revenue less all operating costs and capital expenditures, excluding general and administrative and interest expenses
June 2019 Update 4
Reduced cash costs(2)
by
~$81 million
14% lower than in the 2018 first quarter
DELIVERING ON OUR STRATEGY
1Q’19 HIGHLIGHTS
On track to deliver transformational oil growth
and materially improved cash flow
$15.50/boe
EBITDAX margin
Highest in four years
Brazos Valley projected to be
cash flow positive
at the asset level in 2019
(3)
Year-over-year adjusted
oil production
increased 13%
(1)
5. 310
320
330
340
350
360
370
380
390
400
4Q'18 1Q'19 2Q'19E 3Q'19E 4Q'19E
40
50
60
70
80
90
100
110
120
130
140
4Q'18 1Q'19 2Q'19E 3Q'19E 4Q'19E
INVESTING IN OUR HIGHEST-MARGIN
OPPORTUNITIES
June 2019 Update 5
(1) 2019 EBITDAX/boe projection is based on 5/8/19 Outlook
(2) Subject to capital reallocation
$10.83
$12.81
$14.80(1)
17 18 19E
Adj. EBITDAX/boe
'17 '18 '19E
0
20
40
60
80
100
120
1Q'19 2Q'19E 3Q'19E 4Q'19E
2019 TIL Schedule
(2)
High-margin
Oil-growth Assets
Cash-generating
Gas Assets
Growth Optionality
19%
oil mix 4Q'18
Total Oil Volume (mbo/d) Total Gas + NGL Volume (mboe/d)
26%
oil mix 4Q'19
6. BRAZOS VALLEY
STRATEGIC PORTFOLIO ADDITION
Asset projected to be free cash flow positive in 2019(1)
Capturing expected capital improvements
and base optimization
Reservoir characterization underway
June 2019 Update 6
(1) Free cash flow defined as net revenue less all operating costs and capital expenditure, excluding general and administrative and interest expense; Based on 5/8/19 Outlook
(2) Represents average net production volumes for 1Q’19; Brazos Valley net sales volumes began on 2/1/19
(3) 2019 Activity reflects 5/8/19 Outlook
2019 Activity(3)
Wells to Turn in Line 85
Rigs 4
Frac Crews 2
Total Capex (millions) $665 – $685
Overview
1Q’19 Production 47 mboe/d(2)
Net Acres ~470,000
Production Mix(2)
GasOil NGL
14%75% 11%
2019 TIL Schedule(3)
13
28
21
23
0
5
10
15
20
25
30
1Q'19 2Q'19E 3Q'19E 4Q'19E
7. ACCELERATING VALUE
BRAZOS VALLEY’S 90-DAY UPDATE
(1) Cash flow positive defined as net revenue less all operating costs and capital expenditures, excluding general and administrative and interest expenses; Based on 5/8/19 Outlook
(2) Improved year-over-year drilling cycle time from March 2018 to March 2019
(3) Set a completion stage record with 11 stages per day on the Bell Pad, which is a 57% improvement over WildHorse's record
June 2019 Update 7
In 2019, asset projected to be
cash flow positive(1)
Base production management
~300 mbo gained
4% monthly improvement
$500k per
well savings
Achieved >$1mm on individual wells
Drilled first extended lateral
~9,800' LL
Plan to average ~9,000' in 2019
SETTING RECORDS:
Drilling cycle time(2)
decreased ~40%
Max completed stages per day(3)
increased ~55%
8. 0
2
4
6
8
10
2017 2018 2019E
Stages per Day by Frac Start Date
~60%
increase
DELIVERING ON EXPECTATIONS
June 2019 Update 8
$0
$200
$400
$600
$800
$1,000
$1,200
2017 2018 2019E
Well Cost per Lateral Foot
by Spud Date
~20%
decrease
0
2,000
4,000
6,000
8,000
10,000
2017 2018 2019E
Lateral Length by Spud Date (ft)
~25%
increase
WRD CHK
0
200
400
600
800
1,000
2017 2018 2019E
IP90 of Oil Wells by TIL Date (boe/d)
~35%
increase
9. OPERATIONAL EXCELLENCE
DRIVING PRODUCTION IMPROVEMENTS
Early wins
• Two-well pad with new flowback procedure
• Average lateral length of 7,500'
• ~35% IP30 uplift based on type well
estimate
Continued focus
• Optimized choke settings and gas lift
injection rates to manage drawdown
• Accelerating gas lift start up to maximize
early time volumes
• Automation upgrades for production
management
June 2019 Update 9
Outperforming type well
estimate by ~35%
~12,000 incremental barrels of oil in first 30 days
0
5,000
10,000
15,000
20,000
25,000
30,000
0 10 20 30 40
GrossOil(bbls)
Producing Days
Easy Rider Production
~35%
increase
Easy Rider Pad
7,500' Type Two-Well Pad
0
60,000
50,000
40,000
30,000
20,000
10,000
10. Bell Pad
Eagle Ford Focus Area
Eagle Ford Play Extent
OPTIMIZED COMPLETIONS
YIELDING RESULTS
Driving significant efficiencies
• 45% reduction in average stage pump time
• 30% reduction in pumped water while maintaining
sand volume
• ~190% improvement, 6.7 mbo,(1)
over historic
performance in traditionally weaker-performing
portion of the play
June 2019 Update 10
(1) Improvement is over a normalized offset analog
(2) Offset WRD pad normalized to four wells per pad and lateral length of 7,000'
0
500
1,000
1,500
2,000
2,500
3,000
0 3 6 9 12 15 18
OilProduction(bo/d)
Days on Production
~190%
increase
CHK Bell Pad Production
Offset WRD Pad(2)
Bell Pad Oil Production
(Avg. Lateral Length of 7,000')
Miles
50250
11. WE ARE JUST GETTING STARTED
Continuing to accelerate value through:
• Driving additional cost savings
• Shifting focus to high-margin oil window
• Leveraging CHK technology to optimize field development
• Improving choke management on flowbacks
• Aggressively addressing repair and maintenance
needs to drive long-term value
• Adopting our top-quartile safety and
environmental practices
June 2019 Update 11
Rex Tyson Jr. 1H Pad in Burleson County
…more to do…
12. SOUTH TEXAS
FREE CASH FLOW MACHINE
Projected to generate ~$450mm in free cash flow(1)
Optimized spacing and completions driving value
Multi-zone high-margin oil growth potential
June 2019 Update
(1) Free cash flow defined as net revenue less all operating costs and capital expenditure, excluding general and administrative and interest expense; Based on 5/8/19 Outlook
(2) Represents average net production volumes for 1Q’19
(3) 2019 Activity reflects 5/8/19 Outlook
2019 TIL Schedule(3)
Overview
1Q’19 Production 110 mboe/d(2)
Net Acres ~235,000
2019 Activity(3)
Wells to Turn in Line 133
Rigs 4
Frac Crews ~2
Total Capex (millions) $510 – $540
Production Mix(2)
GasOil NGL
22%56% 22%
12
29 16
39
49
0
10
20
30
40
50
60
1Q'19 2Q'19E 3Q'19E 4Q'19E
13. Jun-11 Nov-11 May-12 Nov-12 May-13 Nov-13 May-14 Nov-14 May-15 Nov-15 May-16 Nov-16 Apr-17 Oct-17 Apr-18 Oct-18
EURbo/ft
Well Productivity Progression – West Four Corners Region
Percent of the Parent EUR Range of production outcomes
73% at 500' spacing
50% at 330' spacing
95% at 660' spacing
Parent EUR
EAGLE FORD WELL SPACING
ENHANCING PRODUCTION
Significantly reduced parent-child EUR
degradation with 660' spacing
Increased spacing and larger completions
contribute to lower decline rates
Lowest well cost per foot operator on the
western portion of the play(1)
June 2019 Update 13
(1) Source: RS Energy Group
West Four Corners
Lower Eagle Ford
Maturity Windows
Oil
Volatile Oil
Condensate/Wet Gas
Dry Gas
Miles
50250
14. Maturity Windows
Oil
Volatile Oil
Condensate/Wet Gas
Dry Gas
First Co-Development Location
Producing Austin Chalk
Austin Chalk
Upper Eagle Ford
Lower Eagle Ford
Austin Chalk
Upper Eagle Ford
EXPANDING INTO DIFFERENT HORIZONS
June 2019 Update 14
Maximizing multi-bench recovery
• Drilled first CHK Lower Eagle Ford, Upper Eagle Ford
and Austin Chalk co-development location
Promising Austin Chalk results
• Will be developed over existing Lower Eagle Ford
Advancing Upper Eagle Ford
• Will be co-developed with Lower Eagle Ford drilling program
0
50,000
100,000
150,000
200,000
250,000
300,000
350,000
1 101 201 301 401 501
CumulativeProduction(boe)
Days
Austin Chalk Well Performance
2019 Austin Chalk
2018 Upper Eagle Ford
2017 Austin Chalk
0 100 200 300 400 500
Miles
20100
15. POWDER RIVER BASIN
OIL GROWTH ENGINE
Averaged 39 mboe/d (46% oil) in April
Project 100% YOY oil growth in 2019
Turner in full development
June 2019 Update 15
2019 TIL Schedule(2)
Overview
1Q’19 Production 36 mboe/d(1)
Net Acres ~213,000
2019 Activity(2)
Wells to Turn in Line 72
Rigs 6
Frac Crews ~1
Total Capex (millions) $505 – $525
Production Mix(1)
GasOil NGL
38%45% 17%
13
15
24
20
0
5
10
15
20
25
30
1Q'19 2Q'19E 3Q'19E 4Q'19E
(1) Represents average net production volumes for 1Q’19
(2) 2019 Activity reflects 5/8/19 Outlook
16. DRIVING RECORD RESULTS IN THE TURNER
June 2019 Update 16
BB2 PAD
SWD Wells
Producing Turner Well
Planned TIL
CPF/SWD
Turner Oil Window
High GOR
Delineated
Turner
Miles
1050
Single well production record – RRC 5 well
• >4,000 boe/d
• >3,000 bo/d
Pad production record – BB2 pad
• >9,000 boe/d
• >7,800 bo/d
• >7,200 mcf/d
Field production record
• Net 42 mboe (48% oil) on May 1
17. $11.18 $11.54
$12.89
$20.50
FY 2016 FY 2017 FY 2018 FY 2019E
EXPANDING POWDER RIVER MARGINS
June 2019 Update 17
(1) Based on 5/8/19 Outlook
(1)
Powder River Basin EBITDAX/boe
3%
increase
12%
increase
~60%
increase
Oil sales line began flowing 5/3/19
• >15% field volumes currently being piped
GP&T/boe expected to be reduced by more than 25% in 2019
• Gathering agreements eliminate >$2/bbl for trucking
Water pipeline system eliminates >$1/bbl trucking cost
30 mbo/d Central Production Facility coming online in 2Q’19
KEY DRIVERS
40% oil 40% oil 44% oil 47% oil
18. MARCELLUS
FOUNDATIONAL ASSET
Projected to generate ~$400mm in free cash flow(1)
Field optimized for spacing and lateral length
January 2019 gross production record
of 2.5 bcf/d
June 2019 Update 18
2019 TIL Schedule(2)
Overview
1Q’19 Production 158 mboe/d(3)
Net Acres ~540,000
2019 Activity(2)
Wells to Turn in Line 44
Rigs ~2.5
Frac Crews ~1
Total Capex (millions) $190 – $210
Production Mix(3)
Gas
100%
9
14
8
13
0
2
4
6
8
10
12
14
16
1Q'19 2Q'19E 3Q'19E 4Q'19E
(1) Free cash flow defined as net revenue less all operating costs and capital expenditure, excluding general and administrative and interest expense; Based on 5/8/19 Outlook
(2) 2019 Activity reflects 5/8/19 Outlook
(3) Represents average net production volumes for 1Q’19
19. LONGER LATERALS MAXIMIZING VALUE
Longer laterals driving down F&D costs and
delivering strong recovery per foot
Acreage position provides significant
long-lateral runway
• In 1Q’19, drilled the 1st 15k lateral in App North
• 15 wells >8,000' lateral length TIL’d in 2018
55% of the 2019 program will have >8,000'
lateral lengths
June 2019 Update 19
(1) Source: RS Energy Group
2
2.2
2.4
2.6
2.8
3
3.2
3.4
3.6
3.8
4
4,000' to 8,000' >8,000'
EUR (mmcf/ft) by Lateral Length
(1)
Achieving same EUR/ft with longer laterals
$0.00
$0.05
$0.10
$0.15
$0.20
$0.25
$0.30
$0.35
4,000' to 8,000' >8,000'
F&D ($/mcf) by Lateral Length
(1)
NICKOLYN 6HC
Avg 30 days: 37 mmcfd*
NICKOLYN 7HC
Avg 30 days: 36 mmcfd*
JOEGUSWA 4HC
Avg 30 days: 51 mmcfd*
JOEGUSWA 5HC
Avg 30 days: 40 mmcfd*
BOREK 104H
Avg 30 days: 37 mmcfd*
BOREK 2H
Avg 30 days: 38 mmcfd*
BOREK 4H
Avg 30 days: 40 mmcfd*
CANNELLA 24HC
Avg 30 days: 26 mmcfd*
CANNELLA 25HC
Avg 30 days: 20 mmcfd*
Lower Marcellus Well
Upper Marcellus Well
Lower Marcellus Core
Upper Marcellus Core
Lower Marcellus Core Expansion
*Average 30 days for non-zero production
Miles
20100
20. GULF COAST
CONSISTENT PERFORMANCE
Projected to generate ~$200mm in free cash flow(1)
Access to premium markets
Base optimization yielding significant results
June 2019 Update
2019 TIL Schedule(3)
Overview
1Q’19 Production 127 mboe/d(2)
Net Acres ~301,000
2019 Activity(3)
Wells to Turn in Line 24
Rigs ~2
Frac Crews ~1
Total Capex (millions) $130 – $150
Production Mix(2)
Gas
100%
20
10
9
5
0
2
4
6
8
10
12
1Q'19 2Q'19E 3Q'19E 4Q'19E
(1) Free cash flow defined as net revenue less all operating costs and capital expenditure, excluding general and administrative and interest expense; Based on 5/8/19 Outlook
(2) Represents average net production volumes for 1Q’19
(3) 2019 Activity reflects 5/8/19 Outlook
21. ADVANCING THE HAYNESVILLE FIELD
DEVELOPMENT PROGRAM
June 2019 Update 21
(1) JPIL wells TIL’d on 4/12/19
Lateral length designed for acreage footprint
and drilling risk mitigation
Completion, drill out and flowback optimized
for reservoir
Recent highlights
• Initial flowback results exceeding 80 mmcfd
for the two-well pad(1)
JPIL 1HC
Peak Rate: 47 mmcfd
Lateral Length: 12,500'
JPIL 2HC
Peak Rate: 34 mmcfd
Lateral Length: 10,000'
JPIL Wells
Springridge
Mansfield
Miles
20100
22. MID-CONTINENT
GROWTH OPTIONALITY
Redeployed capital to Powder River
Integrating new 3D data and recent appraisal
program results
High-grading 2020 and 2021 program
June 2019 Update
2019 TIL Schedule(2)
Overview
1Q’19 Production 24 mboe/d(1)
Net Acres ~764,000
2019 Activity(2)
Wells to Turn in Line 14
Rigs 0
Frac Crews ~1
Total Capex (millions) $75 – $95
Production Mix(1)
GasOil NGL
42%33% 25%
22
9
5
0
2
4
6
8
10
1Q'19 2Q'19E 3Q'19E 4Q'19E
(1) Represents average net production volumes for 1Q’19
(2) 2019 Activity reflects 5/8/19 Outlook
23. DIVERSE & STRONG PORTFOLIO
CORE POSITIONS ACROSS MULTIPLE BASINS
(1) As of 1Q’19
Marcellus: Foundational Asset
Mid-Continent: Growth Optionality
Powder River Basin: Oil Growth Engine
South Texas: Free Cash Flow Machine
Brazos Valley: Strategic Portfolio Addition
DAILY PRODUCTION AVERAGE(1)
~484 mboe
June 2019 Update 23
Gulf Coast: Consistent Performance
TOTAL 2019 PRODUCTION MIX(1)
Gas 70%
Oil 22%
NGL 8%
24. HEDGING POSITION
AS OF 5/3/19(1)
(1) Does not reflect April or May 2019 settlements
24June 2019 Update
W E I G H T E D A V E R A G E P R I C E
OIL Volume (mmbbl) Fixed Call ($ per bbl) Put
Swaps:
2019 17.4 $59.39
2020 11.4 $59.32
Collars:
2019 4.4 $67.75 $58.00
2020 1.8 $83.25 $65.00
Swaptions:
2020 4.4 $62.45
Puts:
2019 1.6 $54.08
Total 2019 23.4
Total 2020 17.6
NATURAL GAS Volume (bcf) Fixed Call ($ per mcf) Put
Swaps:
2019 344.0 $2.84
2020 250.1 $2.75
Three-way collars:
2019 66.0 $3.10 $2.50/$2.80
Collars:
2019 27.5 $2.91 $2.75
Swaptions:
2020 106.1 $2.77
Total 2019 437.5
Total 2020 356.2
24
25. BASIS HEDGES
AS OF 5/3/19(1)
June 2019 Update
(1) Does not reflect April or May 2019 settlements
25
CIG
2019: 8 bcf @ ($0.89) / mcf
HSC
2019: 19.3 bcf @ $0.03 / mcf
Argus Houston vs Argus WTI
2019: 3.4 mmbbls @ $5.16 / bbl
Argus LLS vs Argus WTI
2019: 2.7 mmbbls @ $6.20 / bbl
25
26. $302 $293
$451
$338
$850
$1,300 $1,319 $1,300
$1,250
$688
BVL
$1,222
CHK
$700
$0
$500
$1,000
$1,500
$2,000
$2,500
$3,000
2019 2020 2021 2022 2023 2024 2025 2026 2027
Unsecured
Convertibles
Revolving Credit Facility
BVL Unsecured
$millions
DEBT MATURITY PROFILE(1)
June 2019 Update 26
(1) As of 3/31/19 pro forma for settlement of the exchange transaction on 4/3/19 and maturity of the 2019 FRNs on 4/15/19 ($380mm FRN balance added to CHK’s 3/31/19 revolver balance of $842mm)
$1.9 billion
$1.2 billion CHK RCF
$688 million WRD RCF
$8.1 billion
Senior Notes
7.0%
WACD
27. CORPORATE INFORMATION
June 2019 Update 27
As of May 1, 2019
Headquarters
6100 N. Western Avenue
Oklahoma City, OK 73118
WEBSITE: www.chk.com
Corporate Contacts
BRAD SYLVESTER, CFA
Vice President – Investor Relations
and Communications
DOMENIC J. DELL’OSSO, JR.
Executive Vice President and
Chief Financial Officer
Investor Relations department
can be reached at ir@chk.com
Publicly Traded Securities Cusip Ticker
6.625% Senior Notes due 2020 #165167CF2 CHK20A
6.875% Senior Notes due 2020
#165167BU0
#165167BT3
#U16450AQ8
CHK20
6.125% Senior Notes Due 2021 #165167CG0 CHK21
5.375% Senior Notes Due 2021 #165167CK1 CHK21A
4.875% Senior Notes Due 2022 #165167CN5 CHK22
5.75% Senior Notes Due 2023 #165167CL9 CHK23
7.00% Senior Notes due 2024 #165167DA2 CHK24
8.00% Senior Notes due 2025
#165167CT2
#165167CU9
#U16450AU9
N/A
7.50% Senior Notes due 2026 #165167DB0 CHK26
8.00% Senior Notes due 2026
#165167DC8
#U16450AY1
N/A
8.00% Senior Notes due 2027
#165167CV7
#165167CZ8
N/A
5.50% Contingent Convertible Senior Notes due 2026 #165167CY1 N/A
4.5% Cumulative Convertible Preferred Stock #165167842 CHK PrD
5.0% Cumulative Convertible Preferred Stock (Series 2005B)
#165167834
#165167826
N/A
5.75% Cumulative Convertible Preferred Stock
#U16450204
#165167776
#165167768
N/A
5.75% Cumulative Convertible Preferred Stock (Series A)
#U16450113
#165167784
#165167750
N/A
Chesapeake Common Stock #165167107 CHK
Editor's Notes
Sheldon is most excited about:
Applying Chesapeake Efficiencies to Create Value
Strong Margins from Eagle Ford Development
Future Opportunity in Austin Chalk
Best-in-class operations
Long laterals & optimized completions driving value
Customized well spacing
Multi-zone potential
Proven and dependable Lower Eagle Ford
High potential Upper Eagle Ford and Austin Chalk
Original 3 bullet points in top left:
Consistent high-margin EBITDA delivery
~$520 million FCF in 2018
Multi-zone growth potential
Kevin’s 3 things he looks forward to in 2019:
Inventory growth through appraisal of AC and Upper Eagle Ford
IOR implementation
Overall efficiency gains and improvements in many aspects of the business as we continue to find ways to deliver better results (returns, capital efficiency, drilling performance, base optimization)
Original footnote below…don’t think we need it now that we have removed the y-axis from WFC chart and removed the yoy improvement chart.
Economics with $60 / $2.75, Invest diffs, 1018 capex model. Economics based on Rogers spacing test
Tim’s looking forward to the following things in 2019:
Tremendous Production Growth – 100% YOY w/ Additional Growth in ‘20
Positioned to Deliver – ~40 Wells of Learning Combined w/ Capital Efficiency
Proven Explorers with Enormous Growth Potential – Greater than 20 Horizons Identified
Best-In-Basin Production Results
Original 3 points in top left:
Production ramp ahead of schedule
Turner leads the way
Stacked pay with hotspot advantage
Cycle time & lateral length from DSO
Capex is weekly FE+ 7%
Staley- Can we start going to IP30 rates on callouts
Sheldon is most excited about:
Economical growth with ~400 million FCF in 2019
Enhancing value with long laterals and optimal spacing
Core expansion coupled with additional appraisal
Data set consists of 73 core wells TIL’s since 2016
Dave Bert’s top things to be excited about in 2019:
Strong well results with more great investments available:
58% ROR (Invest at $2.75); team is working to improve this significantly.
Excellent Capital and G&A efficiency
Strong EHS performance
Delivering large EBITDA with a small and efficient team (strong EBITDA/employee)
Deep future inventory & unrealized value
Bossier
Mansfield Haynesville
Modern fracs in legacy areas
Optimize lateral length, D&C to ensure delivery & maximize return
Base optimization:
Potential to drillout recent 10ks to full length
Current 10ks (where stick pipe is used) may be 15% above projection
Welltender
Original 3 bullet points:
Completion and drilling excellence redefines play
Expansive inventory
Access to premium markets
Rich’s bullet points for what he is excited about in 2019:
Looking forward and very excited in the future growth potential of the MidCon
Very excited to continue to be involved the transformation of CHK into the great company I have always believed it would be.