This document provides information about EOG Resources, Inc. It includes EOG's stock symbol and dividend, shares outstanding, investor relations contacts, copyright and risk disclaimer, and cautionary statements about forward-looking statements. The document also provides highlights about EOG's operations and financial results, including increasing its 2017-2020 oil growth outlook, raising its Delaware Basin resource estimate, exceeding US production guidance, and lowering per-unit expenses. Tables show increasing premium well locations and resource potential from the Delaware Basin.
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.
This document provides information about EOG Resources Inc. (EOG), including its stock symbol, common dividend amount, number of common shares outstanding, and investor relations contacts. It also contains legal disclaimers about forward-looking statements and non-GAAP financial measures, as well as brief statements about EOG being a U.S. leader in return on capital employed and oil growth, having among the lowest costs of production globally, and being committed to safety and the environment.
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.
Denbury Resources reported financial and operational results for the third quarter of 2016. Some key points:
- Total debt principal was reduced by $562 million year-to-date through open market debt purchases, debt exchanges, and a reduction in the bank credit facility balance.
- Adjusted net income was $1 million for the third quarter, compared to $29 million in the previous quarter.
- Average realized oil prices per barrel were $42.12 for the third quarter when including commodity derivative settlements, compared to $52.61 in the previous quarter.
- Total injected CO2 volumes averaged 459 million cubic feet per day for the third quarter, a 35% reduction from the previous quarter due
- 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
- EOG Resources Inc. is acquiring Yates Petroleum Corporation for $2.5 billion, adding 1.6 million net acres to its portfolio.
- The acquisition significantly increases EOG's core positions in the Delaware Basin, Powder River Basin, and Northwest Shelf, providing an additional 1,740 net premium drilling locations and estimated premium net resource potential of 1.6 billion barrels of oil equivalent.
- The transaction will be completed through the issuance of $2.3 billion in EOG equity and $151 million in cash and debt assumption, and is expected to close in early October.
This document provides information about EOG Resources, Inc. (EOG), an oil and gas exploration and production company. It includes EOG's stock symbol, dividend, shares outstanding, and investor relations contacts. The document also contains cautionary statements about forward-looking estimates and non-GAAP financial measures. Additionally, it summarizes EOG's strategy of focusing on premium wells that offer high rates of return even at low oil prices, and outlines EOG's plan to deliver double-digit oil production growth in 2017 through its premium drilling strategy.
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.
This document provides information about EOG Resources Inc. (EOG), including its stock symbol, common dividend amount, number of common shares outstanding, and investor relations contacts. It also contains legal disclaimers about forward-looking statements and non-GAAP financial measures, as well as brief statements about EOG being a U.S. leader in return on capital employed and oil growth, having among the lowest costs of production globally, and being committed to safety and the environment.
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.
Denbury Resources reported financial and operational results for the third quarter of 2016. Some key points:
- Total debt principal was reduced by $562 million year-to-date through open market debt purchases, debt exchanges, and a reduction in the bank credit facility balance.
- Adjusted net income was $1 million for the third quarter, compared to $29 million in the previous quarter.
- Average realized oil prices per barrel were $42.12 for the third quarter when including commodity derivative settlements, compared to $52.61 in the previous quarter.
- Total injected CO2 volumes averaged 459 million cubic feet per day for the third quarter, a 35% reduction from the previous quarter due
- 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
- EOG Resources Inc. is acquiring Yates Petroleum Corporation for $2.5 billion, adding 1.6 million net acres to its portfolio.
- The acquisition significantly increases EOG's core positions in the Delaware Basin, Powder River Basin, and Northwest Shelf, providing an additional 1,740 net premium drilling locations and estimated premium net resource potential of 1.6 billion barrels of oil equivalent.
- The transaction will be completed through the issuance of $2.3 billion in EOG equity and $151 million in cash and debt assumption, and is expected to close in early October.
This document provides information about EOG Resources, Inc. (EOG), an oil and gas exploration and production company. It includes EOG's stock symbol, dividend, shares outstanding, and investor relations contacts. The document also contains cautionary statements about forward-looking estimates and non-GAAP financial measures. Additionally, it summarizes EOG's strategy of focusing on premium wells that offer high rates of return even at low oil prices, and outlines EOG's plan to deliver double-digit oil production growth in 2017 through its premium drilling strategy.
The document provides an overview of Antero Resources Corporation. It notes that the presentation contains forward-looking statements regarding activities, events or developments that may occur in the future. It cautions that forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from expectations. The document also provides updates to slides since the last October 2016 presentation, including updated financial data, production guidance, and hedge positions.
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.
Sysco held its annual Investor Day, where it outlined its growth strategy through fiscal 2024. Sysco plans to grow substantially faster than the market through five strategic pillars: digital, products, solutions, supply chain, and customer teams. Sysco also announced a large acquisition that will help cultivate new channels and capabilities. Sysco expects to grow 1.5 times faster than the total foodservice market by executing on its strategic plan.
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.
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.
This document provides an investor presentation for Devon Energy Corporation (DVN). It summarizes DVN's operations in the STACK and Delaware Basins, where it has over 30,000 potential locations across the two plays. DVN is focused on expanding high-margin production from these core areas to drive rapid cash flow growth. The presentation outlines DVN's strategic vision to optimize its portfolio and balance sheet through 2020 to improve returns and deliver top-tier value to shareholders.
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.
- 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.
The document summarizes AREX's first quarter 2016 results. It discusses:
- Drilling of 4 Wolfcamp wells on time and on budget during the quarter with no completions.
- Production of 1,165 Mboe during the quarter as no new wells were completed.
- EBITDAX of $8.7 million and cash flow from operations of $5.3 million for the quarter. Capital expenditures were $4.9 million.
- The company maintains a strong financial position and liquidity of $54 million providing flexibility for its 2016 plan.
China Gold International Resources reported record breaking financial results in Q3 2020. Revenues increased 29% year-over-year to $240.5 million, net income soared to $47.6 million, and EBITDA reached $103 million. Production also rose, with gold output up 12% and copper production increasing 31% compared to the same period last year. The company has benefited from strong operational performance as well as financial and technical support from its major shareholder, China National Gold Group, one of China's largest gold producers. China Gold International maintains an investment grade credit rating of BBB- from S&P.
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 provides an overview of a partnership between Antero Midstream Partners LP and Antero Resources Corporation. It contains forward-looking statements regarding future plans, strategies, objectives, and anticipated financial and operating results. These statements are based on certain assumptions and are subject to risks and uncertainties that could cause actual results to differ materially. The ability to make future distributions is substantially dependent on Antero Resources' development and drilling plan, which is dependent on its annual capital budget approval.
This document provides a summary and overview of New Zealand Energy Corp's proposed acquisition of oil and gas assets in Taranaki Basin, New Zealand from Origin Energy. Some of the key points include:
1) NZEC will acquire producing oil and gas fields and a production facility for $33.5 million, to be paid through a combination of cash and a joint venture with L&M Energy.
2) The acquisition will add over 1 million barrels of oil equivalent in reserves and increase projected production to over 2,300 barrels of oil equivalent per day.
3) NZEC plans to undertake work programs on the acquired assets focused on reactivating existing wells and drilling new wells to access identified reserves
This document provides an overview of Denbury Resources Inc. (NYSE: DNR), an oil and gas company focused on enhanced oil recovery using carbon dioxide (CO2) flooding. Some key points:
- DNR owns over 1,100 miles of CO2 pipelines and has produced over 155 million gross barrels from CO2 EOR projects to date.
- DNR's two core CO2 EOR target areas in the Gulf Coast and Rocky Mountain regions have an estimated recoverable potential of up to 16 billion gross barrels.
- DNR's 2017 capital budget is approximately $300 million, focused on expanding existing CO2 floods and other projects. Production is expected to remain relatively flat in 2017 compared to
The document discusses Crestwood Midstream Partners LP and Crestwood Equity Partners LP. It provides an investor presentation covering key highlights, including 2016 guidance being on track, a focused growth strategy, a strong balance sheet, and significant insider ownership. It summarizes recent financial results and outlines the company's long-term outlook, focusing on growth opportunities in the Delaware Permian Basin, Northeast Marcellus shale, and Bakken shale plays.
Franklin Resources reported second quarter results for fiscal year 2017. Total revenue was $1.6 billion for the quarter, generating $556 million in operating income. Diluted earnings per share were $0.74. Relative investment performance has rebounded for many strategies, with 84% of equity and hybrid fund assets in the top two quartiles for the past year. Sales increased over 24% from the previous quarter, driven by a significant improvement in retail channels, particularly offshore where net flows turned positive. The company also announced organizational changes to strengthen its investment capabilities and better meet evolving client needs.
This document provides an investor presentation for Crestwood Midstream Partners LP and Crestwood Equity Partners LP. It highlights key points such as 2016 guidance being on track, a focused growth strategy in core areas like the Delaware Permian and Bakken, a strong balance sheet and distribution coverage. It summarizes growth opportunities and projects in these regions that are expected to provide accretive cash flow growth beginning in 2018.
This document provides an overview of Antero Resources Corporation. It begins with forward-looking statements and disclosures, noting that the document contains projections that may not come to pass. It then provides updates to slides presented in a prior September 2016 presentation, including improved well economics from lower costs and longer laterals, higher estimated ultimate recoveries, and updated financial information. The document highlights Antero's large core acreage position, growing production and improving well returns, leading realized prices due to premium sales contracts, and strong balance sheet with significant liquidity. It presents Antero as well positioned for sustainable growth in the Appalachian basin.
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.
The document is an investor presentation for Sunoco LP (SUN) that provides an overview of the company. It discusses SUN's recent acquisitions that have increased its scale and diversified its operations across 30 states. It highlights SUN's leading retail and wholesale fuel business, real estate portfolio of over 2,000 sites, and financial strategy targeting investment grade ratings. The presentation also provides an operating performance summary for the second quarter of 2016 that shows increased retail fuel margins and merchandise sales growth compared to the prior year.
This document provides contact information for Devon Energy's investor relations team. It also includes standard legal disclaimers about forward-looking statements and the use of non-GAAP financial measures in company presentations. The document highlights Devon's high-quality asset portfolio, with a focus on increasing activity and investment in the STACK and Delaware Basin plays to deliver production and cash flow growth.
EOG Resources reported successful results from its enhanced oil recovery project in the Eagle Ford, exceeding its US oil production forecast for the first quarter of 2016. It also announced an established Austin Chalk play overlaying its South Texas Eagle Ford acreage. EOG increased its 2016 US oil production forecast by 2% while reducing expected capital expenditures by 47% and lowering operating and general and administrative expenses. It achieved significant well cost reductions through efficiency improvements and pricing.
The document provides an overview of Antero Resources Corporation. It notes that the presentation contains forward-looking statements regarding activities, events or developments that may occur in the future. It cautions that forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from expectations. The document also provides updates to slides since the last October 2016 presentation, including updated financial data, production guidance, and hedge positions.
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.
Sysco held its annual Investor Day, where it outlined its growth strategy through fiscal 2024. Sysco plans to grow substantially faster than the market through five strategic pillars: digital, products, solutions, supply chain, and customer teams. Sysco also announced a large acquisition that will help cultivate new channels and capabilities. Sysco expects to grow 1.5 times faster than the total foodservice market by executing on its strategic plan.
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.
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.
This document provides an investor presentation for Devon Energy Corporation (DVN). It summarizes DVN's operations in the STACK and Delaware Basins, where it has over 30,000 potential locations across the two plays. DVN is focused on expanding high-margin production from these core areas to drive rapid cash flow growth. The presentation outlines DVN's strategic vision to optimize its portfolio and balance sheet through 2020 to improve returns and deliver top-tier value to shareholders.
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.
- 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.
The document summarizes AREX's first quarter 2016 results. It discusses:
- Drilling of 4 Wolfcamp wells on time and on budget during the quarter with no completions.
- Production of 1,165 Mboe during the quarter as no new wells were completed.
- EBITDAX of $8.7 million and cash flow from operations of $5.3 million for the quarter. Capital expenditures were $4.9 million.
- The company maintains a strong financial position and liquidity of $54 million providing flexibility for its 2016 plan.
China Gold International Resources reported record breaking financial results in Q3 2020. Revenues increased 29% year-over-year to $240.5 million, net income soared to $47.6 million, and EBITDA reached $103 million. Production also rose, with gold output up 12% and copper production increasing 31% compared to the same period last year. The company has benefited from strong operational performance as well as financial and technical support from its major shareholder, China National Gold Group, one of China's largest gold producers. China Gold International maintains an investment grade credit rating of BBB- from S&P.
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 provides an overview of a partnership between Antero Midstream Partners LP and Antero Resources Corporation. It contains forward-looking statements regarding future plans, strategies, objectives, and anticipated financial and operating results. These statements are based on certain assumptions and are subject to risks and uncertainties that could cause actual results to differ materially. The ability to make future distributions is substantially dependent on Antero Resources' development and drilling plan, which is dependent on its annual capital budget approval.
This document provides a summary and overview of New Zealand Energy Corp's proposed acquisition of oil and gas assets in Taranaki Basin, New Zealand from Origin Energy. Some of the key points include:
1) NZEC will acquire producing oil and gas fields and a production facility for $33.5 million, to be paid through a combination of cash and a joint venture with L&M Energy.
2) The acquisition will add over 1 million barrels of oil equivalent in reserves and increase projected production to over 2,300 barrels of oil equivalent per day.
3) NZEC plans to undertake work programs on the acquired assets focused on reactivating existing wells and drilling new wells to access identified reserves
This document provides an overview of Denbury Resources Inc. (NYSE: DNR), an oil and gas company focused on enhanced oil recovery using carbon dioxide (CO2) flooding. Some key points:
- DNR owns over 1,100 miles of CO2 pipelines and has produced over 155 million gross barrels from CO2 EOR projects to date.
- DNR's two core CO2 EOR target areas in the Gulf Coast and Rocky Mountain regions have an estimated recoverable potential of up to 16 billion gross barrels.
- DNR's 2017 capital budget is approximately $300 million, focused on expanding existing CO2 floods and other projects. Production is expected to remain relatively flat in 2017 compared to
The document discusses Crestwood Midstream Partners LP and Crestwood Equity Partners LP. It provides an investor presentation covering key highlights, including 2016 guidance being on track, a focused growth strategy, a strong balance sheet, and significant insider ownership. It summarizes recent financial results and outlines the company's long-term outlook, focusing on growth opportunities in the Delaware Permian Basin, Northeast Marcellus shale, and Bakken shale plays.
Franklin Resources reported second quarter results for fiscal year 2017. Total revenue was $1.6 billion for the quarter, generating $556 million in operating income. Diluted earnings per share were $0.74. Relative investment performance has rebounded for many strategies, with 84% of equity and hybrid fund assets in the top two quartiles for the past year. Sales increased over 24% from the previous quarter, driven by a significant improvement in retail channels, particularly offshore where net flows turned positive. The company also announced organizational changes to strengthen its investment capabilities and better meet evolving client needs.
This document provides an investor presentation for Crestwood Midstream Partners LP and Crestwood Equity Partners LP. It highlights key points such as 2016 guidance being on track, a focused growth strategy in core areas like the Delaware Permian and Bakken, a strong balance sheet and distribution coverage. It summarizes growth opportunities and projects in these regions that are expected to provide accretive cash flow growth beginning in 2018.
This document provides an overview of Antero Resources Corporation. It begins with forward-looking statements and disclosures, noting that the document contains projections that may not come to pass. It then provides updates to slides presented in a prior September 2016 presentation, including improved well economics from lower costs and longer laterals, higher estimated ultimate recoveries, and updated financial information. The document highlights Antero's large core acreage position, growing production and improving well returns, leading realized prices due to premium sales contracts, and strong balance sheet with significant liquidity. It presents Antero as well positioned for sustainable growth in the Appalachian basin.
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.
The document is an investor presentation for Sunoco LP (SUN) that provides an overview of the company. It discusses SUN's recent acquisitions that have increased its scale and diversified its operations across 30 states. It highlights SUN's leading retail and wholesale fuel business, real estate portfolio of over 2,000 sites, and financial strategy targeting investment grade ratings. The presentation also provides an operating performance summary for the second quarter of 2016 that shows increased retail fuel margins and merchandise sales growth compared to the prior year.
This document provides contact information for Devon Energy's investor relations team. It also includes standard legal disclaimers about forward-looking statements and the use of non-GAAP financial measures in company presentations. The document highlights Devon's high-quality asset portfolio, with a focus on increasing activity and investment in the STACK and Delaware Basin plays to deliver production and cash flow growth.
EOG Resources reported successful results from its enhanced oil recovery project in the Eagle Ford, exceeding its US oil production forecast for the first quarter of 2016. It also announced an established Austin Chalk play overlaying its South Texas Eagle Ford acreage. EOG increased its 2016 US oil production forecast by 2% while reducing expected capital expenditures by 47% and lowering operating and general and administrative expenses. It achieved significant well cost reductions through efficiency improvements and pricing.
The document is a company overview for Antero Resources Corporation from July 2016. It discusses Antero's acquisition of 68,000 net acres and 5.1 trillion cubic feet of reserves for $558 million. This significantly increases Antero's core drilling inventory and positions the company for long-term production growth. The acquisition also enhances Antero's dry gas optionality and increases dedication of acreage to Antero Midstream. The economics of wells on the acquired acreage are attractive, with estimated returns of 51% to 77% at current strip prices.
The document provides an overview of Antero Resources Corporation. It notes that the presentation contains forward-looking statements regarding activities, events or developments that may occur in the future. It cautions that these forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from expectations. The document then provides details on Antero's market capitalization, net debt, production levels, reserve estimates, and acreage holdings.
The document provides an overview of Antero Resources Corporation. It notes that the company has a market capitalization of $8.5 billion and net production of 1,875 MMcfe/d. It also contains forward-looking statements regarding Antero's estimates and plans. These include estimates of reserves, production growth targets, drilling plans, and expected realized natural gas prices. The document highlights Antero's leading well economics in the Marcellus, including lower costs and higher estimated ultimate recoveries. It also summarizes Antero's substantial natural gas hedge portfolio, which locks in prices significantly above current strip.
Company website presentation (a) september 2016AnteroResources
The document provides an overview of Antero Resources Corporation. It begins with forward-looking statements and disclaimers about projections. It then notes that the company has updated its 2016 production and operating cost guidance, increasing projected growth to 20% and lowering costs. The acquisition of additional acreage from a third party is discussed, which adds over 66,000 net acres and over 5 trillion cubic feet of reserves. This significantly increases Antero's core drilling locations and provides growth for its midstream subsidiary, Antero Midstream. The economics of developing the acquired acreage are attractive, with projected returns of 51-77% depending on gas prices.
Company website presentation (b) october 2016AnteroResources
The document provides an overview of Antero Resources Corporation. It notes that Antero has a large net acreage position of over 629,000 acres and over 42 trillion cubic feet of estimated reserves. It also highlights Antero's leading well economics, driven by drilling longer laterals and more intensive completions that have increased estimated ultimate recoveries. Antero has significant located drilling inventory and the financial strength to continue developing its acreage inventory.
Barclays conference presentation (website) september 2016 v5AnteroResources
This document provides guidance and forward-looking statements from Antero Resources Corporation regarding its operations and financial outlook. Some of the key points include:
- Revised 2016 total production guidance of 1.8 Bcfe/d, an increase from previous guidance of 1.75 Bcfe/d.
- Estimated net income range for 2016 of $205-225 million, an increase from the previous estimate of $165-190 million.
- Capital budget for 2016 remains at $1.4 billion to drill 110 wells while maintaining production growth of 20-25% annually through 2020.
- The company has significant liquidity and a large drilling inventory that positions it to capitalize on growing natural
This corporate presentation by Denbury Resources provides an overview of the company's CO2 enhanced oil recovery (EOR) business. Some key points:
- Denbury focuses on CO2 EOR, owning significant CO2 reserves and over 1,100 miles of pipelines to transport CO2 for injection.
- The company's assets have substantial long-term EOR resource potential estimated at 890 million barrels recoverable.
- In response to low oil prices, Denbury is focusing on reducing costs, optimizing operations, reducing debt, and preserving cash and liquidity.
- The company has ample CO2 supply for EOR operations with no significant capital required for several years.
Company website presentation (a) december 2016AnteroResources
The document provides an overview of Antero Resources Corporation. It notes that the presentation contains forward-looking statements and describes various risk factors that could affect Antero's actual results. It then provides highlights of Antero's profile, including its market capitalization, enterprise value, reserves, production rates, and acreage position. The document emphasizes Antero's strong balance sheet, leading realized prices and margins, improving well economics, and large drilling inventory.
Company website presentation (a) february 2017AnteroResources
The document provides an overview of Antero Resources Corporation. Some key points:
- It contains forward-looking statements regarding estimates, plans, expectations and guidance that are subject to risks and uncertainties.
- As of February 2017, Antero has a market capitalization of $8.2 billion and net production of 1,875 MMcfe/d that is 26% liquids. It holds 624,000 net acres of land.
- In 2016, Antero grew its proved reserves by 16% to 15.4 Tcfe and its 3P reserves by 25% to 46.4 Tcfe through acquisitions and successful drilling, establishing an outstanding drilling inventory for long-term growth.
Company website presentation (b) february 2017AnteroResources
The document provides an overview of Antero Resources Corporation. It contains forward-looking statements regarding estimates, plans, expectations and guidance. It also cautions that actual results could differ materially from forward-looking statements due to risks and uncertainties. The document then provides details on Antero's market capitalization, reserves, production, drilling inventory, and long-term growth outlook through 2020. Antero plans annual production growth and decreasing leverage while maintaining a substantial inventory of drilling locations with attractive economics.
Company website presentation (c) february 2017AnteroResources
The document provides an overview of Antero Resources Corporation. It contains forward-looking statements regarding estimates, plans, expectations and guidance. It also cautions that actual results could differ materially from forward-looking statements due to risks and uncertainties. The document then provides details on Antero's market capitalization, reserves, production, acreage position, and drilling inventory to support long-term growth plans. Antero has over 8,000 potential drilling locations that provide multi-year development opportunities on its large, consolidated acreage position in the Marcellus and Utica shale plays.
- The document is a presentation by Antero Resources Corporation that contains forward-looking statements about Antero's estimates, plans, expectations and guidance.
- It provides Antero's market capitalization, enterprise value, recent liquidity events, and reserves and acreage positions as well as production and financial metrics.
- The presentation outlines Antero's 2017 capital budget and guidance, and long-term targets for production growth, leverage, hedging and cash flow that aim to double production by 2020 while maintaining financial strength.
Credit suisse conference presentation february 2017 v-fAnteroResources
The document provides forward-looking statements and guidance for Antero Resources Corporation. It summarizes Antero's 2016 reserve growth which saw proved reserves increase 16% to 15.4 trillion cubic feet equivalent and 3P reserves increase 25% to 46.4 trillion cubic feet equivalent. The document also announces a new joint venture between Antero Midstream and MPLX for natural gas processing and fractionation in Appalachia, providing long-term growth opportunities through 2020. Finally, it provides Antero's 2017 guidance which calls for production growth to 2.2 billion cubic feet equivalent per day, D&C capital of $1.3 billion, and modest annual increases in cash flow from operations within cash flow from operations.
The document provides an overview of Antero Resources Corporation. It contains forward-looking statements regarding estimates, expectations, plans, strategies and guidance. It cautions that forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from expectations. The document also provides an overview of Antero's market capitalization, reserves, production, acreage position, and 2017 guidance including planned capital expenditures, production growth targets, and hedging percentages.
This document provides an overview of Antero Resources Corporation. It contains forward-looking statements regarding Antero's estimates, plans, strategies, objectives, anticipated financial and operating results. These statements are based on certain assumptions and are subject to risks and uncertainties. The document also cautions that forward-looking statements are subject to difficulties in predicting Antero's future results. It provides updated information on Antero's balance sheet, liquidity, production growth targets, and reserve additions as of the end of 2016.
- Denbury is an oil and gas company focused on CO2 enhanced oil recovery (CO2 EOR) with over 155 million barrels of oil produced from CO2 EOR.
- It has proved reserves of 254 million barrels of oil equivalent (58% from CO2 EOR) and estimated potential reserves of around 800 million barrels.
- In the fourth quarter of 2016, Denbury produced over 60,000 barrels of oil equivalent per day (62% from CO2 EOR).
- For 2017, Denbury expects relatively flat production from 2016 and has budgeted $300 million primarily for expanding existing CO2 floods.
- SandRidge Energy has built a portfolio focused on three project areas: Mississippian, NW STACK, and North Park Niobrara
- The presentation highlights recent well results and cost reductions in each area that have improved economics and supported continued development
- SandRidge has over $500 million in liquidity and a long drilling inventory across the projects to support its future investment and growth plans
This document provides information about EOG Resources, Inc. It includes EOG's stock symbol and dividend, shares outstanding, website and investor relations contacts. It also contains cautionary statements regarding forward-looking statements and assumptions of risk. The document notes that EOG is shifting capital to premium locations that generate over 30% returns even at $40/barrel oil. It also discusses growing premium well inventory, increasing capital productivity, and maintaining a strong balance sheet while focusing on returns.
This document provides information about EOG Resources (EOG), including its stock symbol, common dividend, shares outstanding, and investor relations contacts. It also contains cautionary statements regarding forward-looking estimates and non-GAAP financial measures. EOG exceeded its 2017 production targets and delivered expenses below targets while reducing costs in several basins. EOG has also achieved $175 million in asset sale proceeds so far this year.
This document provides information about EOG Resources, Inc. (EOG), an oil and gas exploration and production company. It lists EOG's stock symbol and dividend, shares outstanding, and investor relations contacts. It also contains cautionary statements about forward-looking estimates and reserves, describes EOG's strategy of focusing on high-return oil growth through premium drilling locations and technological advantages, and provides production and well performance data to demonstrate EOG's leading position.
EOG Resources Inc. is an oil and gas exploration and production company with stock symbol EOG trading on the NYSE. It pays a quarterly dividend of $0.67 per share and has 550 million shares outstanding. The document provides contact information for EOG's investor relations department and cautions that any forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially. It also notes that some reserve estimates disclosed may include probable and possible reserves not calculated according to SEC guidelines.
- Quattro Exploration and Production Ltd is an oil and gas producer focused on three core regions in Western Canada.
- The company's goal is to increase production from 3,000 boe/d in June 2016 to 6,000 boe/d by December 2016 through development of existing assets.
- Quattro has over 300 identified drilling locations across its regions and operated infrastructure to provide economies of scale.
Quattro Exploration and Production Ltd. is a profitable, low cost oil and gas producer operating in Canada and Guatemala. Some key points:
- Acquired oil and gas properties in Saskatchewan, Canada and a license in Guatemala, expanding its land base and estimated recoverable resources.
- Entered discussions with a tier one lender for a $20 million term facility at a low interest rate.
- Closed the purchase of SRD Innovations Inc., anticipating annual cost savings from eliminating alternative services.
This corporate presentation summarizes New Zealand Energy Corp's growth strategy of acquiring and exploring new assets. It highlights a proposed transformative acquisition of petroleum licenses and assets from Origin Energy that would significantly increase NZEC's reserves and resource potential. The acquisition is made more attractive through the formation of a joint venture with L&M Energy that reduces costs and simplifies terms. If completed, the acquisition would nearly double NZEC's proved and probable reserves. However, the presentation notes that the acquisition and its benefits are subject to regulatory approval and meeting financing conditions.
The document discusses National Fuel Gas Company's assets and operations across its Exploration & Production, Midstream, and Downstream segments. It highlights the company's:
- 2.3 Tcfe of proved reserves and 785,000 net acres in the Marcellus Shale
- $267 million in annual adjusted EBITDA across its balanced portfolio
- Strong balance sheet and $1.36 billion in liquidity as of June 30, 2016
- Opportunities for significant growth through its Appalachian acreage position and coordinated infrastructure build-out
Penn Virginia Corporation is acquiring Eagle Ford Hunter, Inc. (MHR) for $400 million. The acquisition significantly increases Penn Virginia's Eagle Ford position by expanding its acreage to approximately 83,000 net acres across Gonzales and Lavaca Counties. The MHR assets add over 12 million barrels of oil equivalent of proved reserves and 345 gross drilling locations. The acquisition transforms Penn Virginia's asset profile by increasing its Eagle Ford net acreage from 10% to 54%, net inventory from 28% to 68%, and proved developed reserves from 20% to 42%.
The document discusses Teck Resources' proposed full sale of its steelmaking coal business to Glencore, Nippon Steel Corporation, and POSCO. Key points:
- Glencore will acquire a 77% stake in Elk Valley Resources for $9 billion. NSC will acquire a 20% stake for $8.5 billion. POSCO will exchange interests for a 3% stake.
- Total proceeds to Teck are estimated at $9.6 billion, including $1 billion in interim cash flows retained by Teck until closing.
- Teck will use proceeds to strengthen its balance sheet, return cash to shareholders, and fund its copper growth portfolio.
- The transaction supports Teck's strategy of
This corporate presentation from New Zealand Energy Corp outlines their plans to increase production and cash flow from their assets in New Zealand. It summarizes that NZEC has acquired additional permits increasing their reserves by 150% and now owns a full-cycle production facility. It details NZEC's planned work program to reactivate existing wells in the Tikorangi formation and undertake uphole completions and drill new wells in the Mt Messenger formation between late 2013 and 2014. Forecasts indicate this could increase NZEC's production and cash flow significantly by the end of 2014. The presentation also provides an overview of NZEC's other permit areas and conventional and unconventional resource potential across their lands.
The document provides an investor presentation for a global metals and mining conference. It summarizes Teck's proposed sale of its steelmaking coal business to Glencore and other parties for total implied proceeds of $8.9 billion. Teck will retain interim cash flows from the business until the sale's expected closing in Q3 2024. Teck plans to use the proceeds to strengthen its balance sheet, return cash to shareholders, and position itself to realize value from its copper growth portfolio. The presentation also outlines Teck's strategy to focus on near-term development options for its copper assets that have lower scope and complexity than its recent Quebrada Blanca project.
APPLYING ARTIFICIAL INTELLIGENCE TO IMPROVE PIPELINE INTEGRITYiQHub
Petro Lucrum is applying artificial intelligence to improve pipeline integrity by using data optics like drones and cameras to provide predictive maintenance and detect issues like corrosion and cracks. AI automation can improve safety, efficiency and reduce human errors by providing automated detection and optimizing pipeline integrity. While current technologies are limited, AI integration has potential benefits but also implementation challenges to overcome.
This corporate presentation from New Zealand Energy Corp outlines their plans to increase oil production and cash flow from their assets in the Taranaki Basin of New Zealand. Key points include:
- Reactivating existing wells to produce from the proven Tikorangi formation, with an expected 780 bbl/d of net production to NZEC by the end of 2014.
- Conducting uphole completions and drilling new wells in the Mt. Messenger formation, with an expected 575 bbl/d of net production to NZEC by the end of 2014.
- Drilling two new wells in the Tikorangi formation, expected to add 570 bbl/d of net production
BMO Global Metals, Mining & Critical Minerals conferenceTeckResourcesLtd
The document is a presentation from the Global Metals and Mining Conference on February 26, 2024 by Jonathan Price, President and CEO of Global Metals. It discusses Teck's strategy to maximize long-term shareholder value by capitalizing on strong demand for metals in the transition to a low-carbon economy through sustainability leadership, balancing growth and returns to shareholders, unlocking value from copper growth projects, and operational excellence. Teck is a leading base metals producer, ranking among the top 10 copper producers in the Americas and as the largest net zinc miner globally, operating mines like Highland Valley Copper, Antamina, and Quebrada Blanca.
Global Metals and Mining Conference Investor Presentation provides an overview and outlook for Teck Resources. Key points include:
Teck aims to maximize long-term shareholder value through industry-leading copper growth, operational excellence, and balancing growth investments with cash returns to shareholders. Production guidance is provided for 2024-2027 with significant near-term copper growth from Quebrada Blanca ramping up. Capital expenditures are estimated between $2.4-2.9 billion Canadian dollars for 2024 with a focus on advancing the copper growth pipeline. Teck maintains a disciplined capital allocation framework to fund growth while returning a minimum of 30% of available cash flow to shareholders.
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Eog 1116
1. NYSE Stock Symbol: EOG
Common Dividend: $0.67
Basic Shares Outstanding: 576 Million
Internet Address:
http://www.eogresources.com
3Q 2016
Investor Relations Contacts
Cedric W. Burgher, SVP Investor & Public Relations
(713) 571-4658, cburgher@eogresources.com
Kimberly M. Ehmer, Director IR/PR
(713) 571-4676, kehmer@eogresources.com
David J. Streit, Director IR
(713) 571-4902, dstreit@eogresources.com
2. Copyright; Assumption of Risk: Copyright 2016. This presentation and the contents of this presentation have been copyrighted by EOG Resources, Inc. (EOG). All rights reserved. Copying of the presentation is
forbidden without the prior written consent of EOG. Information in this presentation is provided “as is” without warranty of any kind, either express or implied, including but not limited to the implied warranties of
merchantability, fitness for a particular purpose and the timeliness of the information. You assume all risk in using the information. In no event shall EOG or its representatives be liable for any special, indirect or
consequential damages resulting from the use of the information.
Cautionary Notice Regarding Forward-Looking Statements: This presentation 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 facts, including, among others, statements and projections regarding EOG's future financial position, operations,
performance, business strategy, returns, budgets, reserves, levels of production and costs, statements regarding future commodity prices and statements regarding the plans and objectives of EOG's management for
future operations, are forward-looking statements. EOG typically uses words such as "expect," "anticipate," "estimate," "project," "strategy," "intend," "plan," "target," "goal," "may," "will," "should" and "believe" or the
negative of those terms or other variations or comparable terminology to identify its forward-looking statements. In particular, statements, express or implied, concerning EOG's future operating results and returns or
EOG's ability to replace or increase reserves, increase production, reduce or otherwise control operating and capital costs, generate income or cash flows or pay dividends are forward-looking statements. Forward-
looking statements are not guarantees of performance. Although EOG believes the expectations reflected in its forward-looking statements are reasonable and are based on reasonable assumptions, no assurance can be
given that these assumptions are accurate or that any of these expectations will be achieved (in full or at all) or will prove to have been correct. Moreover, EOG's forward-looking statements may be affected by known,
unknown or currently unforeseen risks, events or circumstances that may be outside EOG's control. Important factors that could cause EOG's actual results to differ materially from the expectations reflected in EOG's
forward-looking statements include, among others:
• the timing, extent and duration of changes in prices for, supplies of, and demand for, crude oil and condensate, natural gas liquids, natural gas and related commodities;
• the extent to which EOG is successful in its efforts to acquire or discover additional reserves;
• the extent to which EOG is successful in its efforts to economically develop its acreage in, produce reserves and achieve anticipated production levels from, and maximize reserve recovery from, its existing and future
crude oil and natural gas exploration and development projects;
• the extent to which EOG is successful in its efforts to market its crude oil and condensate, natural gas liquids, natural gas and related commodity production;
• the availability, proximity and capacity of, and costs associated with, appropriate gathering, processing, compression, transportation and refining facilities;
• the availability, cost, terms and timing of issuance or execution of, and competition for, mineral licenses and leases and governmental and other permits and rights-of-way, and EOG’s ability to retain mineral licenses
and leases;
• the impact of, and changes in, government policies, laws and regulations, including tax laws and regulations; environmental, health and safety laws and regulations relating to air emissions, disposal of produced
water, drilling fluids and other wastes, hydraulic fracturing and access to and use of water; laws and regulations imposing conditions or restrictions on drilling and completion operations and on the transportation of
crude oil and natural gas; laws and regulations with respect to derivatives and hedging activities; and laws and regulations with respect to the import and export of crude oil, natural gas and related commodities;
• EOG's ability to effectively integrate acquired crude oil and natural gas properties into its operations, fully identify existing and potential problems with respect to such properties and accurately estimate reserves,
production and costs with respect to such properties;
• the extent to which EOG's third-party-operated crude oil and natural gas properties are operated successfully and economically;
• competition in the oil and gas exploration and production industry for the acquisition of licenses, leases and properties, employees and other personnel, facilities, equipment, materials and services;
• the availability and cost of employees and other personnel, facilities, equipment, materials (such as water) and services;
• the accuracy of reserve estimates, which by their nature involve the exercise of professional judgment and may therefore be imprecise;
• weather, including its impact on crude oil and natural gas demand, and weather-related delays in drilling and in the installation and operation (by EOG or third parties) of production, gathering, processing, refining,
compression and transportation facilities;
• the ability of EOG's customers and other contractual counterparties to satisfy their obligations to EOG and, related thereto, to access the credit and capital markets to obtain financing needed to satisfy their
obligations to EOG;
• EOG's ability to access the commercial paper market and other credit and capital markets to obtain financing on terms it deems acceptable, if at all, and to otherwise satisfy its capital expenditure requirements;
• the extent and effect of any hedging activities engaged in by EOG;
• the timing and extent of changes in foreign currency exchange rates, interest rates, inflation rates, global and domestic financial market conditions and global and domestic general economic conditions;
• political conditions and developments around the world (such as political instability and armed conflict), including in the areas in which EOG operates;
• the use of competing energy sources and the development of alternative energy sources;
• the extent to which EOG incurs uninsured losses and liabilities or losses and liabilities in excess of its insurance coverage;
• acts of war and terrorism and responses to these acts;
• physical, electronic and cyber security breaches; and
• the other factors described under ITEM 1A, Risk Factors, on pages 13 through 21 of EOG’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015 and any updates to those factors set forth in EOG's
subsequent Quarterly Reports on Form 10-Q or Current Reports on Form 8-K.
In light of these risks, uncertainties and assumptions, the events anticipated by EOG's forward-looking statements may not occur, and, if any of such events do, we may not have anticipated the timing of their occurrence
or the duration and extent of their impact on our actual results. Accordingly, you should not place any undue reliance on any of EOG's forward-looking statements. EOG's forward-looking statements speak only as of the
date made, and EOG undertakes no obligation, other than as required by applicable law, to update or revise its forward-looking statements, whether as a result of new information, subsequent events, anticipated or
unanticipated circumstances or otherwise.
Oil and Gas Reserves; Non-GAAP Financial Measures: The United States Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose not only “proved” reserves
(i.e., quantities of oil and gas that are estimated to be recoverable with a high degree of confidence), but also “probable” reserves (i.e., quantities of oil and gas that are as likely as not to be recovered) as well as
“possible” reserves (i.e., additional quantities of oil and gas that might be recovered, but with a lower probability than probable reserves). Statements of reserves are only estimates and may not correspond to the
ultimate quantities of oil and gas recovered. Any reserve estimates provided in this presentation that are not specifically designated as being estimates of proved reserves may include "potential" reserves and/or other
estimated reserves not necessarily calculated in accordance with, or contemplated by, the SEC’s latest reserve reporting guidelines. Investors are urged to consider closely the disclosure in EOG’s Annual Report on
Form 10-K for the fiscal year ended December 31, 2015, available from EOG at P.O. Box 4362, Houston, Texas 77210-4362 (Attn: Investor Relations). You can also obtain this report from the SEC by calling 1-800-SEC-0330
or from the SEC's website at www.sec.gov. In addition, reconciliation and calculation schedules for non-GAAP financial measures can be found on the EOG website at www.eogresources.com.
3. EOG _1116-3
Raised 2017-2020 Oil Growth Outlook to 15%-25% CAGR
Increased Delaware Basin Resource Estimate 155% to 6.0 BnBoe*
Exceeded High End of All U.S. Production Guidance Ranges
Reduced Per-Unit Lease and Well Expense 18% YoY
3Q 2016
Increased 2016 U.S. Oil Production Forecast 3%**
Lowered 2016 LOE and Transportation Expense Forecast**
Generated $625 Million Proceeds from Asset Sales YTD
Increased 2016 Capex Forecast by $200 Million to $2.6-$2.8 Billion**
Drilling 90 More and Completing 180 More Net Wells vs. Original Plan
- Complete 450 and Drill 290 Net Wells
- YE 2016 DUC Inventory ≈ Normal
* Estimated potential reserves net to EOG, not proved reserves. Includes prior production from existing wells.
** Based on full-year estimates as of November 3, 2016.
FY 2016
4. EOG _1116-4
0
100
200
300
400
500
600
700
800
2016* 2017 2018 2019 2020
$60
* Pro forma for full year of production from Yates in 2016
** Discretionary Cash Flow Capex + Current Dividend
$50
MBopd
2020
Prior
Outlook
15%-25% CAGR
Prior
Outlook
10% - 20%
5. EOG _1116-5
Precision Targeting and
Advanced Completions
Longer Laterals
Yates Increases Quality and Size
of Acreage Position
Convert Wells to Premium with
Infrastructure and Lower Costs
Testing Tighter Spacing and
Additional Zones
Test Northwest Shelf in 2017
* Estimated potential reserves net to EOG, not proved reserves. Includes prior production from existing wells.
Eddy
Lea
Loving
Winkler
Culberson
Ward
Reeves
Chaves
Roosevelt
Northwest
Shelf
143,000
Net Acres
Delaware
Basin
416,000
Net Acres
EOG 559,000 Net Acres
Resource Potential Increased 155% to 6.0 BnBoe*
6. EOG _1116-6
Nov 2016
2.35 BnBoe
Nov 2015
Net Acres
Net Locations
Average Lateral Length
Gross EUR per Well (MBoe)
- Wolfcamp Oil
- Wolfcamp Combo
- Second Bone Spring
- Leonard Shale
238,000
4,900
4,500’
750
900
500
500
416,000
6,330
7,200’
1,330
1,550
950
1,175
6.0 BnBoeNet Resource Potential*
Change
+75%
+29%
+60%
+77%
+72%
+90%
+135%
+155%
* Estimated potential reserves net to EOG, not proved reserves. Includes prior production from existing wells.
7. EOG _1116-7
Premium Well Definition
- Generates at Least 30% Direct ATROR* at $40 Oil
- Does Not Change with Oil Prices; Benchmark Remains $40 Oil
Significant Capital Productivity Increase
- Higher Direct ATROR* with Lower F&D Costs
- Stronger Production Growth from Fewer Wells
Add New Premium Inventory in Three Ways
- Convert Existing Locations to Premium
- Improve Well Productivity with Science and Technology
- Lower Costs and Longer Laterals
- Exploration
- Tactical Acquisitions
Monetize Non-Premium Inventory
* See reconciliation schedules.
Robust Growth for Far Less Capital
8. EOG _1116-8
$30 $40 $50 $60
* Percent of domestic gross completed wells which are premium.
14%
23%
60%
81%
98%
2014 2015 2016
Est
2017
Est
2018+
Est
* Estimated potential reserves net to EOG, not proved reserves.
100%+
10%
60%
30%
Oil:
5.1 BnBoe* ≈6,000 Net Locations >10 Years of Drilling
* See reconciliation schedules.
Premium Drilling Direct ATROR*
(Minimum Return for Premium)
Shifting to Premium Locations
(% Completed Premium Wells*)
9. EOG _1116-9
Aug 2016
≈3,200
Feb 2016
Eagle Ford
Bakken/Three Forks Core
Delaware Basin
- Wolfcamp
- Second Bone Spring
- Leonard
DJ Basin
Powder River Basin
1,535
330
695
255
280
-
80
1,925
330
775
540
435
200
80
≈4,300Total Premium Net Locations
Yates
-
-
500
600
600
-
40
1,740
2.0 BnBoe 3.5 BnBoePremium Net Resource Potential*
* Estimated potential reserves net to EOG, not proved reserves.
1.6 BnBoe
Sept 2016
≈6,000
5.1 BnBoe
1,925
330
1,275
1,140
1,035
200
120
625 MBoe 815 MBoeNet Resource Per Well 850 MBoe920 MBoe
10. EOG _1116-10
0
50
100
150
200
250
300
0 30 60 90 120 150 180 210 240 270
Delaware Basin Second Bone Spring Wells
Average Cumulative Production*
Delaware Basin Wolfcamp Oil Wells
Average Cumulative Production*
(MBoe)
Producing Days
* Normalized to 4,500-foot lateral.
2015
0
25
50
75
100
125
150
0 30 60 90 120 150 180
Producing Days
(MBoe)
2015
2016 2016
* Normalized to 4,500-foot lateral.
11. EOG _1116-11
0
200
400
600
800
1,000
EOG A B C D E F G H I J K L M N O P Q R S
Boed Delaware Basin Oil
Average three-month production, normalized to 5,000’ lateral. All horizontal wells from original operator July 2015 – October 2016.
Gas production converted at 20:1.
Delaware Basin: Culberson, Eddy, Lea, Loving, Reeves and Ward counties. Peer Companies: APA, APC, BHP, COP, CXO, MTDR, NBL, OXY, RDS, WPX and XEC.
Midland Basin: Martin, Midland and Upton counties. Peer Companies: APA, CXO, EGN, FANG, PE, PXD, RSPP and XOM.
Source: IHS Performance Evaluator, supplied by IHS Global Inc.; Copyright (2016).
Well Count 42 59 6 32 47 19 24 12 6611 519
Midland Basin Oil
Solid Colors: Barrels of Oil per Day
Gray Bar: BOE of Natural Gas per Day
92422 10 29 149 7 8
12. EOG _1116-12
38.3
21.5 21.1
10.5
2014 2015 3Q16 Record
Delaware Basin
Wolfcamp Oil Play
South Texas Eagle Ford Bakken
* Normalized to 5,300’ lateral. * Normalized to 8,400’ lateral.* Normalized to 7,000’ lateral.
14.2
10.9
8.9
7.8
5.7
3.6
2012 2013 2014 2015 3Q16 Record
20.8
14.7
12.4
8.5 8.6
5.4
2012 2013 2014 2015 3Q16 Record
13. EOG _1116-13
8.8
7.2
4.9 4.8
2014 2015 3Q16 Target
6.1 5.7
4.6 4.5
2014 2015 3Q16 Target
* CWC = Drilling, Completion, Well-Site Facilities and Flowback.
15.4
9.8
8.5
7.8
2014 2015 3Q16 Target
Delaware Basin
Wolfcamp Oil Play
South Texas Eagle Ford Bakken
* Normalized to 5,300’ lateral. * Normalized to 8,400’ lateral.* Normalized to 7,000’ lateral.
14. EOG _1116-14
Pressure
Pumping
Wireline
Rentals &
Equipment
Drilling
Flowback &
Facilities
Supervsion
& Labor
1Q 2015 Efficiencies Pricing 2016
Target
Water
Handling
Faster
Completion
Operations
Drilling
Flowback &
Facilities
* CWC = Drilling, Completion, Well-Site Facilities and Flowback. Costs for 4,500’ lateral well.
High-
Density
Completions
3/4 Savings From Efficiencies
Efficiency Savings
$1.6MM Per Well
Price Savings
$0.6MM Per Well
Sustainable Efficiency Improvements
$8.3MM
-$1.6MM
-$0.6MM
$6.5MM
+$0.4MM
15. EOG _1116-15
February 2016 September 2016 10% Cost
Savings
1,535
1,925
4,185
Potential
Growth
10% EUR
Increase
-OR-
16. EOG _1116-16
2014 2015 YTD 2016
$17.02
$14.11*
$12.16*
G&P
G&A
Taxes Other
Than Income
Transportation
LOE
* Excludes one-time expenses of $19.4 million in 2015 related to early leasehold termination and $45.0 million in 2016 related to
voluntary retirements and acquisition costs. Includes stock compensation expense and other non-cash items.
See reconciliation schedules.
17. EOG _1116-17
Return to Strong Oil Production Growth
Balance Capex + Dividend with Discretionary Cash Flow
Continue to Lower Costs
- Further Efficiency Improvements
- Insulated from Significant Price Inflation
Increase Premium Inventory
Identify and Develop New Exploration Plays
Uniquely Positioned for Strong 2017 Performance
18. EOG _1116-18
U.S. Leader in Return on Capital Employed
U.S. Oil Growth Leader
One of Lowest Cost Producers in Global Oil Market
Commitment to Safety and the Environment
Create Significant Long-Term Shareholder Value
20. EOG _1116-20
Brushy Canyon
Leonard A
Leonard B
1st Bone Spring
2nd Bone Spring
3rd Bone Spring
Upper Wolfcamp
Middle Wolfcamp
Lower Wolfcamp
4,800’
One World
Trade Center
1,792’
Battery Park to Wall Street to City Hall 4,800’ Middle
Bakken
Lower
Eagle
Ford
40’
150’
Battery
Park
Wall Street
City Hall
21. EOG _1116-21
346,000 Net Acres Prospective with Multiple Target Zones
- 2,660 Net Wells
- Complete ≈70 Net Wells in 2016; 52 YTD
Estimated Resource Potential 2.9 BnBoe,* Net to EOG
Oil Play
- 226,000 Net Acres, 1,585 Net Wells; 660’ Spacing
- Upper and Middle Zones
- EUR 1,330 MBoe, Gross; 1,050 MBoe, NAR
- CWC** Target $7.8 MM for 7,000’ Lateral
Combo Play
- 120,000 Net Acres, 1,075 Net Wells; 880’ Spacing
- Upper and Middle Zones
- EUR 1,550 MBoe, Gross; 1,200 MBoe, NAR
- CWC** Target $8.0 MM for 8,300’ Lateral
Testing 500’ Spacing and Additional Targets
Wolfcamp Oil and Combo Plays Bopd Boed Lateral
- 3Q 2016 22 Gross Wells 30-Day IP 1,675 2,350 4,800’
* Estimated potential reserves net to EOG, not proved reserves. Includes 211 MMBoe of proved reserves booked at December 31, 2015
and prior production from existing wells.
** CWC = Drilling, Completion, Well-Site Facilities and Flowback
NGLs
32%
Typical Wolfcamp
Combo Well
Gas
42%
Oil
26%
Gas
27%
NGLs
20%
Oil
53%
Typical Wolfcamp
Oil Well
22. EOG _1116-22
289,000 Net Acres Prospective in Northern Delaware Basin
- 1,870 Net Wells; ≈ 850’ Spacing
- Complete ≈15 Net Wells in 2016; 15 YTD
Estimated Resource Potential 1.4 BnBoe,* Net to EOG
Typical Well
- EUR 950 MBoe, Gross; 780 MBoe, NAR
- CWC** Target $7.3 MM for 7,000’ Lateral
* Estimated potential reserves net to EOG, not proved reserves. Includes 64 MMBoe of proved reserves in Second Bone Spring and
72 MMBoe in Leonard Shale booked at December 31, 2015 and prior production from existing wells.
** CWC = Drilling, Completion, Well-Site Facilities and Flowback.
NGLs
16%
Typical Second Bone
Spring Well
Gas
22%
Oil
62%
Leonard Shale
Second Bone Spring
160,000 Net Acres Prospective; 1,800 Net Wells
- 660’ Spacing in A and B Zones
- Complete ≈10 Net Wells in 2016; 5 YTD
Estimated Resource Potential 1.7 BnBoe,* Net to EOG
Typical Well
- EUR 1,175 MBoe, Gross; 940 MBoe, NAR
- CWC** Target $6.3 MM for 6,800’ Lateral
NGLs
28%
Typical Red Hills
Leonard Shale Well
Gas
41%
Oil
31%
23. EOG _1116-23
Lateral, Feet
CWC*
Direct ATROR**
NPV10
* CWC = Drilling, Completion, Well-Site Facilities and Flowback.
** See reconciliation schedules. Oil price $40, natural gas price $2.50 per MMBtu.
Total
27,000
$40.2 MM
47%
$15.6 MM
Total
28,800
$31.6 MM
78%
$24.0 MM
Per Well
4,500
$6.7 MM
47%
$2.6 MM
Per Well
7,200
$7.9 MM
78%
$6.0 MM
Short Laterals Long Laterals
NPV 54%
Higher with
Long Laterals
640
Acres
640
Acres
640
Acres
960
Acres
960
Acres
24. EOG _1116-24
High-Quality Assets with Scale
- Large Eagle Ford, Bakken and Delaware Basin Footprints
- Scale Drives Cost Savings and Leverages Technology Gains
Innovation and Technology Focus
- In-House Completion Design
- Merging Data Science and Geoscience
Low-Cost Operator
- Highest Production Per Employee in Peer Group
- Vertically Integrated: Self-Sourced Sand, Chemicals and Drilling Fluids
Organic Exploration Growth
- Internal Prospect Generation First-Mover Advantage
- Replacing Premium Inventory at >2x Drilling Pace
Organization and Culture
- Decentralized Structure Bottom-Up Value Creation
- Returns-Driven Culture – Significant Employee Compensation Criteria
Sustainable Competitive Advantage
25. EOG _1116-25
* Number of producing and undrilled remaining net wells as of January 1, 2016. Assumes no further downspacing, acreage additions or enhanced recovery.
** Estimated potential reserves (MMBoe) net to EOG, not proved reserves. Includes proved reserves and prior production from existing wells.
Inventory Growing in Quality and Size
Play
Net
Acres
Total
Locations*
Resource
Potential**
(MMBoe)
Premium
Locations
Eagle Ford 549,000 7,200 3,200 1,925
Bakken/Three Forks
- Core
- Non-Core
120,000
110,000
975
1,125
620
400
330
-
Delaware Basin
- Wolfcamp 346,000 2,660 2,900 1,275
- Second Bone Spring 289,000 1,870 1,400 1,140
- Leonard 160,000 1,800 1,700 1,035
Rockies
- DJ Basin
- Powder River Basin
85,000
400,000 _
460
315 _
210
190 _
200
120 _
≈ 2,100,000 ≈ 16,000 ≈ 10,600 ≈ 6,000
26. EOG _1116-26
* Based on the midpoint of full-year estimates as of November 3, 2016, excluding acquisitions.
289 284 280
$8.3
$4.7
$2.7
0
50
100
150
200
250
300
0
1
2
3
4
5
6
7
8
9
10
2014 2015 2016*
- 42%
- 44%
Oil Production (MBod) versus Capex* ($Bn)
2016 Capital
Expenditures*
Gathering,
Processing
and Other
Exploration and
Development
Facilities
Exploration and
Development
$0.1
$0.3
$2.3
27. EOG _1116-27
WEBB
FRIO
BEE
UVALDE
DIMMIT
BEXAR
KINNEY
ZAVALA
MEDINA
LA SALLE
LAVACA
MAVERICK
LIVE OAK
ATASCOSA
DE WITT
FAYETTE
MCMULLEN
WILSON
GONZALES
KARNES
GUADALUPE
Oil
71%
Gas
15%
NGLs
14%
Typical Eagle Ford Well
2016 Operations
Largest Oil Producer and Acreage Holder in the Eagle Ford
- Average 5 Rigs Operating in 2016
- Complete 220 Net Wells in 2016; 161 YTD
Estimated Resource Potential 3.2 BnBoe;* 7,200 Net Wells
Typical Well
- 5,300’ Lateral; ≈40-Acre Spacing
- EUR 580 MBoe, Gross; 450 MBoe, NAR
- CWC** $5.7MM in 2015; Target $4.5MM
Precision Targeting
- Lateral Drilling Window 20’ vs. Prior 150’
Bopd Boed Lateral
3Q 2016 47 Gross Wells 30-Day IP 1,425 1,825 5,700’
Shifting to Longer Laterals in West
Completion Innovations Lower Well Costs with Same Productivity
Successful Stacked-Staggered 200’ Down-Spacing Test
- Korth Unit 10H-14H 30-Day IP 2,020 Bopd
* Estimated potential reserves net to EOG, not proved reserves. Includes 1,032 MMBoe proved reserves booked at December 31, 2015
and prior production from existing wells.
** CWC = Drilling, Completion, Well-Site Facilities and Flowback
Crude Oil
Window
Dry Gas
Window
Wet Gas
Window
0 25 Miles
San Antonio
Corpus Christi
Laredo
EOG 608,000 Net Acres
549,000 Net Acres in Oil Window
28. EOG _1116-28
0
20
40
60
80
100
120
140
0 30 60 90 120 150 180
Eagle Ford East Wells
Average Cumulative Oil Production*
2012
2013
2014
Eagle Ford West Wells
Average Cumulative Oil Production*
(Mbo)
Producing Days
* Normalized to 6,600-foot lateral.
2015
0
20
40
60
80
100
120
140
0 30 60 90 120 150 180
Producing Days
* Normalized to 4,600-foot lateral.
(Mbo)
2012
2013
2014
2015
2016
2016
29. EOG _1116-29
2015 Completions
4,030 Events /1,000 ft
540 Events /1,000 ft
2010 Completions
Contain Events Closer
to Wellbore
Enhance Complexity to
Contact More Surface Area
Note: Microseismic dots represent well stimulation events during completions.
30. EOG _1116-30
Lower
Eagle
Ford
1. Grade Rock Characteristics High to Low Quality
2. Overall
Grade
3. Drill
* Sample 1-foot core extracted from Lower Eagle Ford. Enlarged to show detail.
* Sample 1-foot core
extracted from
Lower Eagle Ford.
Enlarged to show
detail of the rock.
31. EOG _1116-31
Four Gas Injection Pilot Projects
with 15 Producing Wells
- One Additional Project in 2016
with 32 Wells
Attractive Economics
- Direct ATROR* >30% and PVI** >2.0
- Capital Investment ≈$1MM per Well
Extended Development Timeline
Not Widely Repeatable Across
Other Tight Oil Plays
* See reconciliation schedules. Assumes oil price $40 per barrel WTI and natural gas price $2.50 per MMBtu Henry Hub.
** Net present value divided by capital investment.
Cumulative Oil Production per Well
1.0x
1.3x – 1.7x
Primary
Recovery
(Net Mbo)
Enhanced Oil
Recovery
Produce 2 - 5 Years
Before EOR Injection
Production Response
≈3 Months After Injection
32. EOG _1116-32
* Estimated potential reserves net to EOG, not proved reserves. Includes 165 MMBoe proved reserves in Bakken/Three Forks
booked at December 31, 2015. Includes prior production from existing wells.
** CWC = Drilling, Completion, Well-Site Facilities and Flowback.
Focus on Premium Locations
Complete ≈50 Net Wells in Williston in 2016
Estimated Resource Potential 1.0 BnBoe*
- 8,400’ Lateral
- $7.2 MM CWC** in 2015; Target $4.8 MM
- 650’ Spacing
Completing DUCs With Premium Go-Forward
Rates of Return
Complete ≈55 Net Wells DJ Basin and Powder River Basin in 2016
PRB Turner Sand Delivering Consistent Premium Returns
- Shift to Two-Mile Laterals to Further Enhance Returns
Gas
15%
Williston Basin
Remaining Wells
Oil
70%
NGL
15%
Canada
Bakken
Core
Antelope
Extension
Bakken
Lite
State Line
Elm
Coulee
EOG Acreage – Bakken/Three Forks
Bakken Oil Saturated
20 Miles
Stanley, ND
Core
Non-Core
33. EOG _1116-33
United Kingdom
East Irish Sea (Conwy)
- Production Commenced March 2016
- Current Production ≈10,000 Bopd
- Further Evaluation to Maximize Reservoir
Productivity
Sercan Joint Development Project
- 5-Well Program
- Complete One Well Late 2016
Limited Capital Spending in 2016
Active Exploration Program
Trinidad
TRINIDAD
ATLANTIC
OCEAN
U(a)
VENEZUELA
4(a)
U(b)
SECC
NORTH
SEA
East
Irish
Sea
Trinidad and Tobago
United Kingdom
34. EOG _1116-34
* EIA STEO Model Released October 2016
8,033
8,262
8,605
8,718
8,876
9,233
9,496
9,517
9,627
9,320
9,384
9,304
9,194
9,174
8,947 8,711
8,744
8,399
8,450
8,493
8,501
8,514
8,506
8,654
8,853
6,187
6,408 6,667
6,964 7,147
7,405
7,427
7,679
7,595
7,402
7,289
7,258
7,067
7,027
6,776
6,694 6,365
6,228
6,228
6,200
6,294
6,357
6,390
6,415
Jan Mar May Jul Sep Nov Jan Mar May Jul Sep Nov Jan Mar May Jul Sep Nov Jan Mar May Jul Sep Nov
2014
+1,296
2015
+652
2016
-681
2017
-147
2014
+1,172
2015
+548
2016
-777
2017
-330
35. EOG _1116-35
Middle East
Venezuela
Brazil
Russia
Nigeria
Angola
US L48 Conv
Mexico
GOM
$0
$10
$20
$30
$40
$50
$60
$70
$80
$90
$100
Middle
East/Russia
Medium Cost
Conventional
US
Tight Oil
Deep
Water
High Cost
Non-OPEC
Arctic / Russian
Unconventional
* Price required to achieve 10% Direct ATROR (see reconciliation schedules).
Source: PIRA.
Brent ($/BBL)
50% 22% 5% 16% 7% -% World Supply
Oil Sands
New Marginal Cost of Oil
(≈ $65 - $75)
North Sea
U.S. Tight OilFar East
Russia EOG ($30)
*
EOG Competitive Globally
36. EOG _1116-36
Industry production data from IHS for U.S. onshore horizontal well production in Eagle Ford, Bakken, Permian, DJ and Powder River. EOG economic analysis.
* ATROR and NPV calculated using $50 WTI and $2.50 NYMEX fixed for life of well. Assumes industry capital and operating costs equal to EOG.
Percent of Wells with ATROR*
>10% at $50 Oil
Net Present Value*
Per Well at $50 Oil
EOG EOGIndustry
79%
95%
39%
2015 2016
EOG EOG
-$0.3MM
$1.7MM
$3.3MM
Industry
2015 2016
38. EOG _1116-38
Production and
Reserve GrowthReturns
A 30%
B 45%
C 40%
D 30%
F 58%
10%
EOG 8%25%
E 30%10%
G 10%
H 30%
Source: Company Reports. Percentages represent weightings applied in determining executive officer short-term incentive compensation.
Peer Group: APA, APC, CHK, DVN, HES, MRO, NBL and PXD.
EOG Employees Are Incentivized to Deliver Returns
39. EOG _1116-39
$0.03 $0.04 $0.04 $0.04 $0.05 $0.06
$0.08
$0.12
$0.18
$0.26
$0.29
$0.31 $0.32
$0.34
$0.38
$0.59
$0.67 $0.67
$0.00
$0.10
$0.20
$0.30
$0.40
$0.50
$0.60
$0.70
1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016*
Note: Dividends adjusted for 2-for-1 stock splits effective March 1, 2005 and March 31, 2014.
* Indicated annual rate.
16 Dividend Increases in 17 Years
Committed to the Dividend
40. EOG _1116-40
0%
10%
20%
30%
40%
50%
60%
70%
80%
A B C D E F G H Peer
Avg
EOG I J K L M N O
* Source: FactSet. As of 6/30/16. See reconciliation schedule.
Peer Group: APA, APC, CLR, COG, COP, CXO, DVN, HES, MRO, NBL, NFX, OXY, PXD, RRC and XEC.
CA G I J K L N O
Issued Equity
Since June 2014
41. Copyright; Assumption of Risk: Copyright 2016. This presentation and the contents of this presentation have been copyrighted by EOG Resources, Inc. (EOG). All rights reserved. Copying of the presentation is
forbidden without the prior written consent of EOG. Information in this presentation is provided “as is” without warranty of any kind, either express or implied, including but not limited to the implied warranties of
merchantability, fitness for a particular purpose and the timeliness of the information. You assume all risk in using the information. In no event shall EOG or its representatives be liable for any special, indirect or
consequential damages resulting from the use of the information.
Cautionary Notice Regarding Forward-Looking Statements: This presentation 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 facts, including, among others, statements and projections regarding EOG's future financial position, operations,
performance, business strategy, returns, budgets, reserves, levels of production and costs, statements regarding future commodity prices and statements regarding the plans and objectives of EOG's management for
future operations, are forward-looking statements. EOG typically uses words such as "expect," "anticipate," "estimate," "project," "strategy," "intend," "plan," "target," "goal," "may," "will," "should" and "believe" or the
negative of those terms or other variations or comparable terminology to identify its forward-looking statements. In particular, statements, express or implied, concerning EOG's future operating results and returns or
EOG's ability to replace or increase reserves, increase production, reduce or otherwise control operating and capital costs, generate income or cash flows or pay dividends are forward-looking statements. Forward-
looking statements are not guarantees of performance. Although EOG believes the expectations reflected in its forward-looking statements are reasonable and are based on reasonable assumptions, no assurance can be
given that these assumptions are accurate or that any of these expectations will be achieved (in full or at all) or will prove to have been correct. Moreover, EOG's forward-looking statements may be affected by known,
unknown or currently unforeseen risks, events or circumstances that may be outside EOG's control. Important factors that could cause EOG's actual results to differ materially from the expectations reflected in EOG's
forward-looking statements include, among others:
• the timing, extent and duration of changes in prices for, supplies of, and demand for, crude oil and condensate, natural gas liquids, natural gas and related commodities;
• the extent to which EOG is successful in its efforts to acquire or discover additional reserves;
• the extent to which EOG is successful in its efforts to economically develop its acreage in, produce reserves and achieve anticipated production levels from, and maximize reserve recovery from, its existing and future
crude oil and natural gas exploration and development projects;
• the extent to which EOG is successful in its efforts to market its crude oil and condensate, natural gas liquids, natural gas and related commodity production;
• the availability, proximity and capacity of, and costs associated with, appropriate gathering, processing, compression, transportation and refining facilities;
• the availability, cost, terms and timing of issuance or execution of, and competition for, mineral licenses and leases and governmental and other permits and rights-of-way, and EOG’s ability to retain mineral licenses
and leases;
• the impact of, and changes in, government policies, laws and regulations, including tax laws and regulations; environmental, health and safety laws and regulations relating to air emissions, disposal of produced
water, drilling fluids and other wastes, hydraulic fracturing and access to and use of water; laws and regulations imposing conditions or restrictions on drilling and completion operations and on the transportation of
crude oil and natural gas; laws and regulations with respect to derivatives and hedging activities; and laws and regulations with respect to the import and export of crude oil, natural gas and related commodities;
• EOG's ability to effectively integrate acquired crude oil and natural gas properties into its operations, fully identify existing and potential problems with respect to such properties and accurately estimate reserves,
production and costs with respect to such properties;
• the extent to which EOG's third-party-operated crude oil and natural gas properties are operated successfully and economically;
• competition in the oil and gas exploration and production industry for the acquisition of licenses, leases and properties, employees and other personnel, facilities, equipment, materials and services;
• the availability and cost of employees and other personnel, facilities, equipment, materials (such as water) and services;
• the accuracy of reserve estimates, which by their nature involve the exercise of professional judgment and may therefore be imprecise;
• weather, including its impact on crude oil and natural gas demand, and weather-related delays in drilling and in the installation and operation (by EOG or third parties) of production, gathering, processing, refining,
compression and transportation facilities;
• the ability of EOG's customers and other contractual counterparties to satisfy their obligations to EOG and, related thereto, to access the credit and capital markets to obtain financing needed to satisfy their
obligations to EOG;
• EOG's ability to access the commercial paper market and other credit and capital markets to obtain financing on terms it deems acceptable, if at all, and to otherwise satisfy its capital expenditure requirements;
• the extent and effect of any hedging activities engaged in by EOG;
• the timing and extent of changes in foreign currency exchange rates, interest rates, inflation rates, global and domestic financial market conditions and global and domestic general economic conditions;
• political conditions and developments around the world (such as political instability and armed conflict), including in the areas in which EOG operates;
• the use of competing energy sources and the development of alternative energy sources;
• the extent to which EOG incurs uninsured losses and liabilities or losses and liabilities in excess of its insurance coverage;
• acts of war and terrorism and responses to these acts;
• physical, electronic and cyber security breaches; and
• the other factors described under ITEM 1A, Risk Factors, on pages 13 through 21 of EOG’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015 and any updates to those factors set forth in EOG's
subsequent Quarterly Reports on Form 10-Q or Current Reports on Form 8-K.
In light of these risks, uncertainties and assumptions, the events anticipated by EOG's forward-looking statements may not occur, and, if any of such events do, we may not have anticipated the timing of their occurrence
or the duration and extent of their impact on our actual results. Accordingly, you should not place any undue reliance on any of EOG's forward-looking statements. EOG's forward-looking statements speak only as of the
date made, and EOG undertakes no obligation, other than as required by applicable law, to update or revise its forward-looking statements, whether as a result of new information, subsequent events, anticipated or
unanticipated circumstances or otherwise.
Oil and Gas Reserves; Non-GAAP Financial Measures: The United States Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose not only “proved” reserves
(i.e., quantities of oil and gas that are estimated to be recoverable with a high degree of confidence), but also “probable” reserves (i.e., quantities of oil and gas that are as likely as not to be recovered) as well as
“possible” reserves (i.e., additional quantities of oil and gas that might be recovered, but with a lower probability than probable reserves). Statements of reserves are only estimates and may not correspond to the
ultimate quantities of oil and gas recovered. Any reserve estimates provided in this presentation that are not specifically designated as being estimates of proved reserves may include "potential" reserves and/or other
estimated reserves not necessarily calculated in accordance with, or contemplated by, the SEC’s latest reserve reporting guidelines. Investors are urged to consider closely the disclosure in EOG’s Annual Report on
Form 10-K for the fiscal year ended December 31, 2015, available from EOG at P.O. Box 4362, Houston, Texas 77210-4362 (Attn: Investor Relations). You can also obtain this report from the SEC by calling 1-800-SEC-0330
or from the SEC's website at www.sec.gov. In addition, reconciliation and calculation schedules for non-GAAP financial measures can be found on the EOG website at www.eogresources.com.