- Sandridge Energy provides a 3-year plan to grow production 20% annually through developing its large inventory of drilling locations in the Midcontinent region, focused on the Mississippian formation.
- The company has achieved strong early results from new zones like the Chester and Woodford, and from expanding into new areas. Well costs have declined to a record low of $2.85 million per lateral through pad drilling and other innovations.
- Sandridge has a significant acreage position with over 4,500 identified high-graded locations and potential in additional zones provides decades of drilling inventory. Financial strength with $919 million of cash and no bond maturities until 2020 provides funding for continued growth.
1) SandRidge Energy presented at the Howard Weil Energy Conference on March 24, 2015. The presentation provided an overview of the company, its assets and operations, capital expenditure plans for 2015, and strategies for adapting to lower oil prices.
2) Key points included outlining a $700 million capital expenditure budget for 2015, a plan to reduce the rig count from 19 to 7 rigs, and targeting $200 million in proceeds from asset sales. The presentation also highlighted efficiency gains and expanded use of multilaterals to reduce well costs.
3) SandRidge demonstrated success in 2014 by growing reserves 37% and type curves 27%, with 47% production growth in the Midcontinent. The presentation emphasized preserving value
This document provides an investor presentation for SandRidge Energy. It summarizes the company's strategic focus on increasing capital efficiency through well cost reductions and expanded use of multilaterals. SandRidge plans to reduce 2015 capital expenditures to $700 million while still guiding for 6% production growth. The presentation highlights recent operational successes in increasing reserves by 37% and improving type curves. It also outlines opportunities in appraising new zones like the Chester and Woodford formations while defending the company's strong position in the Mississippian play.
Cenovus Energy is accelerating its 10-year oil growth plan by bringing forward timelines for its oil sands projects. It is increasing production capacity for existing phases at Foster Creek and increasing the size of future phases. It is also growing its conventional oil production. Cenovus expects these changes will increase its oil production to over 400,000 barrels per day by 2019 while maintaining its cost advantage and financial strength through continued self-funding of its organic growth.
The document provides guidance for SandRidge Energy's 2015 operations including:
- Capital expenditures of $700 million focused on drilling and production in key areas.
- Production guidance of 28-30.5 million barrels of oil equivalent.
- Plans to reduce rig count from 19 to 7 while expanding use of multilaterals.
- Focus on capital discipline, cost reductions, and preserving drilling locations and returns.
This document discusses SandRidge Energy's operations and strategy. It provides an overview of the company, including its production, reserves, assets, and financial information. It outlines Sandridge's strategic focus on lowering well costs and improving returns in its Mississippian operations in the Midcontinent region through techniques like pad drilling, multilaterals, and shared infrastructure. The document also discusses various innovations Sandridge is pursuing to further reduce costs and boost production, such as its successful multilaterial drilling program and plans to expand full section development.
Sandridge Energy presented its operational plan and investment thesis. Key points include:
- Focus on high-grading its Mid-Continent assets and appraising new zones while developing its North Park Niobrara acreage position.
- North Park Niobrara drilling is showing encouraging early results and potential upside through extended laterals and additional benches.
- The company has a strong balance sheet, $536 million in liquidity, and minimal covenants following its restructuring providing financial flexibility.
SandRidge Energy presented its corporate strategy and assets at an investor presentation in March 2017. The company has over $500 million in liquidity and is focused on high-grading its existing positions. SandRidge will continue developing its Mississippian, NW STACK, and North Park Niobrara assets, which have over 1,300 combined drilling locations. The company expects total oil production to increase starting in late 2017. SandRidge is also optimizing completions and lowering costs to maximize value from its key projects.
AMG is expanding its lithium production capabilities in Brazil through a multi-phase project. Phase I involves constructing a plant to produce 90,000 MT of lithium concentrate per year. Phase II, approved with $110M CAPEX, will double concentrate production to 180,000 MT annually by adding a second plant. Subject to Phase III approval, AMG aims to downstream convert concentrate to lithium carbonate, targeting an integrated production cost of around $4,000/MT. The expansion leverages AMG's existing tantalum operations and infrastructure at its long-operating Mibra mine.
1) SandRidge Energy presented at the Howard Weil Energy Conference on March 24, 2015. The presentation provided an overview of the company, its assets and operations, capital expenditure plans for 2015, and strategies for adapting to lower oil prices.
2) Key points included outlining a $700 million capital expenditure budget for 2015, a plan to reduce the rig count from 19 to 7 rigs, and targeting $200 million in proceeds from asset sales. The presentation also highlighted efficiency gains and expanded use of multilaterals to reduce well costs.
3) SandRidge demonstrated success in 2014 by growing reserves 37% and type curves 27%, with 47% production growth in the Midcontinent. The presentation emphasized preserving value
This document provides an investor presentation for SandRidge Energy. It summarizes the company's strategic focus on increasing capital efficiency through well cost reductions and expanded use of multilaterals. SandRidge plans to reduce 2015 capital expenditures to $700 million while still guiding for 6% production growth. The presentation highlights recent operational successes in increasing reserves by 37% and improving type curves. It also outlines opportunities in appraising new zones like the Chester and Woodford formations while defending the company's strong position in the Mississippian play.
Cenovus Energy is accelerating its 10-year oil growth plan by bringing forward timelines for its oil sands projects. It is increasing production capacity for existing phases at Foster Creek and increasing the size of future phases. It is also growing its conventional oil production. Cenovus expects these changes will increase its oil production to over 400,000 barrels per day by 2019 while maintaining its cost advantage and financial strength through continued self-funding of its organic growth.
The document provides guidance for SandRidge Energy's 2015 operations including:
- Capital expenditures of $700 million focused on drilling and production in key areas.
- Production guidance of 28-30.5 million barrels of oil equivalent.
- Plans to reduce rig count from 19 to 7 while expanding use of multilaterals.
- Focus on capital discipline, cost reductions, and preserving drilling locations and returns.
This document discusses SandRidge Energy's operations and strategy. It provides an overview of the company, including its production, reserves, assets, and financial information. It outlines Sandridge's strategic focus on lowering well costs and improving returns in its Mississippian operations in the Midcontinent region through techniques like pad drilling, multilaterals, and shared infrastructure. The document also discusses various innovations Sandridge is pursuing to further reduce costs and boost production, such as its successful multilaterial drilling program and plans to expand full section development.
Sandridge Energy presented its operational plan and investment thesis. Key points include:
- Focus on high-grading its Mid-Continent assets and appraising new zones while developing its North Park Niobrara acreage position.
- North Park Niobrara drilling is showing encouraging early results and potential upside through extended laterals and additional benches.
- The company has a strong balance sheet, $536 million in liquidity, and minimal covenants following its restructuring providing financial flexibility.
SandRidge Energy presented its corporate strategy and assets at an investor presentation in March 2017. The company has over $500 million in liquidity and is focused on high-grading its existing positions. SandRidge will continue developing its Mississippian, NW STACK, and North Park Niobrara assets, which have over 1,300 combined drilling locations. The company expects total oil production to increase starting in late 2017. SandRidge is also optimizing completions and lowering costs to maximize value from its key projects.
AMG is expanding its lithium production capabilities in Brazil through a multi-phase project. Phase I involves constructing a plant to produce 90,000 MT of lithium concentrate per year. Phase II, approved with $110M CAPEX, will double concentrate production to 180,000 MT annually by adding a second plant. Subject to Phase III approval, AMG aims to downstream convert concentrate to lithium carbonate, targeting an integrated production cost of around $4,000/MT. The expansion leverages AMG's existing tantalum operations and infrastructure at its long-operating Mibra mine.
Mandalay Resources Corporation provides a presentation on its mining portfolio and 2020 guidance. Key points include:
- Costerfield is expected to significantly increase production over the next 12 months from ramping up its high-grade Youle vein. 2020 guidance is 44,000-52,000 gold equivalent ounces at cash costs of $725-875/oz.
- Björkdal will steadily ramp up underground production from its Aurora zone as more levels are developed. 2020 guidance is 51,000-57,000 gold ounces at cash costs of $750-900/oz.
- 2020 consolidated production guidance is 95,000-109,000 gold equivalent ounces at cash costs of $765-915/
Mandalay Resources provides a presentation on its mining portfolio and strategy. It owns the Costerfield gold-antimony mine in Australia and the Björkdal gold mine in Sweden. Costerfield is ramping up production from its high-grade Youle vein, with production expected to increase to 44,000-52,000 gold equivalent ounces in 2020. Björkdal is increasing underground production from the new Aurora zone, with production forecast at 51,000-57,000 gold ounces in 2020. Mandalay also discusses its COVID-19 safety measures, recent financing activities, exploration plans to expand resources at both mines, and summaries for each asset.
SandRidge Energy Q1 2017 Earnings PresentationSandRidgeIR
The document is an earnings presentation for SandRidge Energy's first quarter of 2017. It summarizes the company's operational and financial results for Q1, including production of 4.0 MMBoe, adjusted EBITDA of $56 million, and capital expenditures of $41 million. It discusses the company's three project areas - NW STACK, North Park Niobrara, and Mississippian - and plans for continued delineation and development across the portfolio in 2017.
This document provides an earnings presentation by Sandridge Energy for Q3 2016. It includes cautionary statements about forward-looking projections. The presentation summarizes Sandridge's operational strategy of focusing on high-return projects from its Mid-Continent assets while diversifying into long-term growth from its large North Park Niobrara position. It provides details on improved drilling economics in both areas, highlighting initial positive results from extended laterals in the Niobrara. The presentation also outlines Sandridge's reorganized capital structure and liquidity following its bankruptcy restructuring and concludes with operational and capital expenditure guidance for 2016.
The presentation discusses an investor presentation by an oil and gas company. It contains forward-looking statements about future plans and estimates. The company has 162,000 gross acres in the Permian Basin with an estimated 1 billion barrels of oil equivalent of unrisked resource potential. It plans to drill 70 wells in 2014 with a $400 million capital budget as part of developing its Wolfcamp shale oil resource play.
The document discusses AREX's 2014 development plan for its Wolfcamp shale oil resource play in the Permian Basin. Key points include:
- 2014 capital budget of $400 million, 95% directed to horizontal Wolfcamp drilling with 3 rigs
- Targeting the Wolfcamp A, B, and C zones with pad drilling and stacked laterals
- Expecting 45% production growth in 2014 to 4.95 MMBoe with a 70% liquids mix
- Horizontal Wolfcamp well costs estimated at $5.5 million
The plan focuses on developing AREX's large Wolfcamp shale oil resource potential through horizontal drilling and pad development while maintaining flexibility given commodity price uncertainty
The document provides an overview of Antero Resources Corporation. It discusses forward-looking statements and risks associated with the estimates and projections. It also highlights key aspects of Antero's recent acquisition including the addition of 66,500 net acres and over 5 trillion cubic feet of reserves for $546 million. The acquisition significantly increases Antero's drilling inventory in the Marcellus shale play with attractive well economics.
SandRidge Energy has built a portfolio focused on oil production growth from three key project areas: the Mississippian limestone play, NW STACK area in Oklahoma, and North Park Niobrara oil project in Colorado. The company has $554 million in liquidity and no debt. In 2017, it will continue developing the NW STACK and North Park projects with two rigs total, while high-grading its Mississippian position for cash flow. Recent well results have met or exceeded expectations at both NW STACK and North Park.
This document provides an overview and summary of Petrobras' 2nd Quarter 2012 financial results. Key points include:
- Petrobras reported a loss in 2Q12 versus a profit in 1Q12, due to factors like exchange rate devaluation, lower oil product prices in Brazil, production stoppages, and increased exploration expenses.
- The average exchange rate depreciated in 2Q12 compared to 1Q12, negatively impacting costs.
- Operational highlights included refining throughput records and advances in contracting for offshore oil development.
- 2Q12 results were affected by unique factors that are unlikely to occur together or at the same intensity in future quarters.
DNR Fall 2020 Production Forecast (1.27.2021)Brad Keithley
The document provides a summary of Alaska's 2020 oil production forecast. It notes that the COVID-19 pandemic disrupted production in 2020, leading to deferred maintenance and interrupted drilling. The forecast expects average 2021 production of 470,000 barrels per day, within the range of 413,000 to 526,000 barrels per day. Currently producing fields will remain the backbone of production, while future projects under development or evaluation could help offset declining output from mature fields over the long term. However, uncertainty increases in longer-term forecasts due to risks associated with new projects.
The document discusses AREX's fourth quarter and full-year 2013 results. Key points include:
- Production for 4Q13 exceeded guidance at 11.3 MBoe/d and was 46% oil.
- Proved reserves increased 20% year-over-year to 114.7 MMBoe, with growth driven by the Wolfcamp shale play.
- The company plans to drill approximately 70 horizontal Wolfcamp wells in 2014 with a 3-rig program, targeting 40% production growth.
This document provides an update on Brazil's pre-salt oil and gas reserves. It summarizes key developments including increasing production from pre-salt fields in the Campos and Santos basins through expanded drilling and new production units coming online. Production has ramped up significantly from initial test wells to over 700,000 barrels per day currently. New technologies have been applied including deeper wells and new types of risers. Pre-salt fields provide competitive production costs and represent Brazil's role in global energy supply.
- Third Quarter 2014 Results presentation by AREX discussing financial and operational results
- Produced 14.2 MBoe/d in 3Q14, a 61% increase from the prior year, maintaining low well costs of $5.5 million per well
- Drilled 18 horizontal wells in the Wolfcamp shale play and completed 16 wells, achieving a type curve IP rate of 746 Boe/d
- Achieved record quarterly EBITDAX of $50.7 million and revenues of $68.1 million, maintaining a strong financial position with $362 million in liquidity
The document provides an overview of Antero Resources Corporation and contains forward-looking statements regarding estimates, plans, expectations and guidance. It notes that actual results may differ materially from forward-looking statements due to risks and uncertainties in the exploration and development of natural gas and oil. These risks include commodity price volatility, inflation, operational risks, regulatory changes, reserve estimation uncertainties, and other factors discussed in Antero's SEC filings.
- The document provides an overview of Antero Resources Corporation, a company focused on developing natural gas and oil resources from the Marcellus and Utica Shales.
- Antero has significant reserves and acreage positions in the Marcellus and Utica Shales, with over 37 trillion cubic feet of reserves across both plays.
- The company has invested heavily in midstream infrastructure like gathering lines and processing facilities to support its production and growth.
- Antero has also secured long-term firm transportation and processing agreements to achieve premium realized prices for its natural gas and natural gas liquids.
Noble Energy is positioned for strong growth over the next five years from its portfolio of assets. Production is expected to more than double by 2017 through development of its core areas including the DJ Basin, Marcellus Shale, and offshore projects. Noble will invest $3.9 billion in 2013 to accelerate unconventional programs and complete major projects. This high level of investment is expected to deliver double-digit production and cash flow growth through 2017 and position the company for strong performance over the next decade.
This document discusses an energy conference presentation by AREX, an oil and gas company. Key points:
- AREX has 163,000 acres in the Permian Basin with an estimated 1 billion barrels of oil equivalent of unrisked resource potential from the Wolfcamp shale play.
- AREX is running 3 horizontal drilling rigs and plans to drill 70 wells in 2014 to develop the Wolfcamp shale, with a goal of 40% production growth.
- Well results have tracked or exceeded AREX's 450 Mboe type curve, with a recent Wolfcamp C well averaging 970 boe/d. Infrastructure investments aim to reduce costs and enable large-scale development.
EOG Resources 4Q 2015 Quarterly Presentation Investor RelationsMichelle Smith
EOG Resources provides key information about its operations and financial results. It has over 3,200 premium well locations with over 2 billion barrels of oil equivalent of resource potential. EOG reduced capital spending 44% year-over-year while maintaining flat US oil production in 2015. It aims to generate at least 30% returns on investment at $40/barrel oil from its shifting focus to premium locations with over 10 years of sustainable inventory growth.
- AREX reported strong third quarter 2014 results, with production up 61% year-over-year to 14.2 million barrels of oil equivalent per day and EBITDAX reaching a record high of $50.7 million, up 60% year-over-year.
- In the third quarter, AREX drilled 18 and completed 16 horizontal wells in the Wolfcamp shale play, maintaining best-in-class well costs of $5.5 million per well on average.
- Initial production from recent wells continues to track at or above AREX's 450 thousand barrels of oil equivalent type curve, and an Elliott C bench well expanded the potential of the Wolfcamp development to the east.
Noble Energy's strategy focuses on developing premier basins in the U.S. and globally through operational excellence and financial strength. The company has a diversified portfolio of high-quality, low-cost assets producing oil and natural gas. Noble Energy aims to align capital and costs with market conditions while maintaining investment flexibility and strong financial liquidity. Key goals for 2016 include protecting the balance sheet, maintaining production of 390 MBoe/d with a $1.5 billion capital program, and leveraging benefits of its well-positioned portfolio.
SandRidge Energy presented at an energy conference, outlining their operations and strategy in response to lower oil prices. Key points included:
1) A $700 million capital budget for 2015, down from $1.6 billion in 2014, focusing on efficiency gains and expanded use of multilaterals to preserve returns.
2) Demonstrating success in 2014 through production growth, increased reserves, and pioneering multilaterals in the Mississippian.
3) Pursuing appraisal and redevelopment opportunities in legacy reservoirs like the Chester and Woodford to further extend the drilling inventory.
SandRidge Energy presented at an energy conference, outlining its strategy to thrive in a lower oil price environment through capital discipline and efficiency gains. Key points:
- The company plans to reduce its 2015 capital expenditures to $700 million, down from $1.6 billion in 2014, through lower well costs, expanded use of multilaterals, and other efficiencies.
- SandRidge expects its new strategy will allow it to grow production 6% in 2015 while drilling fewer wells and lowering its rig count.
- The company has a strong hedge position and recently negotiated more flexible debt covenants to bolster its financial position in the current market.
Mandalay Resources Corporation provides a presentation on its mining portfolio and 2020 guidance. Key points include:
- Costerfield is expected to significantly increase production over the next 12 months from ramping up its high-grade Youle vein. 2020 guidance is 44,000-52,000 gold equivalent ounces at cash costs of $725-875/oz.
- Björkdal will steadily ramp up underground production from its Aurora zone as more levels are developed. 2020 guidance is 51,000-57,000 gold ounces at cash costs of $750-900/oz.
- 2020 consolidated production guidance is 95,000-109,000 gold equivalent ounces at cash costs of $765-915/
Mandalay Resources provides a presentation on its mining portfolio and strategy. It owns the Costerfield gold-antimony mine in Australia and the Björkdal gold mine in Sweden. Costerfield is ramping up production from its high-grade Youle vein, with production expected to increase to 44,000-52,000 gold equivalent ounces in 2020. Björkdal is increasing underground production from the new Aurora zone, with production forecast at 51,000-57,000 gold ounces in 2020. Mandalay also discusses its COVID-19 safety measures, recent financing activities, exploration plans to expand resources at both mines, and summaries for each asset.
SandRidge Energy Q1 2017 Earnings PresentationSandRidgeIR
The document is an earnings presentation for SandRidge Energy's first quarter of 2017. It summarizes the company's operational and financial results for Q1, including production of 4.0 MMBoe, adjusted EBITDA of $56 million, and capital expenditures of $41 million. It discusses the company's three project areas - NW STACK, North Park Niobrara, and Mississippian - and plans for continued delineation and development across the portfolio in 2017.
This document provides an earnings presentation by Sandridge Energy for Q3 2016. It includes cautionary statements about forward-looking projections. The presentation summarizes Sandridge's operational strategy of focusing on high-return projects from its Mid-Continent assets while diversifying into long-term growth from its large North Park Niobrara position. It provides details on improved drilling economics in both areas, highlighting initial positive results from extended laterals in the Niobrara. The presentation also outlines Sandridge's reorganized capital structure and liquidity following its bankruptcy restructuring and concludes with operational and capital expenditure guidance for 2016.
The presentation discusses an investor presentation by an oil and gas company. It contains forward-looking statements about future plans and estimates. The company has 162,000 gross acres in the Permian Basin with an estimated 1 billion barrels of oil equivalent of unrisked resource potential. It plans to drill 70 wells in 2014 with a $400 million capital budget as part of developing its Wolfcamp shale oil resource play.
The document discusses AREX's 2014 development plan for its Wolfcamp shale oil resource play in the Permian Basin. Key points include:
- 2014 capital budget of $400 million, 95% directed to horizontal Wolfcamp drilling with 3 rigs
- Targeting the Wolfcamp A, B, and C zones with pad drilling and stacked laterals
- Expecting 45% production growth in 2014 to 4.95 MMBoe with a 70% liquids mix
- Horizontal Wolfcamp well costs estimated at $5.5 million
The plan focuses on developing AREX's large Wolfcamp shale oil resource potential through horizontal drilling and pad development while maintaining flexibility given commodity price uncertainty
The document provides an overview of Antero Resources Corporation. It discusses forward-looking statements and risks associated with the estimates and projections. It also highlights key aspects of Antero's recent acquisition including the addition of 66,500 net acres and over 5 trillion cubic feet of reserves for $546 million. The acquisition significantly increases Antero's drilling inventory in the Marcellus shale play with attractive well economics.
SandRidge Energy has built a portfolio focused on oil production growth from three key project areas: the Mississippian limestone play, NW STACK area in Oklahoma, and North Park Niobrara oil project in Colorado. The company has $554 million in liquidity and no debt. In 2017, it will continue developing the NW STACK and North Park projects with two rigs total, while high-grading its Mississippian position for cash flow. Recent well results have met or exceeded expectations at both NW STACK and North Park.
This document provides an overview and summary of Petrobras' 2nd Quarter 2012 financial results. Key points include:
- Petrobras reported a loss in 2Q12 versus a profit in 1Q12, due to factors like exchange rate devaluation, lower oil product prices in Brazil, production stoppages, and increased exploration expenses.
- The average exchange rate depreciated in 2Q12 compared to 1Q12, negatively impacting costs.
- Operational highlights included refining throughput records and advances in contracting for offshore oil development.
- 2Q12 results were affected by unique factors that are unlikely to occur together or at the same intensity in future quarters.
DNR Fall 2020 Production Forecast (1.27.2021)Brad Keithley
The document provides a summary of Alaska's 2020 oil production forecast. It notes that the COVID-19 pandemic disrupted production in 2020, leading to deferred maintenance and interrupted drilling. The forecast expects average 2021 production of 470,000 barrels per day, within the range of 413,000 to 526,000 barrels per day. Currently producing fields will remain the backbone of production, while future projects under development or evaluation could help offset declining output from mature fields over the long term. However, uncertainty increases in longer-term forecasts due to risks associated with new projects.
The document discusses AREX's fourth quarter and full-year 2013 results. Key points include:
- Production for 4Q13 exceeded guidance at 11.3 MBoe/d and was 46% oil.
- Proved reserves increased 20% year-over-year to 114.7 MMBoe, with growth driven by the Wolfcamp shale play.
- The company plans to drill approximately 70 horizontal Wolfcamp wells in 2014 with a 3-rig program, targeting 40% production growth.
This document provides an update on Brazil's pre-salt oil and gas reserves. It summarizes key developments including increasing production from pre-salt fields in the Campos and Santos basins through expanded drilling and new production units coming online. Production has ramped up significantly from initial test wells to over 700,000 barrels per day currently. New technologies have been applied including deeper wells and new types of risers. Pre-salt fields provide competitive production costs and represent Brazil's role in global energy supply.
- Third Quarter 2014 Results presentation by AREX discussing financial and operational results
- Produced 14.2 MBoe/d in 3Q14, a 61% increase from the prior year, maintaining low well costs of $5.5 million per well
- Drilled 18 horizontal wells in the Wolfcamp shale play and completed 16 wells, achieving a type curve IP rate of 746 Boe/d
- Achieved record quarterly EBITDAX of $50.7 million and revenues of $68.1 million, maintaining a strong financial position with $362 million in liquidity
The document provides an overview of Antero Resources Corporation and contains forward-looking statements regarding estimates, plans, expectations and guidance. It notes that actual results may differ materially from forward-looking statements due to risks and uncertainties in the exploration and development of natural gas and oil. These risks include commodity price volatility, inflation, operational risks, regulatory changes, reserve estimation uncertainties, and other factors discussed in Antero's SEC filings.
- The document provides an overview of Antero Resources Corporation, a company focused on developing natural gas and oil resources from the Marcellus and Utica Shales.
- Antero has significant reserves and acreage positions in the Marcellus and Utica Shales, with over 37 trillion cubic feet of reserves across both plays.
- The company has invested heavily in midstream infrastructure like gathering lines and processing facilities to support its production and growth.
- Antero has also secured long-term firm transportation and processing agreements to achieve premium realized prices for its natural gas and natural gas liquids.
Noble Energy is positioned for strong growth over the next five years from its portfolio of assets. Production is expected to more than double by 2017 through development of its core areas including the DJ Basin, Marcellus Shale, and offshore projects. Noble will invest $3.9 billion in 2013 to accelerate unconventional programs and complete major projects. This high level of investment is expected to deliver double-digit production and cash flow growth through 2017 and position the company for strong performance over the next decade.
This document discusses an energy conference presentation by AREX, an oil and gas company. Key points:
- AREX has 163,000 acres in the Permian Basin with an estimated 1 billion barrels of oil equivalent of unrisked resource potential from the Wolfcamp shale play.
- AREX is running 3 horizontal drilling rigs and plans to drill 70 wells in 2014 to develop the Wolfcamp shale, with a goal of 40% production growth.
- Well results have tracked or exceeded AREX's 450 Mboe type curve, with a recent Wolfcamp C well averaging 970 boe/d. Infrastructure investments aim to reduce costs and enable large-scale development.
EOG Resources 4Q 2015 Quarterly Presentation Investor RelationsMichelle Smith
EOG Resources provides key information about its operations and financial results. It has over 3,200 premium well locations with over 2 billion barrels of oil equivalent of resource potential. EOG reduced capital spending 44% year-over-year while maintaining flat US oil production in 2015. It aims to generate at least 30% returns on investment at $40/barrel oil from its shifting focus to premium locations with over 10 years of sustainable inventory growth.
- AREX reported strong third quarter 2014 results, with production up 61% year-over-year to 14.2 million barrels of oil equivalent per day and EBITDAX reaching a record high of $50.7 million, up 60% year-over-year.
- In the third quarter, AREX drilled 18 and completed 16 horizontal wells in the Wolfcamp shale play, maintaining best-in-class well costs of $5.5 million per well on average.
- Initial production from recent wells continues to track at or above AREX's 450 thousand barrels of oil equivalent type curve, and an Elliott C bench well expanded the potential of the Wolfcamp development to the east.
Noble Energy's strategy focuses on developing premier basins in the U.S. and globally through operational excellence and financial strength. The company has a diversified portfolio of high-quality, low-cost assets producing oil and natural gas. Noble Energy aims to align capital and costs with market conditions while maintaining investment flexibility and strong financial liquidity. Key goals for 2016 include protecting the balance sheet, maintaining production of 390 MBoe/d with a $1.5 billion capital program, and leveraging benefits of its well-positioned portfolio.
SandRidge Energy presented at an energy conference, outlining their operations and strategy in response to lower oil prices. Key points included:
1) A $700 million capital budget for 2015, down from $1.6 billion in 2014, focusing on efficiency gains and expanded use of multilaterals to preserve returns.
2) Demonstrating success in 2014 through production growth, increased reserves, and pioneering multilaterals in the Mississippian.
3) Pursuing appraisal and redevelopment opportunities in legacy reservoirs like the Chester and Woodford to further extend the drilling inventory.
SandRidge Energy presented at an energy conference, outlining its strategy to thrive in a lower oil price environment through capital discipline and efficiency gains. Key points:
- The company plans to reduce its 2015 capital expenditures to $700 million, down from $1.6 billion in 2014, through lower well costs, expanded use of multilaterals, and other efficiencies.
- SandRidge expects its new strategy will allow it to grow production 6% in 2015 while drilling fewer wells and lowering its rig count.
- The company has a strong hedge position and recently negotiated more flexible debt covenants to bolster its financial position in the current market.
- Sandridge Energy provides a 3-year plan to grow production 20% annually through developing its large inventory of drilling locations in the Midcontinent region, focused on the Mississippian formation.
- The company has achieved strong well results that exceed type curves, including 30-day rates for Mississippian wells of 412 boe/d. Innovation in techniques like pad drilling and multilaterals has reduced well costs to a record low of $2.85 million.
- Sandridge has a significant acreage position with over 4,500 identified high-graded locations and estimates over 8,000 additional locations through emerging zones. Financial strength includes $919 million in cash and no bond maturities until 2020.
SandRidge Energy presented at an energy conference, outlining their operations and strategy in response to lower oil prices. Key points included:
1) A $700 million capital budget for 2015, down from $1.6 billion in 2014, focusing on efficiency gains and expanded use of multilaterals to preserve returns.
2) Demonstrating success in 2014 through production growth, increased reserves, and pioneering multilaterals in the Mississippian.
3) Pursuing appraisal and redevelopment opportunities in legacy reservoirs like the Chester and Woodford to further extend the drilling inventory.
SandRidge Energy presented at an energy conference, highlighting its operations, capital efficiency gains, and 2015 guidance. Key points included:
1) A $700 million capital budget for 2015 focusing on efficiency and multilaterals to preserve 6% production growth while lowering rig count.
2) Capital efficiency gains through service cost reductions, improved well design, and expanding multilaterals which provide the same production as single laterals for 20% less cost.
3) 37% proved reserve growth in 2014 to 516 MMBoe and a 27% improvement to the type curve, demonstrating repeated operational success.
- 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
The investor presentation summarizes Sandridge Energy's assets and operational priorities. Sandridge has a Mid-Continent focus area with 462,000 net acres and over 300 drilling locations. It is also developing the North Park Niobrara with 129,000 net acres and over 1,300 locations. Sandridge aims to improve efficiency through extended laterals, reduce costs, and test adjacent plays in the Mid-Continent. In the Niobrara, it seeks to optimize completions, acquire more seismic data, and potentially reduce costs to below $4 million per lateral.
The investor presentation summarizes Sandridge Energy's assets and operational priorities. Sandridge has a Mid-Continent focus area with 462,000 net acres and over 300 drilling locations. It also has a North Park Niobrara oil project with 129,000 net acres and over 1,300 drilling locations. Sandridge's priorities include high-grading its Mid-Continent position through extended laterals and evaluating adjacent plays, and initiating its Niobrara oil program in North Park Basin through extended laterals and optimized completions to reduce costs.
2017 scotia howard weil energy conference finalGib Knight
- Newfield Exploration Company is focused on developing its large acreage position in the Anadarko Basin, which it believes can deliver decades of high returns through drilling.
- Newfield has a proven track record of finding and developing valuable plays and is a proven operator that has taken multiple plays from concept to development.
- Newfield's financial strength and capital discipline allows it to execute its development plan, even at current commodity prices, through continued Anadarko Basin oil growth.
The document summarizes Arex Energy's second quarter 2016 results. It discusses:
- Low operating costs of $4.56 per barrel of oil equivalent and record low drilling and completion costs of $3.7 million per well.
- Average production of 12.6 thousand barrels of oil equivalent per day, exceeding guidance. New wells are outperforming type curves.
- Revenues of $22.4 million and EBITDAX of $13.7 million. Capital expenditures were $6.9 million, aligned with cash flow. The company has $51 million in liquidity.
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 update on Chesapeake Energy's business strategies and operations for September 2018. It discusses restoring the company's balance sheet through applying $1.9 billion in proceeds from an asset sale to debt reduction. It highlights the company's diverse portfolio across five basins and focuses on growth in the Powder River Basin, where production is ramping ahead of schedule led by the Turner opportunity. The company is improving drilling efficiencies to enhance returns in the Powder River Basin.
- The company reported its first quarter 2014 results, with key highlights including a 42% year-over-year increase in production to 11.9 million barrels of oil equivalent per day and record quarterly EBITDAX of $42.7 million, up 75% from the previous year.
- In the quarter the company drilled 16 horizontal wells and completed 19 wells in its Wolfcamp shale play, with an average initial production of 743 barrels of oil equivalent per day across wells completed.
- The financial position of the company remains strong with $354 million in liquidity as of the end of the quarter and an undrawn borrowing base of $350 million.
PVA is an oil and gas E&P company focused on growing its oil and liquids production. It has successfully transitioned to focus on oil-rich plays like the Eagle Ford shale, growing its oil production significantly. PVA is working to improve its liquidity through asset sales and reducing capital spending while maintaining strong drilling results in its key oil assets. The company remains attractively valued given its transition towards oilier production and reserves.
PVA is an E&P company that has transitioned from primarily natural gas to oil and liquids production through its Eagle Ford Shale position. It has 23,000 net acres in the Eagle Ford with 190 well locations identified. PVA's strategy has increased revenues and cash flows as oil and liquids prices have risen relative to natural gas prices. PVA believes its valuation is low relative to peers given its oil and liquids focus, production growth, and hedging program. It plans to continue developing its Eagle Ford acreage and adding other oil projects while maintaining its gas assets for potential future price recovery.
- The company has a high-quality asset base in the Permian Basin with over 115 million barrels of oil equivalent in proved reserves and over 1 billion barrels of oil equivalent in estimated resource potential from over 1,000 identified drilling locations.
- Production has grown significantly in recent years through horizontal drilling in the Wolfcamp shale, with a 19% increase in 2013 and a target of 40% growth in 2014.
- Oil reserves and production have increased substantially, with oil reserves up over 10 times since 2009 and oil production up nearly 50% in 2013 alone, driven by successful horizontal Wolfcamp development.
Broadwind Energy presented an investor presentation covering their industry and financial performance. Key highlights included a strong backlog of $228M at Q3 2014 with 2015 tower production capacity nearly sold out. Broadwind has diversified into industrial markets representing half of sales in 3-5 years. Challenges in Q3 2014 from a new tower design were addressed and financial results are expected to improve in 2014 over 2013, supported by solid order backlogs.
- The company reported third quarter 2015 results with record production of 16.6 MBoe/d, up 17% year-over-year.
- Operating costs continued to decrease, with lease operating expenses of $5.04/Boe, a 14% reduction from the prior year.
- The company drilled 4 wells and completed 5 wells in the Wolfcamp B-C zones, with initial production averaging 931 Boe/d.
PVA is transitioning from a natural gas producer to an oil and natural gas liquids producer through its focus on oil-rich plays like the Eagle Ford Shale. This shift has improved revenues and cash flows as oil and NGL prices have increased relative to natural gas prices. PVA plans to continue growing its oil and liquids production and considers asset sales to boost liquidity in the near term. The company believes it is undervalued relative to its peers given its leverage to higher-priced oil and natural gas liquids.
Victory Energy (VYEY) Investor PresentationDerek Gradwell
Victory Energy Corporation is a public oil and gas exploration company focused on development in the Permian Basin. The company owns interests in several producing properties in the basin. Victory plans to deploy $15 million in 2014 for drilling, completions, and acquisitions to increase production and proved reserves. The goal is to achieve over 30 million barrels of proved reserves by year-end and increase revenue to over $1 million. A key focus is the recently acquired 4,050 acre Fairway project, which Victory expects can generate a 60% internal rate of return over three years of planned drilling.
- The document provides financial and operational highlights for Arex Energy's fourth quarter and full-year 2014 results.
- Key highlights include record revenues and net income for the full year, strong production and reserve growth, capital expenditures below budget, and a flexible capital program for 2015 focused on financial discipline and returns.
- Operational results demonstrated continued strong well performance and recoveries from the Wolfcamp shale play, Arex's core asset.
PVA is an E&P company focused on growing its oil and NGL production and reserves. It has successfully transitioned to focus on oil-rich plays like the Eagle Ford shale through acquisitions and drilling. This strategy has increased revenues and cash flows as oil and NGL production rose 192% from 2010 to 2011. PVA will continue developing the Eagle Ford and testing new oil prospects while retaining gas assets for potential future price increases to further optimize its portfolio.
- PVA is a small-cap E&P company focused on oil and liquids-rich plays like the Eagle Ford Shale with excellent drilling results to date. PVA has been executing a strategy to transition from natural gas to growing oil and NGL production and reserves.
- PVA appears undervalued relative to peers based on trading at a discount to peer multiples of 2012 estimated cash flow per share and EBITDAX, and its enterprise value is only modestly above its year-end 2011 proved reserve value.
- PVA has options to build financial liquidity in 2012 including potential asset sales, reducing capital expenditures given its focus on oil and liquids plays, and continuing its active hedging program.
- PVA is a small-cap E&P company focused on oil and liquids-rich plays like the Eagle Ford Shale, with excellent drilling results to date in the Eagle Ford
- PVA is executing a strategy to transition from natural gas to oil and liquids, through increased drilling in plays like the Eagle Ford where it has over 23,000 net acres
- Key catalysts for PVA include further exploratory success in the Eagle Ford, improving production and cash flows from the Eagle Ford, and a potential Granite Wash asset sale to boost liquidity
- PVA is a small-cap E&P company focused on oil and liquids-rich plays like the Eagle Ford Shale, with excellent drilling results to date in the Eagle Ford
- PVA is executing a strategy to transition from natural gas to oil and liquids, through its Eagle Ford position and other oil-focused assets
- Key catalysts for PVA include further exploratory success in the Eagle Ford, increasing Eagle Ford production and margins, and selling its Granite Wash assets to boost liquidity
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.
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MUTUAL FUNDS (ICICI Prudential Mutual Fund) BY JAMES RODRIGUESWilliamRodrigues148
Mutual funds are investment vehicles that pool money from multiple investors to purchase a diversified portfolio of stocks, bonds, or other securities. They are managed by professional portfolio managers or investment companies who make investment decisions on behalf of the fund's investors.
2. 2
DISCLAIMER
Forward Looking Statement
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. These statements express a belief, expectation or intention and are generally accompanied by words that convey
projected future events or outcomes. The forward-looking statements include statements about the company’s future operations, rig counts, drilling inventory
and locations, acreage positions, corporate strategies, including the exploration and development of the Midcontinent and potential monetization of saltwater
disposal infrastructure, generating high rates of return from quality assets in our focus areas, estimates of oil and natural gas production, projected capital
expenditures and other costs, liquidity and leverage, debt maturities, price realizations, projected earnings, and hedging strategies. We have based these
forward-looking statements on our current expectations and assumptions and analyses made by us in light of our experience and our perception of historical
trends, current conditions and expected future developments, as well as other factors we believe are appropriate under the circumstances. However, whether
actual results and developments will conform with our expectations and predictions is subject to a number of risks and uncertainties, including the volatility of oil
and natural gas prices, our success in discovering, estimating, and developing oil and natural gas reserves, the availability and terms of capital, our timely
execution of hedge transactions, credit conditions of global capital markets, changes in economic conditions, regulatory changes and other factors, many of
which are beyond our control. We refer you to the discussion of risk factors in Part I, Item 1A – “Risk Factors” of our Annual Report on Form 10-K for the year
ended December 31, 2013 and in comparable “Risk Factors” sections of our Quarterly Reports on Form 10-Q filed after the date of this presentation. All of the
forward-looking statements made in this presentation are qualified by these cautionary statements. The actual results or developments anticipated may not be
realized or, even if substantially realized, they may not have the expected consequences to or effects on our company or our business or operations. Such
statements are not guarantees of future performance and actual results or developments may differ materially from those projected in the forward-looking
statements. We undertake no obligation to update or revise any forward-looking statements.
The SEC permits oil and natural gas companies, in their filings with the SEC, to disclose only proved, probable and possible reserves, as each is defined by the
SEC. At times we use the term "EUR" (estimated ultimate recovery) and refer to their location and potential to provide estimates that the SEC’s guidelines
prohibit us from including in filings with the SEC. These estimates are by their nature more speculative than estimates of proved, probable or possible reserves
and, accordingly, are subject to substantially greater risk of being actually realized by the company. For a discussion of the company’s proved reserves, as
calculated under current SEC rules, we refer you to the company’s Annual Report on Form 10-K referenced above, which is available on our website at
www.sandridgeenergy.com and at the SEC’s website at www.sec.gov.
Regulation G Disclosure: This presentation includes certain non-GAAP financial measures as defined under SEC Regulation G. A reconciliation of those
measures to the most directly comparable GAAP measures is available on our website at www.sandridgeenergy.com.
3. 3
SANDRIDGE MISSION
Premier Mid‐Continent Company
MISSION STATEMENT
Our Mission at SandRidge
is to create the premier,
high-return, growth-oriented,
resource conversion company,
focused in the Mid-Continent
region of the United States.
1
4. a) Non-GAAP financial measure. Refer to the Disclaimer slide for additional
4
disclosure
b) Pro Forma for the Q1’14 Gulf of Mexico divestiture
c) SandRidge consolidated reserves as of YE2013 including royalty trusts
d) Based on YE13 SEC pricing ($93.42/$3.67)
SANDRIDGE COMPANY OVERVIEW
MARKET VALUE ($ in millions)
Market Cap (08/29/2014) $2,590
Net Debt(a) 2,276
Preferred Stock 765
Enterprise Value $5,370
ASSET OVERVIEW(b)(c)
Q2’14 Production (MBoe/d) 69.8
Proved Reserves (MMBoe) 377
% Reserves as Liquids 46%
YE13 PV10 Value ($Bln)(d) $4.1
• Rig counts are projected averages for 2014
www.SandRidgeEnergy.com 2
SD Quick Facts
• Fractured Carbonate Focus
• Mid-Continent, Horizontal
Mississippian Leader
• Sub-$3.0MM/well, 380 MBoe EUR
• Stacked Pay Development
• $1.5Bln Capex Plan
• $919MM Cash at Q2’14
5. 5
INVESTMENT THESIS
3
20+% Production Growth, 30+% EBITDA
Growth & Flattish Capex
• Growth program continues to improve
– New zones (Chester, Woodford), New areas (Garfield)
– Better than type curve results
• Base assets performing well
– Consistent decline ratios, GOR and EURs
• Approximate doubling of production in three years
• Operating leverage yields higher EBITDA growth
• Outspend shrinks year over year
• Plus infrastructure, new zone, and expanding footprint upsides
• Excess liquidity and no bond maturities until 2020
• Pursuing unlock of infrastructure value
Refined Business Model
FOCUSED
Strategy, Execution and Culture
are Focused
COMPETITIVE ADVANTAGE
Established Infrastructure, Sizable
Leasehold and Vast Knowledge Base
ACTIONABLE GROWTH
Confidence in the Drilling Inventory
and Asset Quality
INNOVATION
Team Mindset of Continuous
Improvement
UPSIDES
Multi-zones, Appraisal Areas
and SWD Business
FUNDED
Excellent Liquidity, Leverage,
and Visible Funding into Future
www.SandRidgeEnergy.com
6. * STRIP 8/1/2014
6
ACTIONABLE GROWTH WITH UPSIDES
20+% Production Growth, 30+% EBITDA Growth & Flattish Capex
Stacked Oily Pay Zones
Significant Acreage Position
FOCUSED
*
Improving Already Strong Returns
www.SandRidgeEnergy.com 4
7. ACTIONABLE
• Confident in multi-year
drilling program
• Existing focus area position
provides >4,500 locations
• PDP base decline is flattening
• Assumes average capital
expenditure program of
~$1.55 Bln
• Well cost improvements from
$3.0 to $2.7 MM
7
MULTI‐YEAR PRODUCTION GROWTH
Confidence in Asset Base and Execution
2016 Activity
15 %
Decline
GROWTH
www.SandRidgeEnergy.com 5
8. 8
Q2’14 – CONTINUED STRONG WELL RESULTS RESULTS
Focus and Innovation Yield Exceptional
Operating Results in the Second Quarter
Mississippian Success
• 412 Boe/d 30-day IP, 122 laterals (30% above type curve)
• 7 laterals over 1,000 Boe/d in 4 counties
• Garfield County net production ramped 400% to 5,000 Boe/d in 1H’14
– 407 Boe/d 30-day IP (54% oil), 21 wells
– 7 rig program through YE’14
Chester Success
• 365 Boe/d 30-day IP (69% oil), 9 wells
– 3 rig program through YE’14
Woodford Success
• 360 Boe/d 30-day IP (84% oil)
– New geologic model, second well completing in Q3’14
www.SandRidgeEnergy.com 6
9. 9
• Record low Q2’14 Drilling and Completion (D&C) lateral costs of $2.85 MM
– +$1 MM decrease in capital since Q1 2012
– 97% Electric Submersible Pump (ESP) implementation rate in Q2’14
• Primary D&C cost saving in 2014 linked to innovation championed by SD teams:
– Pad drilling: 80% of Q2’14 wells drilled from multi-well pads
– Multilateral drilling: Stacked and Co-planar Dual Laterals, Trilaterals and
Full Section Development
– Wellsite facilities design improvements:
– Centralized tank batteries
– Commingled tank batteries
– Centralized Salt Water Disposal (SWD) systems
• Record low LOE at $6.69 per Boe
FOCUSED
MATERIAL WELL COST AND LOE REDUCTION
Mississippian Leader
$2.85MM /Well
$6.69 /boe
www.SandRidgeEnergy.com 7
10. 10
TARGETING BREAKOUT ECONOMICS
Ahead of Schedule, Reducing Well Costs INNOVATION
• Already strong well economics improving as costs
come down
• Breakout innovations on well design could both:
– Enhance returns
– Expand focus areas
• Value enhancing projects in motion
– Completion techniques
– Sectional development
– Shared facilities
– Artificial lift management system
• Expand competitive advantages
− Salt water disposal
− Electrical distribution system
• Multi-zone appraisal program
*
* 8/1/2014 STRIP
www.SandRidgeEnergy.com 8
11. 11
2014 MISSISSIPPIAN PUD TYPE CURVE
Actual Performance Consistently Above Type Curve FOCUSED
200
180
160
140
120
100
80
60
40
20
-
0 1 2 3 4 5 6 7 8 9 10
www.SandRidgeEnergy.com 9
350
300
250
200
150
100
50
-
Cumulative Production (Mboe)
Avg. Boe/d
Years
Type Curve Daily Avg. Rate Type Curve Cum Production PDPs
GAS: 1.2 Bcf
30 Day IP(b) (Mcf/day)
1st Year Decline(a)
B Factor
848
65%
1.83
NGL: 64 MBbls
Yield (Bbls/MMcf)
Shrink
47.5
87.3%
Oil: 118 MBo
30 Day IP (Bo/day)
1st Year Decline(a)
B Factor
176
80%
1.41
12. 12
MISSISSIPPIAN WELL PERFORMANCE
Continued Improvement
Type Curve
176 Bbl/d
MULTI-YEAR
GROWTH
www.SandRidgeEnergy.com 10
Type Curve
849 Mcf/d
13. 13
MISSISSIPPIAN WELL EURS
Continued Improvement
MULTI-YEAR
GROWTH
www.SandRidgeEnergy.com 11
20%
18%
16%
14%
12%
10%
8%
6%
4%
2%
0%
% of Wells
1 EURs are as of Year-End 2013
2 EURs are per the Company’s estimates as of Mid-Year 2014
EUR (MBoe)
COMMERCIAL
1 2
1
Wells Prior to 2013 2013 Wells 2014 Wells
14. 14
MID‐CONTINENT FOCUS AREA
Deep Understanding of the Play FOCUSED
100 MILES SD LEASEHOLD
www.SandRidgeEnergy.com 12
• Shallowest Decline Profile
• Higher EUR Distribution
• Geology Most
Understood
• Stacked Pay Potential
• Highest 30 Day Gas IPs
• Low H2O Cut
• Upside as Gas Prices Rise
• Chester Delivering Above
TC Oil Rates
• Multi Laterals Decreasing
per Lateral CAPEX
• High Density Fracs
Potentially Impactful
• 3D Required to Define Fracture Trends
• Positive Multi Lateral Results
• Highest 30 Day Oil IPs
• Highest Liquids %
• Lowest H2O Cut
• Improving EURs with Time
• Dual Laterals Exceeding TC
~650,000 Acres in Focus Area
• Miss Exhibiting Tightest
Performance Distribution
• Unlocked Woodford Potential
• Potential for Extensive Multi
Lateral Development
15. 15
FOCUSED
MULTI‐ZONE DRILLING LOCATIONS
Many Years of Drilling Ahead
Upper Miss
HZ Wells to Sales 849
Locations 2,668
Marmaton
HZ Wells to Sales 1
Locations TBD
Chester
HZ Wells to Sales 5
Locations 180
Middle Miss
HZ Wells to Sales 143
Locations 857
Lower Miss
HZ Wells to Sales 25
Locations 319
Woodford
HZ Wells to Sales 5
Locations 486
High-Graded Locations to Drill 4,510 wells
Emerging Un-Risked Locations >8,000 wells development
www.SandRidgeEnergy.com 13
Note: Drilling location information as of 03/04/14
16. 16
APPLYING SEISMIC TECHNOLOGY
Understanding The Rock INNOVATION
KS
OK
COMPLETED PLANNED SD LEASEHOLD
100 MILES
www.SandRidgeEnergy.com 14
2013 - 730 square miles of 3D data acquired
2014- 1,070 square miles of new 3D data to acquire
2015 - 800 square miles of new 3d data to acquire
Parallel
fault trend
Main fault
trend
17. 17
MULTILATERAL APPROACH IS SUCCESSFUL
Changing how carbonates are developed INNOVATION
Achieving Breakthrough Cost Upsides with Production Uplift
• Multilateral success achieved on three dual stacked laterals and one co-planar
well in Grant, Alfalfa, and Harper counties during Q2’14
www.SandRidgeEnergy.com
• Four wells averaged $2.5 million per lateral
– 83% of type curve cost
– 108% of the type curve 30-day IP
• Six rigs are currently planned to drill multilateral wells through the
second half of the year
• Broader sanction of multilaterals expected in 2015
– 18% of 2H14 wells involve multilaterals (two or more laterals from a
single vertical well)
Dual Stacked Lateral
Co-Planar Dual Lateral
15
18. 18
INNOVATION / UPSIDE
FSD offers up to 34% more section for 26% less
capex
Full Section Development
• Fracture stimulates 34% more interval: 22,000’ vs typically 16,400’ with four single
laterals
• Rock integrity of our carbonates (vs shales or sandstones elsewhere) allows for
effective use of open hole multilaterals
• 130% IRR* to drill and complete a multilateral Full Section Development at
$2.3MM per lateral vs 65% IRR* for a single lateral well at $2.9 MM
• $3.2MM savings per square mile section ($9.1MM vs $12.3MM):
INNOVATION
Full Section Development
(For Illustrative Purposes)
www.SandRidgeEnergy.com
Full Section Development D&C Cost Savings Detail $M
Tank Battery, SWD, Powerline and Connection $ 1,350
Intermediate 7" Casing and ESP Savings (One Each vs Four) $ 1,100
Drilling Location, Rig Move and Reduced Drilling Days $ 1,000
Rentals and Miscellaneous $ 350
Incremental cost to frac an additional ~6000’ of interval $ (600)
Total Savings $3,200
* Strip as of 8/1/14 16
19. Most Efficient
SWG Operator in
the midcontinent
– Various tubing sizes based
produced water for ~80 years
• Frac flowback is < 5% of total
interconnected – maximizing
system flexibility
19
SALTWATER GATHERING & DISPOSAL (SWG) UPSIDES
• Produce
– ~1 million barrels of water per day at mid 2014 from 1,300
Mid-Continent producers
• Gather & Process
– Produced water is transported to disposal location through
SD owned pipeline system
– Typically Polyethylene pipe (8” to 12” diameter) connected
to producing wells, buried under ground
– Water is cleaned and treated at disposal location
• Inject
– + 170 disposal wells as of mid-2014,
adding ~50 wells per year
– Many take water on a vacuum (hydrostatic
pressure is adequate to achieve disposal)
• $590 MM invested by the end of 2014
• Average capacity of 15,000
BWPD per well
– Low pressure pumps at
most locations
on needed capacity
– Open hole Arbuckle
completion
• Pressure and volume
continuously monitored
• Arbuckle has been taking
• Gathering system is
www.SandRidgeEnergy.com 17
Produced water gathered and sequestered into
Arbuckle through cost effective infrastructure
20. 20
FINANCIAL STRENGTH
• Contains Non-GAAP financial measures. Refer to slide 2 for additional disclosure.
a) Leverage Ratio represents Consolidated Leverage Ratio calculated pursuant to the terms of the Senior Credit Facility
b) Liquidity represents the quarter ending cash balance and revolver availability, adjusted for letters of credit
FUNDED
• Excellent cash and liquidity
– $919MM cash at 6/30/14
– Fully undrawn credit facility of $775 MM
– Total liquidity of $1.7 Bln
• Comfortable leverage
– 3.2x Q2’14 leverage ratio
– No near term bond maturities
• Growing cash flow
– Product of 20-25% CAGR production growth
– Keeps leverage in check
– Shrinks capex outspend of cash flow
• Significant oil hedges at strong prices provide
cash flow stability and visibility
www.SandRidgeEnergy.com 18
22. 2014 PRODUCTION GUIDANCE GUIDANCE
www.SandRidgeEnergy.com 22
(A) 2013: 11.3 MMBoe of non-recurring production related to divested Permian and GoM assets
(B) 2014: 1.3 MMBoe of non-recurring production related to divested GoM assets (2/25/2014 closing)
20
23. 23
CREDIT PROFILE
• ~$1.7 Bln liquidity at Q2’14
– $919MM cash
– Fully undrawn credit facility of $775 MM
• 3.2x Q2’14 leverage ratio
• Borrowing base of $775MM undrawn; reserve
value provides for significant increase potential
• Significant oil hedges at strong prices provide
cash flow stability and visibility
• Contains Non-GAAP financial measures. Refer to slide 2 for additional disclosure.
a) Leverage Ratio represents Consolidated Leverage Ratio calculated pursuant to the
terms of the Senior Credit Facility
b) Liquidity represents the quarter ending cash balance and revolver availability,
adjusted for letters of credit
APPENDIX
www.SandRidgeEnergy.com 21
24. 24
CAPITAL STRUCTURE OVERVIEW APPENDIX
Senior Notes Preferred Stock
8.75% Sr Notes due 2020 $445
7.5% Sr Notes due 2021 1,179
8.125% Sr Notes due 2022 750
7.5% Sr Notes due 2023 821
Total $3,195
($ in millions)
8.5% Convertible Perpetual Preferred(a) $265
6.0% Convertible Preferred(b) 200
7.0% Convertible Perpetual Preferred(c) 300
Total $765
Credit Rating Corp Rating Outlook
Credit Rating Corp Outlook
Moody's B1 Stable
S&P B Stable
($ in millions)
(d)
(d)
(a) Convertible at holder’s option at $8.0125 per common share; convertible after Feb 20, 2014 (b) Convertible at holder’s option at $10.856 per common share; automatic conversion after Dec 21, 2014
(c) Convertible at holder’s option at $7.7645 per common share; convertible after Nov 20, 2015 (d) Weighted Average Maturity excludes Credit Facility amounts
www.SandRidgeEnergy.com 22
25. 25
CONSOLIDATED HEDGE POSITION
Q3 2014 ‐ 2016
2014: 95% of Liquids Volumes Hedged 2015: 10.2 MMBBls Liquids volume hedged
97% of liquids revenue hedged
2.1 MMBbls
$99.08/Bbl
4.1 MMBbls
$70.00 -$90.20 -
$100.00/BBL
5.6 MMBBLS
$92.44/BBL
4.6 MMBbls
$76.47 -$90.28 -$103.48/BBL
3-Way
Collars
SWAPS 64%
UNHEDGED
31%
5%
2014: 59% of natural gas volumes Hedged
60% of gas revenue hedged
24.8 BCF
$4.28/MCF
SWAPS UNHEDGED
3-WAY
COLLARS
2015: 16.4 BCF natural gas volumes Hedged
15.4 BCF
$4.50/MCF
SWAPS
58%
UNHEDGED
41%
Collars 1%
0.5 BCF
$4.00-$7.78/MCF
Collars
1.0 BCF
$4.00-$8.55/MCF
SWAPS UNHEDGED
HEDGING
2016: 1.8 MMBBLS Liquids volume hedged
2016: 0 BCF natural gas volumes Hedged
• Positions displayed include royalty trusts and are displayed for July forward. Liquids hedged to NYMEX WTI; Natural Gas hedged to NYMEX Henry Hub; NGL barrels hedged at
3:1 ratio to WTI. 3-way collar and revenue calculations assume $95/bbl WTI and $4.25/Mcf NYMEX gas in 2014 and $90/bbl WTI and $4.25/Mcf NYMEX gas in 2015 and 2016.
UNHEDGED
UNHEDGED
3-Way Collars
1.8 MMBbls
$84.40 -$90.00 -$103.50/BBL
www.SandRidgeEnergy.com 23
26. 26
2013 RESERVE METRICS
Focused On The Mississippian Play APPENDIX
RESERVES PV10
Pro Forma 2013 Excluding Gulf of Mexico Proved Reserves*
SEC Pricing - $93.42 / $3.67
Liquids
MMBbls
Gas
Bcf
Equivalent
MMBoe
% $MM %
Reserves by Reservoir Status
PDP - Producing 88 708 206 55% $ 2,441 59%
PNP - Non Producing 9 57 19 5% 283 7%
PBP - Behind Pipe 1 74 14 4% 73 2%
PUD - Undeveloped 74 384 138 37% 1,306 32%
Total 173 1,223 377 $ 4,103
Reserves by Development
Total Developed 98 839 238 63% 2,797 68%
Total Undeveloped 74 384 138 37% 1,306 32%
Total 173 1,223 377 $ 4,103
434% Reserve Replacement
63% Proved Developed
25% Reserve Growth
$10.19 Organic Drilling F&D
$11.72 All-In F&D
16.7 Years of R/P Life
* Adjusted for Permian & Gulf of Mexico divestitures
• Includes non-controlling royalty trust interests
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2014 MISSISSIPPIAN PUD TYPE CURVE
380 MBoe, 48% Liquids FOCUSED
200
180
160
140
120
100
80
60
40
20
-
350
300
250
200
150
100
50
-
Cumulative Production (Mboe)
Avg. Boe/d
Type Curve EUR YE2013
Oil (Mbo) 118
NGLs (MBbls) 64
Liquids (MBbls) 182
Gas - Shrunk (MMcf) 1,185
MBoe 380
Mcf Shrink 87.3%
NGL Yield (Bbls/MMcf) 47.5
0 1 2 3 4 5 6 7 8 9 10
Years
Type Curve Daily Avg. Rate Type Curve Cum Production
GAS: 1.2 Bcf
30 Day IP(b) (Mcf/day)
1st Year Decline(a)
B Factor
848
65%
1.83
NGL: 64 MBbls
Yield (Bbls/MMcf)
Shrink
47.5
87.3%
Oil: 118 MBo
30 Day IP (Bo/day)
1st Year Decline(a)
B Factor
176
80%
1.41
a) Represents decline from month 1 to month 13
b) Wet gas, wellhead volumes
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2014 OPERATIONAL GUIDANCE UPDATE
PRODUCTION
Oil (MMBbls) 10.7 - 11.3
Natural Gas Liquids (MMBbls) 3.5 - 3.6
Total Liquids (MMBbls) 14.2 - 14.9
Natural Gas (Bcf) 82.6 - 84.6
Total (MMBoe) 28.0 - 29.0
CAPITAL EXPENDITURES ($ in millions)
Exploration and Production $1,230
Land and Seismic 120
Total Exploration and Production $1,350
Oil Field Services 15
Electrical/Midstream 60
General Corporate 50
Total Capital Expenditures (excl. A&D) $1,475
EBITDA from Oilfield Services
and Other ($MM) (a) $30
Adjusted Net Income
Attributable to NCI ($MM) (b) $110
Adjusted EBITDA
Attributable to NCI ($MM) (c) $145
PRICE REALIZATIONS
Oil (differential below WTI) $2.75
NGLs (realized % of WTI) 36%
Gas (differential below Henry Hub) $0.75
COSTS PER BOE
Lifting $11.15 - $13.15
Production Taxes 1.15 - 1.35
DD&A – oil & gas 15.00 - 17.00
DD&A – other 2.20 - 2.40
Total DD&A $17.20 - $19.40
G&A – cash 3.60 - 4.00
G&A – stock 0.65 - 0.80
Total G&A $4.25 - $4.80
Corporate Tax Rate 0%
Deferral Rate 0%
APPENDIX
a) EBITDA from Oilfield Services and Other is a non-GAAP
financial measure as it excludes from net income interest
expense, income tax expense and depreciation, depletion
and amortization. The most directly comparable GAAP
measure for EBITDA from Oilfield Services and Other is
Net Income from Oilfield Services and Other. Information
to reconcile this non-GAAP financial measure to the most
directly comparable GAAP financial measure is not
available at this time, as management is unable to
forecast the excluded items for future periods and/or
does not forecast the excluded items on a segment basis
b) Adjusted Net Income Attributable to Noncontrolling
Interest is a non-GAAP financial measure as it excludes
gain or loss due to changes in fair value of derivative
contracts and gain or loss on sale of assets. The most
directly comparable GAAP measure for Adjusted Net
Income Attributable to Noncontrolling Interest is Net
Income Attributable to Noncontrolling Interest.
Information to reconcile this non-GAAP financial measure
to the most directly comparable GAAP financial measure
is not available at this time, as management is unable to
forecast the excluded items for future periods
c) Adjusted EBITDA Attributable to Noncontrolling Interest
is a non-GAAP financial measure as it excludes from net
income interest expense, income tax expense and
depreciation, depletion and amortization, gain or loss due
to changes in fair value of derivative contracts and gain or
loss on sale of assets. The most directly comparable
GAAP measure for Adjusted EBITDA Attributable to
Noncontrolling Interest is Net Income Attributable to
Noncontrolling Interest. Information to reconcile this non-
GAAP financial measure to the most directly comparable
GAAP financial measure is not available at this time, as
management is unable to forecast the excluded items for
future periods
Introducing a guidance range of 28 – 29 MMBoe or
19 – 23% pro forma production growth for 2014
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WELL COUNTS GROSS NET
Mid-Continent/Mississippian Focus
460 331
Area
Mid-Continent SWD 50 37
Permian 180 176
2014 CAPEX GUIDANCE
($ in millions)
MID-CONTINENT/MISSISSIPPIAN D&C
Focus Area $985
Appraisal 55
SWD Wells 60
Total Mid-Continent/Mississippian D&C $1,100
OTHER MID-CONTINENT/MISSISSIPPIAN
SWD Pipeline/Infrastructure $59
Workovers & Non-Op 89
Land & Seismic 102
Electrical/Midstream 50
Total Other E&P $300
Total Mid-Continent/Mississippian $1,400
($ in millions)
DRILLING AND COMPLETION (D&C)
Mid-Continent/Mississippian $1,040
Mid-Continent SWD Wells 60
Permian 110
Gulf of Mexico / Gulf Coast 10
JV Carry (205)
Total D&C $1,015
OTHER E&P
SWD Pipeline/Infrastructure $71
Workovers & Non-Op 94
Land & Seismic 120
Capitalized G&A and Interest 50
Total Other E&P $335
E&P Capital Expenditures $1,350
NON-E&P
Drilling & Oil Field Services $15
Electrical/Midstream 60
General Corporate 50
Total Non-E&P $125
Total $1,475
APPENDIX
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Our Mission at SandRidge is to create the premier, high-return, growth-oriented,
resource conversion company, focused in the Midcontinent region of the United States.
SANDRIDGE INVESTOR RELATIONS
123 Robert S. Kerr Avenue, Oklahoma City, OK 73102
investors@sandridgeenergy.com
www.SandRidgeEnergy.com