As operators in shale producing regions across the world face uncertainty over oil prices, many E&P companies, big and small are veering increasingly towards more consistent proven plays, with the world famous Permian Basin being at the top of many strategic priorities lists. With both rig count and production per rig growing steadily throughout 2014, and oil production expected to reach an all time high of 2 million bpd in 2015, the most established shale play in the US is showing no signs of slowing down.
The recovery potential in the Permian is not a concern here, but maintaining barrel margins on crude by driving down production and artificial lift costs is now mission-critical. By exchanging the very latest case studies, tried and tested lift technology innovations and failure prevention techniques, operators in the Permian can learn enough to make sure even marginal wells remain economics in 2015.
PERMIAN PRODUCTION OPTIMIZATION - DEDICATED PURELY TO PRODUCTION PROFESSIONALS
The 2nd in the highly rated series, this year's Permian Artificial Lift & Production Optimization 2015 is coming back with the brand new angle of "cutting costs and improving recovery", to guide operators through times of uncertain oil prices.
Renowned for being the most practical, learning focused operator-led production congress in the US, presentations will focus on implementing the right type of artificial lift at the right stage of a well's life, optimizing operability of each lift type, preventing corrosion, paraffin build-up and scale and reducing the costs of water management.
Bakken Artificial Lift & Production Optimization Congress 2014 marketinglbcg
The Bakken success story has continued into 2014, with the latest data showing that wells in the region are now producing over a million barrels of oil per day. However, operators are increasingly aware that with the productivity rate of Bakken wells shown to decline by an average of 70% in the first year, it is vital that they optimize the production phase of their operations if this explosive growth is to be sustained.
Operators in the region therefore increasingly need to know which artificial lift techniques and chemical treatments are working best in the Bakken to cost-effectively maximize production rates.
Building on the sell-out success of the first event in the series, the 2nd Annual Bakken Artificial Lift & Production Optimization Congress 2014 will again bring together Bakken's leading E&Ps for the only dedicated congress for production professionals in the Bakken, focusing on artificial lift, chemical treatments & production optimization.
Featuring a totally revamped agenda for 2014, the event this year will present 20+ brand new case studies based on work done in the last year. Speakers will be examining technical solutions for reducing failure rates, maximizing productivity & improving run times by optimizing artificial lift design & chemical treatments for Bakken wells & overcoming challenges relating to sand control, gas interference & wellbore deviation.
Artificial Lift Optimization - North America Congress 2016marketinglbcg
Assessing Selection Criteria For Artificial Lift Systems In Horizontal Wells: Fully Optimizing Rod Pump, Gas Lift Plunger Lift & Artificial Lift Techniques
Increase Production Efficiency, Reduce Equipment/Energy Costs And Mitigate Failures
This is presentation given by PG&E representatives about a large Liquified Natural Gas (LNG) project being developed in Felton, CA. This project is one of the largest ever developed in the industry.
Bakken Artificial Lift & Production Optimization Congress 2014 marketinglbcg
The Bakken success story has continued into 2014, with the latest data showing that wells in the region are now producing over a million barrels of oil per day. However, operators are increasingly aware that with the productivity rate of Bakken wells shown to decline by an average of 70% in the first year, it is vital that they optimize the production phase of their operations if this explosive growth is to be sustained.
Operators in the region therefore increasingly need to know which artificial lift techniques and chemical treatments are working best in the Bakken to cost-effectively maximize production rates.
Building on the sell-out success of the first event in the series, the 2nd Annual Bakken Artificial Lift & Production Optimization Congress 2014 will again bring together Bakken's leading E&Ps for the only dedicated congress for production professionals in the Bakken, focusing on artificial lift, chemical treatments & production optimization.
Featuring a totally revamped agenda for 2014, the event this year will present 20+ brand new case studies based on work done in the last year. Speakers will be examining technical solutions for reducing failure rates, maximizing productivity & improving run times by optimizing artificial lift design & chemical treatments for Bakken wells & overcoming challenges relating to sand control, gas interference & wellbore deviation.
Artificial Lift Optimization - North America Congress 2016marketinglbcg
Assessing Selection Criteria For Artificial Lift Systems In Horizontal Wells: Fully Optimizing Rod Pump, Gas Lift Plunger Lift & Artificial Lift Techniques
Increase Production Efficiency, Reduce Equipment/Energy Costs And Mitigate Failures
This is presentation given by PG&E representatives about a large Liquified Natural Gas (LNG) project being developed in Felton, CA. This project is one of the largest ever developed in the industry.
This presentation contains an overview of tracking plant performance, with its application in two case studies, including gas compression train monitoring (Aspen) and production facility surveillance system (HYSYS).
Raventech & University of North West presentation - emperors - 9 nov 2016-...John M Riggs
Naf-Tech combustion enhancer is a South-African product. Naf-Tech is a proprietary mixture of hydrocarbons that reduces the surface tension of the fuel when activated. Targeted activation ensures that Naf-Tech will not alter the distinct characteristics of the base fuel before the physical injection of the fuel takes place.
Naf-Tech improves fuel vaporisation during injection thereby increasing the burn velocity of the fuel transforming more of the fuel’s potential energy into mechanical energy. Naf-Tech is widely used in various applications such as transport, mining, earthmoving, diesel generators and shipping.
Naf-Tech is used by a number of companies, some of which are listed on the JSE. The majority of these companies have been using Naf-Tech for several years and have also concluded successful R&D programs using Naf-Tech.
6. Process forward
Should you wish to engage with us on drastically reducing your company’s energy efficiency (and carbon footprint) as described above please note that we do not enter into a “proof of testing-period” without payment. We have been testing and proving our product’s quality for over a decade. For this reason, a minimum order of 2000 lt/month is required for a 3 month period. Upon payment of the first order we will provide assistance to you through a team of experts to help you achieve maximum benefit from our product.
Should you find the above in order we look forward to hearing from you.
Export development by John M Riggs and Yuliya Lutsenko - contact via jophnmriggs@gmail.com and carbon copy at john.riggs@swiss-commodity.ch
Collaborative Working helps assets to operate more efficiently and as one team, resulting in higher production, less cost, lower HSE exposure and higher morale. Shell has pursued the Digital Oilfield for the last fifteen years, under the heading of Smart Fields. Collaborative Work Environments (CWEs) were implemented in the majority of assets, live environments now cover over 60% of Shell’s production. The presentation will provide an overview of current Collaborative Work Environments. It will show examples of CWEs in different types of assets, and of the business value achieved. The large scale implementation was achieved through a structured deployment programme, taking assets and projects through a standard design, implementation and embedding approach. To embed and sustain the new ways of working, a focus on the people aspects and change management has been critical. Each project included process design, awareness and training sessions and establishing coaches, support and continuous improvement.
Frans van den Berg is currently an independent consultant in the design of Digital Oilfields and Collaborative Work Environments. He has worked 32 years in Shell, lastly in its global Smart Fields or Digital Oilfield program in the technology organisation in the Netherlands. There he led the global implementation of Collaborative Work Environments in Shell. He has held various positions as a petroleum engineer, head of petrohysics and asset development leader in operational roles and in global technology deployment. He worked ten years in Malaysia and Thailand. Frans has a PhD and a Master in Physics from Leiden University in the Netherlands. He has been involved in the organisation of the SPE Intelligent Energy and Digital Energy Conferences since 2008.
Artificial Lift Screening and Selection - Focus on Reservoir ConsiderationsAndres Martingano
Break-out session presentation to discuss the influence of reservoir aspects on the selection of an artificial lift system. prepared for Praxis' Interactive Technology Workshop on Artificial Lift, Dubai, September 2013.
Using Aspen HYSYS Upstream for Sizing and Scheduling of Gathering SystemsProcess Ecology Inc
This presentation covers the process of sizing and scheduling of Gathering Systems, including how to approach challenges by using model development and automation and interpretation of the results. Additionally, we compare between HYSYS Hydraulics and HYSYS Dynamics.
Brandon Milar, P.E., Director of Technical Services for CalAPA, delivers a technical presentation on Warm Mix Asphalt standards and technology at the CalAPA Spring Asphalt Pavement Conference & Equipment Expo, April 12-13, 2017 in Ontario, Calif.
Gas Technology Institute & Kwik Trip - Station Installation Guidelines for CNGWisconsin Clean Cities
Are you interested in the station installation guidelines for CNG? Learn about the basics guidelines, processes, and experiences of installing a CNG station.
In Situ Oil Sands SOR Reduction Initiativephilbrown49
Brochure of the In Situ Oil Sands SOR Reduction Initiative 2013.
http://www.oil-sands-sor-reduction-2013.com/
The mission of the In Situ Oil Sands SOR Reduction Initiative 2013 is to uncover the latest steam injection techniques, recovery technologies, water treatment technologies and production techniques through knowledge sharing between industry innovators. The conference will see experienced operators delivering presentations on their successes and failures on trials for novel steam generation and oil recovery practices.
The Marcellus play has been drilled and completed for many years and this congress isn't aiming to recall what operators already know. Liquid Rich Horizontal Completions Optimization: Marcellus & Utica 2014 is focused entirely on exploiting remaining high value, liquid rich opportunities that lie within the play in light of gas prices, and optimizing increasing opportunities in the Utica.
OPTIMIZING NPV IN LIQUID RICH MARCELLUS WELLS
The current gas price situation in the US however, means Marcellus operators need to be ahead of the game by developing highly advanced techniques for making marginal wells economic and developing completions strategies for optimizing liquid recovery. Operators are now actively making progress in reducing cluster spacing and optimizing stage and lateral lengths in liquid rich reservoirs to ensure incremental cost and performance gains. Due to the increasing number of trials measuring changes in such variables, the industry at large is now at a point where findings and information sharing could lead to significant commercial gains.
MAXIMIZING SRV AND WELL ECONOMICS IN HIGH PRESSURED UTICA WELLS
The liquid rich Utica is arguably an easy win for Marcellus operators and many are already seeing significant production successes due to the delivery of optimal completions techniques. However, the increase in near wellbore stimulation and lateral lengths, in the dense, typically higher-pressured, Utica wells, present their own cost challenges. These include ensuring the availability and development of higher PSI rated equipment, developing extended lateral completions strategies and creating frac designs suitable for high pressure wells; challenges that are often easily overcome by hearing what others have already failed and succeeded at.
A CONGRESS DEDICATED TO IDENTIFYING WHICH COMPLETIONS TECHNIQUES AND DESIGNS ARE DELIVERING THE GREATEST NPV IN LIQUID RICH MARCELLUS AND UTICA WELLS
The primary mission of the Liquid Rich Horizontal Completions Optimization: Marcellus & Utica 2014 congress is to determine which advanced completion techniques are being used by leading operators to improve well economics in the Appalachian Basin. Over two days, leading completions managers and experts from E&P companies will be delivering data driven strategies to optimize overall recovery by identifying which well design and frac design parameters are contributing most to production in liquid rich, marginal and high pressured wells in the Marcellus and Utica.
Case studies delivered over the two days include operator strategies for cluster spacing reduction, stage length and lateral length optimization, pump rate and proppant concentration decision making and perforation techniques to optimize completions design to maximize SRV and decrease operational costs in the Marcellus and Utica.
3% of wells in Canada were drilled horizontally in the first quarter of 2014, up from 66% in the first quarter of 2013 and 55% in 2012.
But Canadian E&P companies are not only drilling more and more horizontal wells, they also drill longer and longer laterals and are simultaneously finding ways of driving down ROP. With the pressure to drill faster and cheaper and the uncertainties, risks and opportunities that the advances in technology provide to drill longer and deeper it is critical to look at what E&P companies have done to increase ROP and achieve optimal cost-per-foot for horizontal drilling operations in the WCSB.
To help operators achieve these goals, the 3rd Annual Horizontal Drilling Canada 2014 will be bringing together over 20 exclusively E&P operators, sharing case histories based on recent horizontal drilling operations in the WCSB, with a focus on applications in the Cardium, Montney, Duvernay, Horn River, Viking and Canadian Bakken. It will be the only congress 100% dedicated to drilling professionals working on horizontal wells in Canada's key basins.
Leading operators will be breaking down the latest advances in horizontal drilling technologies and techniques, determining the optimal lateral length for horizontal wells in terms of cost-per-foot, evaluating which drilling fluids can deliver higher ROP in which plays and evaluating how the latest downhole tools, drill bits and casing designs can be utilized to cost-effectively maximize production.
2nd Annual Well Site Automation Congress - ProgramAsh Robins
Returning with a brand new speaker line-up and a fully revamped agenda, The 2nd Annual Well Site Automation Congress will come to Houston on January 27 and 28, with the express purpose of addressing the most pressing concerns in reaping low production costs and maximum efficiency.
The congress will assess in fine detail several pump by exception strategies to ensure that operators have enough visibility in their SCADA to monitor multiple well locations with a minimum of man-hours.
Featuring a host of end user-led case studies from Chevron, Apache, BHP Billiton, Devon Energy, EXCO Resources, Encana, Petro Lucrum, Zaza Energy, Endurance Resources among others, the congress will guarantee valuable lessons to delegates whether they oversee 100% automated operations or are taking a first tentative step towards the process.
Workover Optimization & Horizontal Well Intervention 2014LBCG
With unconventional wells typically depleting 65-85% in the first year and another 20% in the subsequent years, there is a growing impetus to optimize and innovate workover and well intervention operations to improve the life of existing wells and restore production to maximize the recovery of costly unconventional wells.
Innovations in coiled tubing, conveyance, eline and logging tools and the introduction of techniques for re-completions may ensure that depleting wells can be recovered and production maximized but such operations are not without significant cost implications and technical challenges. Unpredictable complications throughout production including damaged casing, blocked perforations and broken and lost equipment downhole incur great risk, come at a high cost to repair and can, of course, result in complete failure of the well. Additionally, the economic viability of re-completions operations is still relatively unknown and the technical challenges of re-fracturing are complex.
Operators therefore need to carefully consider the economic gamble in repairing a depleting well or potential in-fill drilling operations against the cost of drilling a new well. A balance must be struck between optimizing the cost and speed of workovers and remedial well intervention, while increasing the long-term effectiveness and safety of operations to reduce the economic risk of repairing wellbores and adequately extend the production time between workovers.
The Workover Optimization & Horizontal Well Intervention 2014 is the only E&P led forum to provide technical talks and case study based strategies on effective optimization and cost reduction of both workovers and remedial well interventions. Senior E&P presenters will examine techniques for optimizing plug drillouts, cleanouts, coiled tubing interventions, casing repairs and fishing and evaluate how to enable re-completions in depleting wells. The content of the detailed two-day agenda has been created entirely by workover and intervention professional across American unconventional oil and gas operators.
This presentation contains an overview of tracking plant performance, with its application in two case studies, including gas compression train monitoring (Aspen) and production facility surveillance system (HYSYS).
Raventech & University of North West presentation - emperors - 9 nov 2016-...John M Riggs
Naf-Tech combustion enhancer is a South-African product. Naf-Tech is a proprietary mixture of hydrocarbons that reduces the surface tension of the fuel when activated. Targeted activation ensures that Naf-Tech will not alter the distinct characteristics of the base fuel before the physical injection of the fuel takes place.
Naf-Tech improves fuel vaporisation during injection thereby increasing the burn velocity of the fuel transforming more of the fuel’s potential energy into mechanical energy. Naf-Tech is widely used in various applications such as transport, mining, earthmoving, diesel generators and shipping.
Naf-Tech is used by a number of companies, some of which are listed on the JSE. The majority of these companies have been using Naf-Tech for several years and have also concluded successful R&D programs using Naf-Tech.
6. Process forward
Should you wish to engage with us on drastically reducing your company’s energy efficiency (and carbon footprint) as described above please note that we do not enter into a “proof of testing-period” without payment. We have been testing and proving our product’s quality for over a decade. For this reason, a minimum order of 2000 lt/month is required for a 3 month period. Upon payment of the first order we will provide assistance to you through a team of experts to help you achieve maximum benefit from our product.
Should you find the above in order we look forward to hearing from you.
Export development by John M Riggs and Yuliya Lutsenko - contact via jophnmriggs@gmail.com and carbon copy at john.riggs@swiss-commodity.ch
Collaborative Working helps assets to operate more efficiently and as one team, resulting in higher production, less cost, lower HSE exposure and higher morale. Shell has pursued the Digital Oilfield for the last fifteen years, under the heading of Smart Fields. Collaborative Work Environments (CWEs) were implemented in the majority of assets, live environments now cover over 60% of Shell’s production. The presentation will provide an overview of current Collaborative Work Environments. It will show examples of CWEs in different types of assets, and of the business value achieved. The large scale implementation was achieved through a structured deployment programme, taking assets and projects through a standard design, implementation and embedding approach. To embed and sustain the new ways of working, a focus on the people aspects and change management has been critical. Each project included process design, awareness and training sessions and establishing coaches, support and continuous improvement.
Frans van den Berg is currently an independent consultant in the design of Digital Oilfields and Collaborative Work Environments. He has worked 32 years in Shell, lastly in its global Smart Fields or Digital Oilfield program in the technology organisation in the Netherlands. There he led the global implementation of Collaborative Work Environments in Shell. He has held various positions as a petroleum engineer, head of petrohysics and asset development leader in operational roles and in global technology deployment. He worked ten years in Malaysia and Thailand. Frans has a PhD and a Master in Physics from Leiden University in the Netherlands. He has been involved in the organisation of the SPE Intelligent Energy and Digital Energy Conferences since 2008.
Artificial Lift Screening and Selection - Focus on Reservoir ConsiderationsAndres Martingano
Break-out session presentation to discuss the influence of reservoir aspects on the selection of an artificial lift system. prepared for Praxis' Interactive Technology Workshop on Artificial Lift, Dubai, September 2013.
Using Aspen HYSYS Upstream for Sizing and Scheduling of Gathering SystemsProcess Ecology Inc
This presentation covers the process of sizing and scheduling of Gathering Systems, including how to approach challenges by using model development and automation and interpretation of the results. Additionally, we compare between HYSYS Hydraulics and HYSYS Dynamics.
Brandon Milar, P.E., Director of Technical Services for CalAPA, delivers a technical presentation on Warm Mix Asphalt standards and technology at the CalAPA Spring Asphalt Pavement Conference & Equipment Expo, April 12-13, 2017 in Ontario, Calif.
Gas Technology Institute & Kwik Trip - Station Installation Guidelines for CNGWisconsin Clean Cities
Are you interested in the station installation guidelines for CNG? Learn about the basics guidelines, processes, and experiences of installing a CNG station.
In Situ Oil Sands SOR Reduction Initiativephilbrown49
Brochure of the In Situ Oil Sands SOR Reduction Initiative 2013.
http://www.oil-sands-sor-reduction-2013.com/
The mission of the In Situ Oil Sands SOR Reduction Initiative 2013 is to uncover the latest steam injection techniques, recovery technologies, water treatment technologies and production techniques through knowledge sharing between industry innovators. The conference will see experienced operators delivering presentations on their successes and failures on trials for novel steam generation and oil recovery practices.
The Marcellus play has been drilled and completed for many years and this congress isn't aiming to recall what operators already know. Liquid Rich Horizontal Completions Optimization: Marcellus & Utica 2014 is focused entirely on exploiting remaining high value, liquid rich opportunities that lie within the play in light of gas prices, and optimizing increasing opportunities in the Utica.
OPTIMIZING NPV IN LIQUID RICH MARCELLUS WELLS
The current gas price situation in the US however, means Marcellus operators need to be ahead of the game by developing highly advanced techniques for making marginal wells economic and developing completions strategies for optimizing liquid recovery. Operators are now actively making progress in reducing cluster spacing and optimizing stage and lateral lengths in liquid rich reservoirs to ensure incremental cost and performance gains. Due to the increasing number of trials measuring changes in such variables, the industry at large is now at a point where findings and information sharing could lead to significant commercial gains.
MAXIMIZING SRV AND WELL ECONOMICS IN HIGH PRESSURED UTICA WELLS
The liquid rich Utica is arguably an easy win for Marcellus operators and many are already seeing significant production successes due to the delivery of optimal completions techniques. However, the increase in near wellbore stimulation and lateral lengths, in the dense, typically higher-pressured, Utica wells, present their own cost challenges. These include ensuring the availability and development of higher PSI rated equipment, developing extended lateral completions strategies and creating frac designs suitable for high pressure wells; challenges that are often easily overcome by hearing what others have already failed and succeeded at.
A CONGRESS DEDICATED TO IDENTIFYING WHICH COMPLETIONS TECHNIQUES AND DESIGNS ARE DELIVERING THE GREATEST NPV IN LIQUID RICH MARCELLUS AND UTICA WELLS
The primary mission of the Liquid Rich Horizontal Completions Optimization: Marcellus & Utica 2014 congress is to determine which advanced completion techniques are being used by leading operators to improve well economics in the Appalachian Basin. Over two days, leading completions managers and experts from E&P companies will be delivering data driven strategies to optimize overall recovery by identifying which well design and frac design parameters are contributing most to production in liquid rich, marginal and high pressured wells in the Marcellus and Utica.
Case studies delivered over the two days include operator strategies for cluster spacing reduction, stage length and lateral length optimization, pump rate and proppant concentration decision making and perforation techniques to optimize completions design to maximize SRV and decrease operational costs in the Marcellus and Utica.
3% of wells in Canada were drilled horizontally in the first quarter of 2014, up from 66% in the first quarter of 2013 and 55% in 2012.
But Canadian E&P companies are not only drilling more and more horizontal wells, they also drill longer and longer laterals and are simultaneously finding ways of driving down ROP. With the pressure to drill faster and cheaper and the uncertainties, risks and opportunities that the advances in technology provide to drill longer and deeper it is critical to look at what E&P companies have done to increase ROP and achieve optimal cost-per-foot for horizontal drilling operations in the WCSB.
To help operators achieve these goals, the 3rd Annual Horizontal Drilling Canada 2014 will be bringing together over 20 exclusively E&P operators, sharing case histories based on recent horizontal drilling operations in the WCSB, with a focus on applications in the Cardium, Montney, Duvernay, Horn River, Viking and Canadian Bakken. It will be the only congress 100% dedicated to drilling professionals working on horizontal wells in Canada's key basins.
Leading operators will be breaking down the latest advances in horizontal drilling technologies and techniques, determining the optimal lateral length for horizontal wells in terms of cost-per-foot, evaluating which drilling fluids can deliver higher ROP in which plays and evaluating how the latest downhole tools, drill bits and casing designs can be utilized to cost-effectively maximize production.
2nd Annual Well Site Automation Congress - ProgramAsh Robins
Returning with a brand new speaker line-up and a fully revamped agenda, The 2nd Annual Well Site Automation Congress will come to Houston on January 27 and 28, with the express purpose of addressing the most pressing concerns in reaping low production costs and maximum efficiency.
The congress will assess in fine detail several pump by exception strategies to ensure that operators have enough visibility in their SCADA to monitor multiple well locations with a minimum of man-hours.
Featuring a host of end user-led case studies from Chevron, Apache, BHP Billiton, Devon Energy, EXCO Resources, Encana, Petro Lucrum, Zaza Energy, Endurance Resources among others, the congress will guarantee valuable lessons to delegates whether they oversee 100% automated operations or are taking a first tentative step towards the process.
Workover Optimization & Horizontal Well Intervention 2014LBCG
With unconventional wells typically depleting 65-85% in the first year and another 20% in the subsequent years, there is a growing impetus to optimize and innovate workover and well intervention operations to improve the life of existing wells and restore production to maximize the recovery of costly unconventional wells.
Innovations in coiled tubing, conveyance, eline and logging tools and the introduction of techniques for re-completions may ensure that depleting wells can be recovered and production maximized but such operations are not without significant cost implications and technical challenges. Unpredictable complications throughout production including damaged casing, blocked perforations and broken and lost equipment downhole incur great risk, come at a high cost to repair and can, of course, result in complete failure of the well. Additionally, the economic viability of re-completions operations is still relatively unknown and the technical challenges of re-fracturing are complex.
Operators therefore need to carefully consider the economic gamble in repairing a depleting well or potential in-fill drilling operations against the cost of drilling a new well. A balance must be struck between optimizing the cost and speed of workovers and remedial well intervention, while increasing the long-term effectiveness and safety of operations to reduce the economic risk of repairing wellbores and adequately extend the production time between workovers.
The Workover Optimization & Horizontal Well Intervention 2014 is the only E&P led forum to provide technical talks and case study based strategies on effective optimization and cost reduction of both workovers and remedial well interventions. Senior E&P presenters will examine techniques for optimizing plug drillouts, cleanouts, coiled tubing interventions, casing repairs and fishing and evaluate how to enable re-completions in depleting wells. The content of the detailed two-day agenda has been created entirely by workover and intervention professional across American unconventional oil and gas operators.
Energy efficiency: a profit center for companies! Leonardo ENERGY
Investments in energy efficiency not only result in a reduction of energy consumption —the ener-gy benefit— but they also entail non-energy benefits such as improved product quality, reduced production time or improved comfort in sales area. Non-energy benefits significantly improve the business case of energy-efficiency investments in the business sector by raising their strategic character.
Within this context, the aim of this webinar is to discuss a methodology to describe and analyze the industrial non-energy benefits of energy efficiency. Linking energy, operational, strategic and fi-nancial aspects, this new conceptual framework enables to move away from the common view of energy as a commodity (where the only goal is to save kilowatt-hours) to adopt a new perspective on energy and energy services as strategic value for businesses.
This methodology will be further developed and documented by Task 26 Multiple Benefits of Ener-gy Efficiency, a project of IEA Demand Side Management Energy Efficiency Technology Collabora-tion Program, in close collaboration with practitioners, academic researchers and public program-mers. People or Institutions interested by Task 26 are most welcome to contact me.
Multiple benefits will also be discussed in-depth with a panel at this year’s IEPPEC June 7-9 Am-sterdam.
Energy efficiency: a profit center for companies!Leonardo ENERGY
Investments in energy efficiency not only result in a reduction of energy consumption —the energy benefit— but they also entail non-energy benefits such as improved product quality, reduced production time or improved comfort in sales area. Non-energy benefits significantly improve the business case of energy-efficiency investments in the business sector by raising their strategic character.
Within this context, the aim of this webinar is to discuss a methodology to describe and analyze the industrial non-energy benefits of energy efficiency. Linking energy, operational, strategic and financial aspects, this new conceptual framework enables to move away from the common view of energy as a commodity (where the only goal is to save kilowatt-hours) to adopt a new perspective on energy and energy services as strategic value for businesses.
This methodology will be further developed and documented by Task 26 Multiple Benefits of Energy Efficiency, a project of IEA Demand Side Management Energy Efficiency Technology Collaboration Program, in close collaboration with practitioners, academic researchers and public programmers. People or Institutions interested by Task 26 are most welcome to contact me.
Multiple benefits will also be discussed in-depth with a panel at this year’s IEPPEC June 7-9 Amsterdam.
Adapting Project Productivity to a Different World of Competition by Harry Be...AVEVA Group plc
The oil & gas industry faces long-term price pressures from new competitors and future project portfolios need to be scalable and flexible, avoiding the high risks, costs, and poor productivity of the past. Lessons in efficient manufacturing will need to be learned. Industry expert, Harry Benham, formerly Shell, explains how to put energy projects back on track and discusses the 5 key actions to catalyze reduction in project size and complexity and increase performance.
Find out more how AVEVA can transform your business here >> www.aveva.com
Niobrara Completions & Well Spacing Congress 2014marketinglbcg
Oil production in the Niobrara has almost doubled from less than 200 barrels per day in 2012 to almost 400 barrels per day in 2014, whilst rig counts have more than tripled from 20 to 70 in the same period. This rapid expansion is only set to accelerate, with latest reports showing that Niobrara operators collectively are expected to invest over $7 billion in the play in the next year.
With most of the key acreage bought up and sweet spots now identified, the focus of operators in the Niobrara has now moved to maximizing the productivity and economics of their wells. To do this they need to identify the optimal well spacing, completions techniques and lateral lengths to drive increased production rates.
The inaugural Niobrara Completions & Well Spacing Congress 2014 will be the first event to gather up-to-the-minute case studies from the leading E&Ps in the Niobrara to determine the completions and well spacing strategies that are optimizing productivity in the play. Consisting 100% of operator case studies using real life production data, each presentation will be from work done specifically in the play.
The right pressure transmitter can enhance production. The key to maximizing the return on oil and gas development projects rests with the maintenance and safety of your—sometimes—aging equipment.
Similar to Permian Artificial Lift & Production Optimization 2015 (20)
Attending a job Interview for B1 and B2 Englsih learnersErika906060
It is a sample of an interview for a business english class for pre-intermediate and intermediate english students with emphasis on the speking ability.
RMD24 | Debunking the non-endemic revenue myth Marvin Vacquier Droop | First ...BBPMedia1
Marvin neemt je in deze presentatie mee in de voordelen van non-endemic advertising op retail media netwerken. Hij brengt ook de uitdagingen in beeld die de markt op dit moment heeft op het gebied van retail media voor niet-leveranciers.
Retail media wordt gezien als het nieuwe advertising-medium en ook mediabureaus richten massaal retail media-afdelingen op. Merken die niet in de betreffende winkel liggen staan ook nog niet in de rij om op de retail media netwerken te adverteren. Marvin belicht de uitdagingen die er zijn om echt aansluiting te vinden op die markt van non-endemic advertising.
3.0 Project 2_ Developing My Brand Identity Kit.pptxtanyjahb
A personal brand exploration presentation summarizes an individual's unique qualities and goals, covering strengths, values, passions, and target audience. It helps individuals understand what makes them stand out, their desired image, and how they aim to achieve it.
Enterprise Excellence is Inclusive Excellence.pdfKaiNexus
Enterprise excellence and inclusive excellence are closely linked, and real-world challenges have shown that both are essential to the success of any organization. To achieve enterprise excellence, organizations must focus on improving their operations and processes while creating an inclusive environment that engages everyone. In this interactive session, the facilitator will highlight commonly established business practices and how they limit our ability to engage everyone every day. More importantly, though, participants will likely gain increased awareness of what we can do differently to maximize enterprise excellence through deliberate inclusion.
What is Enterprise Excellence?
Enterprise Excellence is a holistic approach that's aimed at achieving world-class performance across all aspects of the organization.
What might I learn?
A way to engage all in creating Inclusive Excellence. Lessons from the US military and their parallels to the story of Harry Potter. How belt systems and CI teams can destroy inclusive practices. How leadership language invites people to the party. There are three things leaders can do to engage everyone every day: maximizing psychological safety to create environments where folks learn, contribute, and challenge the status quo.
Who might benefit? Anyone and everyone leading folks from the shop floor to top floor.
Dr. William Harvey is a seasoned Operations Leader with extensive experience in chemical processing, manufacturing, and operations management. At Michelman, he currently oversees multiple sites, leading teams in strategic planning and coaching/practicing continuous improvement. William is set to start his eighth year of teaching at the University of Cincinnati where he teaches marketing, finance, and management. William holds various certifications in change management, quality, leadership, operational excellence, team building, and DiSC, among others.
Premium MEAN Stack Development Solutions for Modern BusinessesSynapseIndia
Stay ahead of the curve with our premium MEAN Stack Development Solutions. Our expert developers utilize MongoDB, Express.js, AngularJS, and Node.js to create modern and responsive web applications. Trust us for cutting-edge solutions that drive your business growth and success.
Know more: https://www.synapseindia.com/technology/mean-stack-development-company.html
Cracking the Workplace Discipline Code Main.pptxWorkforce Group
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Permian Artificial Lift & Production Optimization 2015
1. The Only Case Study Exchange Designed Specifically
For Production Professionals In The Permian
How Production Engineers Are Ensuring Wells Remain
Economical In Light Of Changing Oil Prices:
Evaluating How To Drive Down The Costs
Of Production And Prevent Well Failures
In The Permian Through Optimization Of
Artificial Lift, Chemical Programs And
Water Disposal
KEY TOPICS INCLUDE:
March 31 - April 1 | Houston | Texas
EXPERT E&P SPEAKERS INCLUDE:
M Follow us @UnconventOilGas
www.permian-production.com
Register By Friday
February 6, 2015
SAVE
$200
• PRODUCTION ECONOMICS: Examining how E&P companies are optimizing
recovery and reducing expenditure in the most costly areas of production to ensure
wells remain economical in light of changing oil prices
• ARTIFICIAL LIFT SELECTION: Comparing the trade offs between ESPs and gas lift
to determine which is most economical in the Wolfcamp: Higher production rates
vs. lower failure rates
• ROD PUMPING THE CURVE: Identifying best practices for placing rod pumps in the
lateral to mitigate premature wearing when pumping the curve
• COST REDUCTION PANEL: Isolating crucial areas of production that can drive down
the break-even point in response to changing oil prices and create greater efficiency
within production
• REDUCING PUMP FAILURES: Assessing how Permian operators are reducing the
costs of failure prevention through corrosion inhibition, gas separator designs and
paraffin prevention
• MANAGING H2S TO REDUCE EQUIPMENT FAILURES: Examining where H2S is
produced and which materials and equipment can drive down the cost of
H2S-related failures
Mark Linroth
Engineering Manager
Kinder Morgan
Organized By:
Partner Sponsor: Co-Sponsor:
Don Ritter
CEO & Co-Founder
Endurance Resources
Alan Barksdale
CEO
Red Mountain Resources
Ben Bloys
Manager - Los Alamos
Technology Alliance
Chevron
Alex Freeman
Senior Production Engineer
ConocoPhillips
Mark Mahoney
Artificial Lift Adviser
Oxy
Youness El Fadili
Production Engineer
Oxy
Greg Darby
Chemical Advisor
Opal Resources
*
2. • COST REDUCTION PANEL: Isolating crucial areas of
production that can drive down the break-even point
in response to changing oil prices and create greater
efficiency within production
• PRODUCTION ECONOMICS: Examining how E&P
companies are optimizing recovery and reducing
expenditure in the most costly areas of production to
ensure wells remain economical in light of changing
oil prices
• REDUCING PUMP FAILURES: Assessing how
Permian operators are reducing the costs of failure
prevention through corrosion inhibition, gas separator
designs and paraffin prevention
• PLAY SPECIFIC CASE STUDIES: This congress takes
into consideration the crucial issues that are unique to
specific locations from the Cline to the Wolfcamp to the
Spraberry to enable operators to increase efficiency
and recovery rates in different locations
WHAT’S NEW FOR THIS YEAR?
PERMIAN PRODUCTION OPTIMIZATION - DEDICATED
PURELY FOR PRODUCTION PROFFESIONALS
The 2nd in the highly rated series, this year’s Permian
Artificial Lift & Production Optimization 2015 is
coming back with the brand new angle of ‘cutting costs
and improving recovery’, to guide operators through
times of uncertain oil prices.
Renowned for being the most practical, learning focused
operator-led production congress in the US, presentations
will focus on implementing the right type of artificial lift at
the correct stage of a wells life, optimizing operability of
each lift type, preventing corrosion, paraffin build-up and
scale and reducing the costs of water management.
As operators in shale producing regions across the world
face uncertainty over oil prices, many E&P companies
big and small are veering increasingly towards more
consistent proven plays, with the world famous Permian
Basin being at the top of many strategic priorities lists.
With both rig count and production per rig growing
steadily throughout 2014, and oil production expected
to reach an all time high of 2 million bpd in 2015, the most
established shale play in the US is showing no signs of
slowing down.
The recovery potential in the Permian isn’t a concern here
but maintaining barrel margins on crude by driving
down production and artificial lift costs is now
mission-critical. By exchanging between operators the
very latest case studies, tried and tested lift technology
innovations and failure prevention techniques, operators
in the Permian can learn enough to make sure even
marginal wells remain economics in 2015.
www.permian-production.com (1) 800 721 3915 info@american-business-conferences.com
Register By Friday
February 6, 2015
SAVE
$200
*
3. LEARNING HOW TO SELECT AND OPTIMIZE ARTIFICIAL LIFT METHODS AT THE LOWEST
POSSIBLE COST TO MAXIMIZE ECONOMICAL RECOVERY IN THE PERMIAN
Day 1
Tuesday March 31, 2015
8.30 Chair’s Opening Remarks
Chairedby:AlanBarksdale,CEO,RedMountainResources
KEYNOTE: PRODUCTION ECONOMICS
8.40 Examining How E&P Companies Are Optimizing Recovery And Reducing
Expenditure In The Most Costly Areas Of Production To Ensure Wells Remain
Economical In Light Of Changing Oil Prices
• Production Rates: Using case studies with production data to determine whether high IPR or
sustained production over a longer term is delivering higher ultimate recovery in Permian wells
• Artificial Lift Selection: Quantifying the extent to which ultimate production was increased
between wells in the same play due to a change in artificial lift strategy
• Failure Reduction: Quantifying the extent to which chemical, mechanical and design methods
have reduced failures between wells to determine which are proving most effective
• Power: Understanding which power supply channels are driving down the costs of power supply
to minimize operational costs in Permian wells
DonRitter,CEO&Co-Founder,EnduranceResources
Moderatedby:AlanBarksdale,CEO,RedMountainResources
9.10 Question & Answer Session
COMPARING ARTIFICIAL LIFT TYPES USING CASE STUDIES
Comparing Costs, Failure Rates And Run Life, And Identifying Which Are Most Effective At
Different Stages In The Decline Curve
ESP VS GAS LIFT: WOLFCAMP
9.20 Comparing The Trade Offs Between ESP And Gas Lift To Determine Which Is
Most Economical In The Wolfcamp: Higher Production Rates Vs. Lower Failure Rates
• Examining economic methods of installing gas lift to identify how to do it at the lowest cost
• Comparing mechanical down hole risks associated with ESP and gas lift to determine which
are most likely to result in premature failures
• Identifying the factors that affect the running of an ESP to assess the economical
consequences on the well
• Identifying techniques to reduce sand contact with the ESP to prevent corrosion during flow
back and make ESPs more useable
• Examining how to reduce scale via unwanted water contact with ESP’s to prevent premature
failing of the equipment to contribute to the business case for using ESPs
• Determining how optimal sitting depths of an ESP in relation to its size can increase production
rates making it more effective than gas lift
MarkLinroth,EngineeringManager,KinderMorgan
9.50 Question & Answer Session
10.00 Morning Refreshments In Exhibition Showcase Area
REDUCING ESP OPERATING COSTS
10.30 Hearing How Operators Have Created Optimal ESP Designs To Reduce
Operational Costs For ESPs: Wolfcamp Focus
• Evaluating how optimal decline rates have been achieved, and costs reduced, by adapting ESP
designs to reservoir conditions
• Examining when to implement scale inhibitors on ESP wells to increase chemical effectiveness
and reduce costly equipment failure
• Evaluating how to optimize chokes for wells using ESPs to increase long-term stability and
EUR’s in the Wolfcamp
• Determining which mechanical and chemical programs are proving most effective in reducing
the failure rates of ESPs
• Understanding the optimum ESP motor running conditions to avoid damaging the well
AlexFreeman,SeniorProductionEngineer,ConocoPhillips
MickUnderwood,ArtificialLiftDirector,BakerHughes
11.20 Question & Answer Session
MATCHING LIFT TYPE TO PRODUCTION STAGE - PANEL DISCUSSION
11.30 Identifying The Types Of Artificial Lift That Best Suit Different Stages Of The
Well Life To Determine How To Maximize EUR
• Learning how predicted pressure changes during different stages of well life can be used to
determine the best type of artificial lift for reducing well down times
• Quantifying the amount of downtime typically seen per artificial lift type to best understand
when the right time to change lift type is to increase recovery rate
• Distinguishing whether ESPs or rod pumps provide the best high IPR during the earlier stages
of the well
Panelist:PeterBazin,ProductionEngineeringSupervisor,ConocoPhillips
12.00 Question & Answer Session
12.10 Networking Lunch In Exhibition Showcase Area
ROD PUMPING THE CURVE
13.10 Identifying Best Practices For Placing Rod Pumps In The Lateral To Mitigate
Premature Wearing When Pumping The Curve
• Weighing up the options of whether to place the pump above the curve, in the curve or in the
lateral to improve efficiency during production and extend the life of rod pump equipment
• Determining how far in the curve operators have been able to place the pump in the horizontal
part of the well and quantifying the effects this has had on production and rod wear
• Examining case studies to determine whether or not premature wearing is occurring as a result
of rod pumps being placed in the curve and how to mitigate it
• Learning how to collect sand and separate gas more efficiently during flow back to reduce the
possibility of failures when pumping from the curve
YounessElFadili,ProductionEngineer,Oxy
13.40 Question & Answer Session
ROD PUMPING HIGH VOLUME WELLS
13.50 Examining Rod Pump Design, Placement Metrics And Chemical Programs To
Optimize Rod Pumping In High Volume Wells
• Learning how to place chemical programs in the most effective manner around the rod pump to
reduce the occurrence of holes in tubing caused by corrosion
• Determining the best sitting depth for a rod pump in a high volume well to maximize flow and
production rates
• Identifying which design adjustments to rod pump motor size and surface control units have led
to greater rod pump capability in higher volume wells
MarkMahoney,ArtificialLiftAdvisor,Oxy
14.20 Question & Answer Session
ALTERNATIVES TO ROD PUMPS
14.30 Examining Field Studies Showing The Costs, Run Times, And Production
Rates Of Rod Pumps Compared To Other Artificial Lift Methods To Identify Suitable
Alternatives
• Examining the impact on costs, downtime and production rates seen when a leading operator
made the decision to move from rod pumps to alternative artificial lift methods
• ESPs
• Gas Lift
• Jet Pumps
• Quantifying the cost of changing artificial lift forms mid-life to determine at what stages it makes
commercial sense to do so
15.00 Question & Answer Session
15.10 Afternoon Refreshments In Exhibition Showcase Area
COST REDUCTION PANEL
Isolating Crucial Areas Of Production That Can Drive Down The Break-Even Point In Response
To Changing Oil Prices And Create Greater Efficiency Within Production
CUTTING ELECTRICITY COSTS
15.40 Showcasing Well Operating Strategies Being Applied To Draw Lessons On
Lessons On Cutting Electricity Costs
• Evaluating how different pump off controllers and monitoring equipment can be used to reduce
electricity requirements and costs
• Outlining cycle time adjustments that can be made to reduce electrical load
• Hearing operators views and rationales on the economic prospect of developing extra shared
infrastructure to increase availability and supply levels of electricity to production areas
FrederickSchoch,DivisionProductionSpecialist,BOPCO
16.10 Question & Answer Session
POWERING ARTIFICIAL LIFT
16.20 Evaluating How To Effectively And Efficiently Power Artificial Lift Applications
While Accounting For Scalability And Reliability To Lower Down Time On Wells
• Analyzing the cost effectiveness of natural gas power and diesel power alternative fuel options
• Examining how to reliably utilize stranded gas for power generation to lower disposal costs
• Assessing the advantages for utilizing scalable microgrids across multi well pad sites to provide
the required power for operations
• Understanding how to increase safety and reliability through engineering, remote monitoring
and maintenance of artificial lift powering to ensure the safety of all equipment and personnel
on site
DavidDickert,HeadOfOil&Gas-Americas,Aggreko
16.40 Question & Answer Session
REDUCING WATER MANAGEMENT COSTS
16.50 Breaking Down The Optimal Produced Water Recycling And Disposal
Techniques To Effectively Manage Water Requirements In The Permian Basin
• Quantifying the amount of water being produced by Permian wells to predict water costs and
enable the development of a cost-effective water disposal strategy
• Comparing the economics of first party and third party disposal vs. treatment and reuse to
identify lowest cost option
• Hearing steps to effectively target optimum locations for salt water injection to ensure disposal
facilities are ready in time for production
• Understanding the regulations in place to store, treat and reuse frac water to avoid regulatory
compliance consequence costs
FrederickSchoch,DivisionProductionSpecialist,BOPCO
17.20 Question & Answer Session
17:30 Chair’s Closing Remarks
www.permian-production.com (1) 800 721 3915 info@american-business-conferences.com
4. IDENTIFYING BEST PRACTICES FOR PREVENTING AND PUMP FAILURES AND MANAGING
H2S TO EXTEND THE LIFE OF PRODUCTION EQUIPMENT AND REDUCE WELL COSTS
Day 2
Wednesday April 1, 2015
8.30 Chair’s Opening Remarks
Chairedby:AlanBarksdale,CEO,RedMountainResources
REDUCING PUMP FAILURES
Assessing How Permian Operators Are Reducing The Costs Of Failure Prevention Through
Corrosion Inhibition, Gas Seperator Designs And Paraffin Prevention
CORROSION & SCALING RELATED PUMP FAILURES
8.40 Determining The Most Cost Effective Chemical Solutions Being Proven To
Minimize Corrosion And Scaling And Extend The Life Of Artificial Lift Pumps In
The Permian
• Assessing whether oil soluble or water soluble chemicals are more effective for preventing
corrosion in rod pumps: costs versus effectiveness
• Examining what percentage of oil soluble chemicals are needed to effectively coat tubing and
prevent failures on rod pumps
• Assessing which chemicals have been proven most effective in preventing sodium sulfate to
determine best practices for mitigating scaling
• Comparing the effectiveness of different volumes and solutions of corrosion inhibitors
Determining whether it’s worth running a capillary strings to make sure the chemical
reaches target
GregDarby,ChemicalAdvisor,OpalResources
9.10 Question & Answer Session
GAS INTERFERENCE - PANEL DISCUSSION
9.20 Examining Bottom Hole Gas Separation Design Improvements Being Applied
In Horizontal Permian Wells To Identify Which Work Best In Preventing Gas Locking
And Interference
• Identifying which designs for rod pump gas separators are being used to dramatically reduce
gas interference and prevent locking
• Examining the design adjustments that need made to prevent gas locking when pumping
the curve
• Discussing the drive equipment being used to handle gas on horizontal Permian wells to identify
which is most effective in preventing locking
• Understanding how operators are operating and maintaining ESP pumps to reduce gas
interference
Panelist:GregDarby,ChemicalAdvisor,OpalResources
Panelist:DrShariDunn-Norman,Professor,UniversityOfMissouri-Rolla
9.50 Question & Answer Session
10.00 Morning Refreshments In Exhibition Showcase Area
PARAFFIN PREVENTION
10.10 Determining Which Chemicals To Use On Paraffin: Reducing The Cost Of
Chemical Programs Without Compromising Performance
• Using case studies on what has worked and what hasn’t to determine aid selection of chemicals
when designing the paraffin prevention program
• Establishing optimal methods for placing chemicals via capillary strings to maximize the
success of paraffin prevention solutions
• Using case studies to determine how fluid analysis has been used to develop a chemical
program proven to cost effectively reduced failures
10.40 Question & Answer Session
CHEMICAL COST REDUCTION
Isolating Lower Costs Chemicals To Prevent Scaling Corrosion And Paraffin
REDUCING CHEMICAL COSTS
10.50 Identifying Lower Cost Chemical Solutions For Preventing Scaling Corrosion
And Paraffin In Permian Wells
• Identifying best practices for predicting and preventing paraffin build up, scaling and corrosion to
reduce remediation costs
• Assessing the possibility of combining chemical solutions to minimize the presence of bacteria
and reduce pump wear costs
• Understanding how to accurately pump hot water to liquefy paraffin build up and prevent
choking more cost effectively
11.20 Question & Answer Session
11.30 Networking Lunch In Exhibition Showcase Area
MANAGING H2S TO REDUCE EQUIPMENT FAILURES
Examining Where H2S Is Produced And Which Materials And Equipment Can Drive Down The
Cost Of H2S-Related Failures
H2S DESIGN TECHNIQUES AND MANAGEMENT
12.30 Examining Optimum Equipment And Material Selection Criteria To Facilitate
Less Costly And More Safe Management Of H2S Within The Production Process
• Mapping H2S levels across the Permian Basin to identify which fields will require more costly
H2S management and guide production facilities requirements
• Determining best practices in quality control for materials to ensure production facilities can
withstand varying H2S levels
• Quantifying how long different materials and equipment take to fail when exposed to H2S to
inform equipment selection and predict costs down the line
• Examining the effectiveness of plastic coasting for protecting against H2S to identify whether it’s
ability to prevent leaks is worth the cost
• Examining safety and evacuation best practices for workers to identify fail safe methods for
protecting personnel against H2S leaks
StevenIlkay,Oil&GasAdvisor,UTEP-CREIE
13.00 Question & Answer Session
PRODUCTION MEASUREMENT & EMISSION CONTROL
Examining The Very Latest Production Monitoring Technologies And Emission Control Systems
Being Used To Guide Decisions Which To Use In Permian Wells
PRODUCTION MONITORING
13.10 Examining The Very Latest Advances In Production Surveillance Technology To
Improve Understanding Of Data And Guide More Effective Production Designs
• Establishing best practices for understanding production data and how to use this data to
influence pump rates, fluid requirements and leak control requirements
• Examining which new technologies are being proven most effective in measuring oil, water and
gas production in the Permian
• Comparing data analysis and transmission software being used to determine which is most
accurate and guide decisions on which to use
BenBloys,Manager-LosAlamosTechnologyAlliance,Chevron
13.40 Question & Answer Session
13.50 Afternoon Refreshments In Exhibition Showcase Area
EMISSION CONTROL
14.20 Comparing Different Emissions Control Systems Being Used In The Permian To
Determine Which Type Has Been Proven Most Cost-Effective
• Examining the latest emissions regulations to determine equipment and surveillance system
requirements
• Assessing how to use gas quality predictions to forecast emissions and guide gas capture
facilities requirements
• Comparing case studies demonstrating which emission control systems have proven most
effective in minimizing emissions, without compromising budget requirements
14.30 Question & Answer Session
14.40 Chair’s Closing Remarks
VENUE INFORMATION:
DOUBLETREE BY HILTON HOTEL HOUSTON - GREENWAY PLAZA
6 E Greenway Plaza,
Houston, TX 77046
Tel: +1 713 629 1200
Web: tinyurl.com/kxuvbkc
It was a great experience
for focused sharing of
ideas and discussion on
the topic of artificial lift
LINN Energy
www.permian-production.com (1) 800 721 3915 info@american-business-conferences.com
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