GENERAL MEETING | First Rich Gas EOR Cyclic Multi-Well Huff N Puff Pilot...
When: Wednesday February 11, 2021 | 11:50 a.m. - 1:00 p.m.
Title: "First Rich Gas EOR Cyclic Multi-Well Huff N Puff Pilot in the Bakken Tight Oil Play"
Paper presented at the SPE Annual Technical Conference and Exhibition, Virtual, October 2020.
Paper Number: SPE-201471-MS
Speaker: Gordon Pospisil, Development Advisor, Liberty Resources LLC
This field case history details the objectives, design, field operations, and production, pressure, and other surveillance results of the first rich gas multiwell cyclic huff ‘n’ puff pilot in the Bakken and Three Forks intervals of the Williston Basin. The broad goal of the enhanced oil recovery (EOR) pilot was to identify key performance metrics of rich gas injection leading to the design of a commercial field-scale EOR process. Objectives included demonstrating the ability to contain gas within the target intervals vertically and laterally and build pressure to promote a miscible displacement process in a fully developed 1280-acre drill spacing unit (DSU) in the Bakken tight oil play.
Gordon Pospisil is Development Advisor for Liberty Resources LLC, a Denver based, private exploration & production company with operations in the Williston Basin (Bakken) play and a track record of delivering well productivity in the top 10% of major operators through completions technology and production operations innovations. Gordon recently led the Liberty Resources team in collaboration with the ND Energy & Environmental Research Center in the first multi-well Rich Gas EOR Huff N Puff pilot in the Bakken / Three Forks intervals of the Williston Basin in North Dakota. This EOR application builds upon success in the Eagle Ford with the potential to unlock 30-70% more resource and value in the Bakken.
Gordon has over 30 years experience in the oil industry in the Rockies, Alaska, Texas, and Canada with Liberty Resources, BP, Atlantic Richfield, and Touche Ross & Co (now Deloitte LLP). His enhanced oil recovery experience includes petroleum engineering and leadership roles implementing miscible gas EOR programs and projects in Prudhoe Bay, Kuparuk River and other fields in Alaska as well as enhanced SAGD (Steam Assisted Gravity Drainage) in Alberta.
COMPLETIONS STUDY GROUP | On-the-Fly Resin Coating Controls Proppant Flowback...
When: Tuesday January 26, 2021 | 11:50 am to 1:00 pm
Speaker: Logan Cabori, Sales Manager, Hexion’s Performance Additives.
Title: "On-the-Fly Resin Coating Controls Proppant Flowback and Enhances Conductivity"
Proppant Flowback is an issue that has plagued the oilfield for many years. With completion designs moving to finer mesh size proppant and higher proppant loadings per lateral foot, operators are increasing spending to deal with higher amounts of proppant flowback. This presentation will cover the details of SPE-201372-MS which introduces an important technology that is an economically viable and beneficial substitute for traditional proppant flowback prevention methods.
This presentation covers the research, development, and field application of a cost-effective, on-the-fly chemical additive that reduces proppant flowback during well production. Laboratory tests and field results, showing the effect this chemical additive has on proppant flowback, are examined. The field case studies show that use of PFCA significantly reduces proppant flowback and typically results in higher hydrocarbon production when compared to conventional proppants used in offset wells. Additionally, the presentation introduces the second- generation version of this product to highlight the continued technical advancements that are being made in this on-the-fly coating space.
Logan Cabori graduated from Oklahoma State University with a bachelor’s degree in Mechanical Engineering Technology. He spent two years working for Archer Pressure pumping as a Frac Engineer and a fluid technician, providing him with fracturing experience in the Permian Basin and the Midcon. Logan joined Hexion in 2013 as an Account Manager and has been involved with the planning and execution of new product development as well as field trials since 2014. He is currently the Sales Manager for the Midcon, Northeast, and Hexion’s Performance Additives. He currently resides in Tulsa, OK with his wife and two boys.
GENERAL MEETING | An Examination of the Effects of Surface Data Acquisition Methods...
When: Wednesday, January 20, 2021 | 11:50 a.m. to 1:00 p.m
Speaker: Darryl Tompkins P. Eng.
It is common to develop unconventional wells changing completion designs to determine which technique works best in each area. A Rate Transient Analysis (“RTA”) of the flowback / early production data is often used to evaluate how well performance is affected by changes in the completion design. Many analysts faced with performing RTA struggle to have confidence in the analysis results due to low-quality production data. This presentation will show how different surface data acquisition methods affect well-performance evaluation using standard RTA techniques. Additionally, we will recommend preferred data acquisition methods and demonstrate how these methods produce less ambiguous results.
Examples of early production data are shown that were acquired from a variety of familiar sources found in production operations. Practical measurement QA/QC methods are used to evaluate data quality, and RTA is used to demonstrate the effect data quality has on performance evaluations. Comparisons of results will illustrate the impact that good and poor quality data can have on evaluating the relative difference in well performance due to changes in completion designs.
Superior data quality should be a top priority if a well’s performance and completion design need to be evaluated quickly and accurately with the RTA of the early production period. Some data acquisition methods shown in this paper are not adequate for collecting the quality of data needed to produce reliable analysis results. Frequently, the changes from one completion design to the next are relatively small. With low-quality data, it can be impossible to quantify the effect of these changes. Examples presented in this paper show how low data quality can be misleading when performing well evaluations. Examples of data acquisition from some of the best quality sources illustrate how straight-lines used on specialized diagnostic plots can match the data very closely. This gives the analyst much more confidence in the magnitude of the difference in well performance due to the completion design changes.
Iterative completion optimization can be a waste of time and money if the difference in a well’s performance due to the completion design changes cannot be evaluated quickly and accurately. Suppose those responsible for unconventional well performance optimization will continue to rely on the insights provided by RTA. In that case, it seems only logical that the data going into the analysis needs to be of the highest quality possible.
Reservoir and production engineers need high-quality data to evaluate a well’s performance to provide feedback to the completions engineers on which changes in the completion design have the most considerable impact on the well’s performance. None of this can be done correctly if the production team does not receive the best quality data available. The production team must have the right people and equipment in place to consistently collect high-quality data. This often seems to be an overlooked component of the overall value chain.
Darryl has spent his career working in reservoir, completions, and operations engineering in mature fields, gas storage, and unconventionals. He is currently the Chief Technology Officer of Revo Testing Technologies based in Houston, TX, where he works on developing technologies for unconventional well performance evaluations and production optimization. He is a registered Professional Engineer in the Province of Ontario, and he holds a B.Sc. in Mechanical Engineering from the University of Windsor, Canada.
GENERAL MEETING | RTA and PTA in Unconventional Reservoirs...
When: Wednesday, December 16 2020 | 11:50 am to 1:00 pm
Title: "RTA and PTA in Unconventional Reservoirs and the Past, Present, and Future of SPE and Petroleum Engineering"
Speaker: Dr. Thomas A. Blasingame, Professor, Texas A&M University
This presentation will cover a variety of content including, but not limited to, rate transient analysis and pressure transient analysis in unconventional reservoirs and recent research and SPE papers from Dr. Blasingame’s team and Texas A&M to Dr. Blasingame’s views and remarks on the past, present, and future of the Society of Petroleum Engineers and petroleum engineering as a petroleum engineering professor, long time industry contributor, and 2021 SPE International
Dr. Tom Blasingame is a Professor in the Department of Petroleum Engineering at Texas A&M University in College Station Texas. He holds B.S., M.S., and Ph.D. degrees from Texas A&M University — all in Petroleum Engineering. In teaching and research activities Blasingame focuses on petrophysics, reservoir engineering, diagnostics / analysis / interpretation of well performance, unconventional resources, and technical mathematics.
Blasingame's research efforts deal with topics in applied reservoir engineering, reservoir modeling, and production engineering. Blasingame has made numerous contributions to the petroleum literature in well test analysis, analysis of production data, reservoir management, evaluation of low/ultra-low permeability reservoirs, and general reservoir engineering (e.g., hydrocarbon phase behavior, natural gas engineering, inflow performance relations, material balance methods, and field studies).
To date (October 2020), Blasingame has graduated 72 M.S. (thesis), 35 M.Eng. (report, non-thesis), and 16 Ph.D. students, and he has prepared approximately 170 technical articles, as well as having performed several major field studies involving geology, petrophysics, and engineering tasks.
Blasingame is a member of the Society of Petroleum Engineers (SPE), the Society for Exploration Geophysicists (SEG) and the American Association of Petroleum Geologists (AAPG). Blasingame's SPE service includes the following highlights:
(2000) Distinguished Member of the Society of Petroleum Engineers
(2005) SPE Distinguished Service Award (2005)
(2005-2006) SPE Distinguished Lecturer
(2006) SPE Uren Award (for technology contributions before age 45) (2006)
(2012) SPE Lucas Medal (SPE's preeminent technical award)
(2013) SPE DeGolyer Distinguished Service Medal
(2014) SPE Distinguished Achievement Award for Petroleum Engineering Faculty
(2015) SPE Honorary Membership
(2015-2018) SPE Technical Director for Reservoir
(2020-2021) 2021 SPE President
In addition, Blasingame has chaired numerous technical committees and technical conference, symposia, and workshops.
As a source of significant personal pride, Blasingame has also been recognized with several teaching and service awards from Texas A&M University. Lastly, Blasingame is also active in community projects (such as the Wai-a-Ariki Food Forest) and his local church (St. Stephens Anglican church) in his adopted homeland of Onerahi, New Zealand where his wife and children permanently reside.
GENERAL MEETING | Leading the COGCC Lessons Learned and Industry Implications
When: Wednesday November 18, 2020 | 11:50 a.m. to 1:00 p.m.
Where: Zoom meeting
Speaker: John Benton, Chief Development Officer, Hydroacoustics, Inc.
The presentation uses changes to laws, policies, regulations, and Colorado Oil and Gas Commission makeup from 2011-2020, along with additional data, as the basis for the conclusion that the hostile oil and gas environment in Colorado could happen anywhere in North America much to the detriment of the industry.
The presentation lists the proactive rulemakings undertaken by the Commission to adapt to changing public and state government perceptions of the industry during that time frame. It summarizes restrictive legislative changes that occurred as a result of the public viewing the Commission’s rulemakings as not moving fast enough to adapt to increasing residential development in one of the hottest shale plays in North America.
The presentation covers the signals industry missed that resulted in restrictive legislation, the consequences of increasingly strict rules on oil and gas investment in Colorado, and discusses why the same thing could happen in other states. It briefly discusses what the industry can do to reduce the possibility of having what happened in Colorado happen elsewhere.
Finally, the presentation discusses some of the recent Colorado rulemakings and their implications to oil and gas development in Colorado.
John Benton has more than 35 years of worldwide experience in the oil and gas industry in positions progressing from technical engineering to senior leadership. For the last 20 years, John has led business units for both large and small companies, including majors and independents. John currently serves as the Chief Development Officer for Hydroacoustics, Inc. Prior to Hydroacoustics, John served as Production Manager and Midstream Business Unit Manager for Caerus Oil and Gas. Prior to Caerus, John served as the VP and GM of Black Hills E&P. During that time, John also served 8 years as a Commissioner with the Colorado Oil and Gas Conservation Commission, chairing the Commission for the last 2 years of his term. Other notable experience includes VP and GM of Rex Energy’s Rockies Division, VP of El Paso E&P’s Western Division, Asset Manager for Whiting Petroleum’s Permian Basin, CEO of Calver Resources, South Region Asset Manager for Conoco Canada, and Chief Engineer for Gulf Canada.
John has a BSc and MSc in Petroleum Engineering from the Colorado School of Mines and has significant experience with operations and reservoir engineering projects throughout North America, Europe, South America and Indonesia. He is a member of Tau Beta Pi, SPE and SPEE.
John has co-authored and presented three SPE papers on effective technology transfer to independent oil and gas producers. John has taught industry courses on reservoir engineering, waterflood management, and under-balanced drilling. He is active in the Denver Section of the SPE and SPEE and currently serves as a Director with the Denver Section of the SPE. John held a number of positions with both the SPE and SPEE Denver Section Boards over 15 years, including Section Chairman.
COMPLETIONS STUDY GROUP| Biocides in Hydraulic Fracturing and Why You Need One to Protect Your Well
When: Thursday November 12, 2020 | 11:45 a.m. to 1:00 p.m.
Speaker: Matheus Paschoalino, Sr. TS&D Specialist for Microbial Control, Dupont
Microbial Control is an important topic in Oil & Gas operations but it is often neglected due to the complexity or specificity of this subject. Many of the key problems seen during oilfield operations may have a crucial contribution from microbes metabolisms initiating or enhancing corrosion, scaling, souring, clogging and impacting directly on the productivity and operational costs. The dynamics, mixtures and reuse of the fluids in a Hydraulic Fracturing operation enable perfect conditions for the proliferation of a diverse population of microorganisms, which may behave different depending on each environment characteristics, demanding different biocide technologies according to each situation. The water composition and the complexity of the fracking additives plays a critical role on the biocide selection since unintended interactions may disactivate those actives instantaneously. This presentation will discuss some of the main paradigms of microbial control in Hydraulic Fracturing related to the need of a biocide on extreme environments, the key differences, limitations and interactions of the main biocides used on this industry. Furthermore, the presentation will highlight the importance of adequate monitoring and correct data interpretation to avoid the selection of an ineffectual biocide, resulting in high and reoccurring operational costs
Matheus Paschoalino is a Sr. TS&D Specialist for DuPont Microbial Control. He received his doctoral degree from the University of Campinas (Brazil), including a stage at the University Complutense of Madrid (Spain). He has fifteen years of experience in Research, Development, and Technical Support on industrial water treatment and microbial control technologies focusing on delivering asset integrity solutions for energy and mining markets. Last year he was relocated from Latin America to the US, aiming to leverage his field experience with preservative chemistries and advanced diagnostics using DNA-based methods in fifty-plus oilfields for leading petroleum companies of Brazil and Argentina. He has five patents and twenty published papers and presentations from various conferences.
PRODUCTION STUDY GROUP | A Reservoir Engineer's Guide...
When: Thursday October 22, 2020 | 11:45 a.m. to 1:00 p.m.
Title: "A Reservoir Engineer’s Guide to Fit-for-Purpose Completions- Minimum Spend for Maximum Performance"
Speaker: David Anderson (B.Sc., P.Eng.) ,CEO of SAGA Wisdom.
Technology has delayed the once considered inevitable “peak oil” and its subsequent decline, permitting the commercialization of oil and gas resources that were previously thought to be unmovable. Along with this, a “bigger is better” trend has emerged, which has seen an enormous influx of capital into completion and fracture stimulation operations. This trend has resulted in unprecedented production growth, year over year – but at what cost? With the collapse of the global oil market, we now face the imminent challenge of “peak demand” and smart oil and gas companies are streamlining their operations, looking for ways to lower production costs, while favoring positive cashflow over production growth. The concept of fit-for-purpose completions fits perfectly within this new paradigm. Executing successful fit-for-purpose completions requires understanding the unique connection between the completion and the reservoir, and squeezing the maximum economic benefit from every play. Overall, this is something the industry has not done well, in the past. This presentation focuses on basics such as completion compartmentalization, well placement, frac surface area, complexity and conductivity – and how to ensure these are optimized for specific reservoir types while avoiding over (or under) capitalization.
David Anderson (B.Sc., P.Eng.) is the CEO of SAGA Wisdom. David is a recognized authority in the discipline of Rate Transient Analysis and is one of the original architects of Fekete's RTA software (now IHSMarkit Harmony). David was a managing partner Fekete, where he helped build a multi-million dollar petroleum engineering software business. He has 23+ years of petroleum engineering experience and has taught training courses around the world, leading to his appointment as distinguished lecturer for the Society of Petroleum Engineers in 2014. David has co-authored 40+ technical publications and has served in multiple program and technical committee positions with the SPE.
GENERAL MEETING | Sustained Casing Pressure
When: Wednesday October 21, 2020 | 12:00 p.m. - 1:00 p.m.
Title: Sustained Casing Pressure: Where are we and what is working across the United States?
Speaker: Geoff Landry, Schlumberger’s North American Cementing Technical Manager
Sustained casing pressure (SCP) has been an ongoing issue for both new and old wells in the DJ Basin and around the United States. The best, and often most cost-effective long-term solution to SCP is to prevent it in the first place, so an effective primary cement design is critical. If encountered after the primary cement placement or post fracture treatment, SCP is a complex problem requiring a comprehensive, often well-specific solution involving advanced techniques for identifying the source of gas influx and the implementation of a tailored remediation design. This iterative process has evolved over the past several years, and many lessons have been learned that have led to the successful prevention and remediation of SCP. Please join us as Schlumberger’s Domain Champion Geoff Landry discusses “what’s working where and why,” from a technical perspective from around America.
Geoff Landry, Schlumberger’s North American Cementing Technical Manager, is actively involved in the design and implementation of primary and remedial cement systems that address SCP.
COMPLETIONS STUDY GROUP| Dual Fracturing Operations...
WHEN: Thursday, September 24, 2020 | 12:00 p.m. - 1:00 p.m.
Title: "Dual Fracturing Operations - Logistics and Best Practices"
Dual frac is a novel idea to obtain significant pumping efficiency by pumping into two wells simultaneously with one frac crew. This method requires a significant amount of planning to align all the field services precisely and be prepared for any sub-surface pressure reactions that may require real-time job design changes. The stimulation job design, perforation schemes, on-site service providers, pumping equipment and monitoring were planned and optimized to ensure safe and effective stimulation treatment.
In this presentation, the step by step demonstration of the planned activities such as health and safety factors, the method of execution, reasons for Non-productive time and the operational gains made when comparing a zipper frac vs dual frac operation are explained.
Chris Caplis is the Completions Manager for Sundance Energy. He has more than 20 years of drilling & completion experience in the energy industry. He started off as a drilling engineer and has held several senior level positions. He was the drilling manager for Crowheart Energy before moving to Sundance Energy to manage their completions program. He has served in this role for over a year. He has a keen interest in advancing well stimulation and completion practices in the Eagleford shale with a science-based approach to understanding the subsurface in conjunction with data analytics. Most recently, he was the first to successfully implement the dual frac approach in the Eagleford shale. Chris has a degree in Petroleum Engineering from Louisiana Tech.
SPE DENVER | Comparative Summary of Conventonal...
When: Wednesday June 17, 2020 | 12:00 pm to 1:00 pm
Title: Comparative Summary of Conventional O&G Injectors, CO2 EOR and CO2 Storage Injectors