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  • Using Downhole Fiber Optic Temperature Sensing Technology to Monitor, Control and Improve Well Performance

    Contains 3 Component(s), Includes Credits Recorded On: 09/18/2019

    Presented by Dr. Ding Zhu

    Downhole sensing technology today provide engineers continuous measurements for flow condition diagnosis. The measurements include temperature, pressure, acoustic, and strain, with distributed temperature sensors (DTS) and distributed acoustic sensors (DAS) being more commonly used compared with other measurements. Since the optical fiber technology introduced to the industry, it has advanced dramatically. Many field applications have been proven effective and beneficial. From downhole flow condition characterization, we can diagnose flow problems, monitor, control, and optimize producing and injecting well performance, monitor well stimulation, both matrix acidizing and hydraulic fracturing, and optimize treatment designs. There are rich field application examples to show the potential of the technology.

    One of the keys of applying downhole sensing technology is to develop models and methodologies to interpret the senor measurements. This is challenging, because from data collection and processing, to model development, to invert the measured parameters to flow profiles, it is extremely mathematical and computationally intensive. In this lecture, we will review current status of downhole sensing technology, explain the available models and approaches for interpretation, and present field application examples including production profiling, horizontal well flow control, matrix acidizing optimization and multi-stage hydraulic fracture diagnosis. The lecture is based on publications by the author and other SPE publications. The lecture illustrates the power of DTS as a tool for production problem diagnosis and well performance optimization.

    All content contained within this webinar is copyrighted by Dr. Ding Zhu and its use and/or reproduction outside the portal requires express permission from Dr. Ding Zhu.

    Dr. Ding Zhu

    Professor, Petroleum Engineering Department, Texas A&M University

    Dr. Zhu holds a BS degree in mechanical engineering from the University of Science and Technology, Beijing, China, a MS and PhD degree in Petroleum Engineering, both from the University of Texas at Austin. Her research areas are production engineering, well stimulation, intelligent well modeling and complex well-performance optimization. Dr. Zhu is an author of more than 150 technical papers, a co-author of text book, Petroleum Production Systems (2nd edition), and a co-author of a SPE book, Multilateral Wells. She has been a committee member and chairperson for many conferences and events with Society of Petroleum Engineers, and is currently an associate editor for SPE Production and Operation Journal. She is a Distinguished Member of SPE.

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  • Transparency in Measurements

    Contains 3 Component(s), Includes Credits Recorded On: 09/17/2019

    ​Systems automation consumes digital data. Without reliable known data automation systems are inherently unstable. The problem is compounded when users do not own or control the measurements systems, as is required for interoperability. It is therefore important to understand the quality and reliability of the measurement systems being used in drilling automation, and to take steps to ensure that measurement systems are transparent. This webinar will explore significant work in this area, based on published SPE papers.

    Systems automation consumes digital data. Without reliable known data automation systems are inherently unstable. The problem is compounded when users do not own or control the measurements systems, as is required for interoperability. It is therefore important to understand the quality and reliability of the measurement systems being used in drilling automation, and to take steps to ensure that measurement systems are transparent. This webinar will explore significant work in this area, based on published SPE papers.

    This first topic is based on SPE 174874 “A Framework for Transparency in Drilling Mechanics and Dynamics Measurements”, which examines the current confusion that exists in drilling mechanics and dynamics measurements. It recommends measurement practices and good processing techniques of these measurements, with examples, and presents a recommended open measurement framework. Adoption of this framework will resolve the current state of confusion and uncertainty, enable all parties to develop monitoring, advising and control applications that use these data, and help lower well costs and improve borehole quality.

    The second topic is based on SPE 189626 “ Operator’s Group, Rig Contractors, and OEM/Service Company Work to Solve Rig data Quality Issues”, which looks at quality issues with rig measurement systems, proposing quality practices among data providers and consumers. Widely adopted practices will support and drive requirements for sensor quality, calibration, field verification and maintenance. This standardization enables improved drilling operations, automation, data analysis and big data processing.

    The final topic will explore SPE 194082 “Creating Open Source Models, Test Cases, and Data for Oilfield Drilling Challenges” which proposes creating an open source repository of models, source code and data. The intent is to encourage the reuse of continuously improving models and coding efforts, and good data sets for verifying and validating the models. An open source repository for drilling will speed up the rate of learning and automation development.

    All content contained within this webinar is copyrighted by John Macpherson, Paul Pastusek, Michael Behounek and Richard Harmer and its use and/or reproduction outside the portal requires express permission from John Macpherson, Paul Pastusek, Michael Behounek and Richard Harmer.

    John Macpherson

    Chief Consulting Scientist, Drilling Services, Baker Hughes, a GE Company

    During his more than 40 years in the oil industry John has participated in exploratory drilling operations -- primarily in remote areas of South Amercia -- and in various positions in drilling research. His focus has been on exploration and drilling: starting with geology, through geomechanics, drilling modeling, to drilling dynamics and drilling systems automation. He has published about 40 papers, holds more than 30 granted patents, is a past Chairman of the SPE DSATS, and a member of the JPT editorial committee.

    Paul Pastusek

    Drilling Mechanics Advisor, Wells Technical Organization, ExxonMobil Upstream Integrated Solutions

    Paul has 41 years of experience working on drilling mechanics issues. His areas of expertise are: automation, drill string dynamics, steerable systems, borehole quality, bit applications, cutting mechanics, rig instrumentation and control systems, and failure analysis. Paul has a BSME from Texas A&M University and a MBA from the University of Houston. He is a Registered Professional Engineer, holds 39 US patents and has written 25 papers on drilling technology. 

    Michael Behounek

    Head of Drilling and Completions, Apache Corporation

    Michael leads a team of experts who support global operations and pursues technology advancement to drive improvement, increase value to Apache. He is a degreed Mechanical Engineer from University of Michigan with a Master’s in Business from Pepperdine. His 37 years of experience lies in drilling engineering, operations, performance improvement, and contracting. In technology, he has led numerous projects in drilling mechanics and dynamics, rig design and drilling automation. Current projects include an agnostic, edge drilling advisory system deployed to all of Apache rigs for the past three years.

    Richard Harmer

    Architect, Schlumberger’s Well Construction Platform

    Richard has been with Schlumberger for 19 years where he started his career as an MWD engineer, and has subsequently held positions as a; Drilling Domain Expert, Product Champion, and a Program Manager for land drilling rig development. Richard’s technical interests include drilling mechanics and dynamics, drilling interpretation and inference, and drilling automation. He has authored and/or co-authored more than 10 technical papers and holds 4 patents. He holds a Masters in Mechanical Engineering from Loughborough University in the UK.

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  • The Dream Well – Closing the Gap in Completions

    Contains 3 Component(s), Includes Credits Recorded On: 09/12/2019

    Horizontals, Multi-zone, Openhole Packers, Barefoot, ICDs, ICVs, Frac Valves, Plug and Perf, Unconventional – Why are there so many lower completion types? There is a better way – all lower completions could be redesigned as a two-trip and intervention capable system.

    Horizontals, Multi-zone, Openhole Packers, Barefoot, ICDs, ICVs, Frac Valves, Plug and Perf, Unconventional – Why are there so many lower completion types? There is a better way – all lower completions could be redesigned as a two-trip and intervention capable system. Such systems could provide higher value and flexibility for unforeseen circumstances enabling future remediation. Scope changes could be made using OPEX adjustments rather than CAPEX investments. Sensor and  actuator reliability would increase as they become replaceable. Such a system could have permanent compartment packers and tubulars, but the flow control and flow sensing elements would be replaceable, upgradeable, and reconfigurable, optimizing the completion for the life of the well. The industry should create a single completions type that can be reconfigured “on demand” into all the types we presently use. The net result would be a hassle free, “Dream Well.”

    All content contained within this webinar is copyrighted by Brett Bouldin and its use and/or reproduction outside the portal requires express permission from Brett Bouldin.

    Brett Bouldin

    Petroleum Engineering Consultant, Saudi Aramco

    Mr. Bouldin is a Petroleum Engineering Consultant with Saudi Aramco with 36 years of product development experience in the completions industry. His career started with Baker Hughes, then he became a founding member of WellDynamics, which is now a Halliburton company prior to his appointment at Saudi Aramco for the previous 9 years. Brett initiates and manages Saudi Aramco’s completions development projects focusing on new tool deployments that would improve production recovery. He has authored 12 technical papers and articles with 38 granted US patents. Brett holds a BS degree in Industrial Engineering from Texas A&M University and is a Registered Professional Engineer in Texas and Saudi Arabia.

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  • Capturing our Geomechanics Legacy to Understand Its Future -- Interview with Dr. Steve Willson

    Contains 1 Component(s) Recorded On: 09/12/2019

    Tune in to this 30-minute interview to gain insight into this industry expert’s personal views and professional experiences on why they chose to focus on the Geomechanics field; what it was like when they began working in it; its evolution and where they see Geomechanics going in the future.

    This series of industry interviews will focus on understanding and capturing the historical legacy of petroleum geomechanics from the experts who created it. From this historical foundation, these same experts with consider the future path, focus and value of petroleum geomechanics.

    Tune in to this 30-minute interview to gain insight into this industry expert’s personal views and professional experiences on why they chose to focus on the Geomechanics field; what it was like when they began working in it; its evolution and where they see Geomechanics going in the future. 

    Interview with: Dr. Steve Wilson, Senior Technology Advisor for Geomechanics and Pore Pressure, Apache Corporation

    Interviewed by: Neal B. Nagel, PhD – Chief Engineer and Principal, Oilfield Geomechanics LLC; Chair, SPE Geomechanics Technical Section (GTS)

    Dr. Steve Willson

    Senior Technology Advisor, Apache Corporation

    Dr. Willson has 35 years’ experience covering a wide range of petroleum geomechanics and rock mechanics applications. His career has included 20 years with BP in both the UK and US; a time at TerraTek Inc. in Salt Lake City; and most recently 9 years at Apache Corporation in Houston, where he is the Senior Technology Advisor for Geomechanics and Pore Pressure.  His current work interests include pore pressure prediction, wellbore stability, geomechanics controls on hydraulic fracturing, and induced seismicity hazard.  He holds a PhD in Civil Engineering from Manchester University, UK. 

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    Members : Free!

    Non-members : USD 50.00

  • Drilling Uncertainty – What Does the Drilling Fluid Have To Do With It?

    Contains 3 Component(s), Includes Credits Recorded On: 09/10/2019

    Critical drilling issues are usually associated with convergence of pore and fracture pressure, and are intimately connected to the downhole behavior of drilling fluids and uncertainties associated with predicting their behavior during well construction. This presentation will highlight how drilling fluids affect uncertainties in pressure estimates and present strategies to quantify and overcome deficiencies.

    Critical drilling issues are usually associated with convergence of pore and fracture pressure, and are intimately connected to the downhole behavior of drilling fluids and uncertainties associated with predicting their behavior during well construction. Top areas of operational concerns, such as lost circulation, hole-cleaning, barite sag, wellbore stability, stuck pipe, etc. all share a common thread in hydraulics, and continue to plague drilling operations and efficiencies. From shallow sections to well completions, the drilling fluid and its imposed pressures represent the primary barrier for well control, and fluid hydraulics affects every stage of well construction.

    Current measurements provide at best a partial view of downhole pressure windows, and software technologies are necessary to fill in the gaps. A classic example includes optimum speeds for running casing where no downhole measurements currently exist. While the consequences of hydraulics-related problems are well documented, deeper understanding of downhole drilling fluid behavior is plagued by difficult to model dynamic conditions and transient operations. Uncertainties in predicting or simulating drilling fluid behavior impact monitoring and optimizing drilling performance. This presentation will highlight how drilling fluids affect uncertainties in pressure estimates and present strategies to quantify and overcome deficiencies.

    Dr. Sanjit Roy

    Global Engineering Applications Director, QMAX Solutions

    Dr. Roy has spent more than 25 years in the areas of drilling fluid research and technology development, specifically in hydraulics, rheology, and real-time analysis of drilling and drilling fluids performance and related areas. He has managed and also developed software to model drilling fluid behavior and drilling processes. He has made many SPE and AADE workshop presentations, and facilitated SPE forums on drilling fluid modeling, hydraulics, ECD management and real-time processes. He has more than 40 industry publications and is a member of SPE and AADE.

    Dr. Roy has a B. Tech. in Mining Engineering from IIT Kharagpur, and MS and Ph.D. in Petroleum Engineering from University of California, Berkeley.

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  • Enabling Safer Offshore Energy Operations: Current Advances in Safety and Risk Assessment

    Contains 3 Component(s), Includes Credits Recorded On: 09/10/2019

    Investigation of past incidents always reveal deficiencies that are not directly equipment-related, but may be non-technical in nature, such as procedural deviation, inadequate communication etc. Past risk assessment models only provide semi-quantitative approaches to incorporate them in the risk assessment and cannot capture their dynamic nature and dependency in a single model. Current research takes up the challenge of developing a framework and step-by-step methodology for quantitatively merging technical, operational, human and organizational factors contributing to the cumulative risk of a barrier failure. It also addresses their dynamic changes with time, considers their interactions with each other and incorporates the uncertainty of parameter estimation to assess the cumulative risk in a facility.

    Investigation of past incidents always reveal deficiencies that are not directly equipment-related, but may be non-technical in nature, such as procedural deviation, inadequate communication etc. Past risk assessment models only provide semi-quantitative approaches to incorporate them in the risk assessment and cannot capture their dynamic nature and dependency in a single model. Current research takes up the challenge of developing a framework and step-by-step methodology for quantitatively merging technical, operational, human and organizational factors contributing to the cumulative risk of a barrier failure. It also addresses their dynamic changes with time, considers their interactions with each other and incorporates the uncertainty of parameter estimation to assess the cumulative risk in a facility.

    Syeda Zohra Halim

    MSc, PhD Candidate

    Syeda Zohra Halim completed her PhD in Chemical Engineering in Spring 2019 with Mary Kay O’Connor Process Safety Center at Texas A&M University.  Her research focused on developing a model for assessing cumulative risk arising from impaired barriers in offshore oil and gas facilities. In her work, she identified and analyzed organizational issues that contribute to increased risk and utilized Hierarchical Bayesian Analysis to show how such contributors can be quantified and brought together with technical factors to understand their dynamic holistic effect on risk.

    A keen supporter of promoting process safety, Zohra has actively been involved in multiple process safety related projects alongside her research work. Such projects include developing a PSM implementation plan for an international industrial corporation, analyzing BSEE incident investigation databases to determine leading causes behind incidents in offshore oil and gas facilities, developing process safety course materials for an international university, working in collaboration with IChemE to develop a roadmap for process safety for the 21st century and writing a book chapter on process safety for petroleum engineering students. She also works as a team member with the Ocean Energy Safety Institute (OESI) and volunteers frequently in their forums and workshops. Zohra has won the Texas Sea Grant Special Award, Lamiya Zahin Memorial Safety Scholarship and has held first position thrice at the Annual MKOPSC Poster Competition. She was elected Media Chair of the Chemical Engineering Graduate Students’ Association (ChEGSA).

    Before coming to Texas A&M University, Zohra completed her B.Sc. and M.Sc. in Chemical Engineering from Bangladesh University of Engineering and Technology (BUET). 

    James Pettigrew

    Principal Investigator and Director of Operations, Ocean Energy Safety Institute

    Retired Navy Captain Jim Pettigrew is the Principal Investigator and Director of Operations for the Ocean Energy Safety Institute (OESI). A partnership between Texas A&M University, University of Houston, and University of Texas – Austin; OESI provides a forum for dialogue, shared learning and cooperative research among academia, government, industry and other non-governmental organizations. OESI’s focus is offshore-related technologies and activities that help ensure safer and environmentally responsible offshore operations. Jim assumed the position of Director in May 2014, and Principal Investigator in December 2018.

    Throughout his three decades in the Navy, Pettigrew worked predominantly in operational oceanography, surface warfare and information warfare; managing and mitigating risk at all levels of operations. He served most recently as Chief of Staff for the Commander, Naval Meteorology and Oceanography Command where he was responsible for the direction and leadership of a team of 150 people, executing a $300 million annual budget, the operations of 4,000 personnel worldwide, the nation's Master Clock, two world-class supercomputing facilities, and six military Oceanographic Survey Ships. He also had the privilege and honor of serving as the Commanding Officer for the Navy’s Global Atmospheric and Ocean Modeling Supercomputing Center (Fleet Numerical, in Monterey, CA) and as the Commanding Officer for the Navy’s only forward deployed Operational Oceanography support center in Yokosuka, Japan. He served twice in the Pentagon and was Joint-qualified serving with the U.S. Space Command in Colorado Springs.

    Pettigrew received his Masters of Science in Physical Oceanography and Meteorology from the Naval Postgraduate School, and received his Bachelors of Science in Ocean Engineering from Texas A&M University.

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  • Carbon Storage in the Mt. Simon: Field Examples of Regional Deployment

    Contains 3 Component(s), Includes Credits Recorded On: 09/06/2019

    The development of commercial-scale projects has been a strategic process across multiple phases leading to a succession of projects of increasing scale in the Central United States. Four major carbon capture and storage (CCS) projects in Decatur, Illinois and Terra Haute, Indiana exemplify the strategic pathway defined more than a decade ago by the U.S. Department of Energy – National Technology Laboratory (US DOE).

    The development of commercial-scale projects has been a strategic process across multiple phases leading to a succession of projects of increasing scale in the Central United States. Four major carbon capture and storage (CCS) projects in Decatur, Illinois and Terra Haute, Indiana exemplify the strategic pathway defined more than a decade ago by the U.S. Department of Energy – National Technology Laboratory (US DOE). Since 2003, the Midwest Geological Sequestration Consortium (MGSC), a US DOE Regional Carbon Sequestration Partnership, has been working to define regional CCS potential, conducting small enhanced oil and enhanced coalbed methane projects, and conducting a large-scale deep saline CCS storage project. As a direct outcome of the Illinois Basin – Decatur Project (IBDP), a one million tonne storage demonstration, the Illinois Industrial Sources CCUS Project (ICCS) has expanded infrastructure and injection potential to industrial commercial-scale CCUS. Advancing CCUS even further, the CarbonSAFE Macon County and Wabash CarbonSAFE projects seek to conduct characterization leading to the development of a 50 million tonne storage complexes with the potential to receive and store CO2 from multiple sources. These projects combined provide an excellent example of how leveraging research, resources, relationships, and experience can drive CCUS toward commercialization.

    Dr. Sallie Greenberg

    Associate Director of Energy and Minerals, Illinois State Geological Survey

    Dr. Greenberg is the principal investigator for the Midwest Geological Sequestration Consortium (MGSC), one of the U.S. Department of Energy’s seven regional sequestration partnerships and the founder of the Sequestration Training and Education Program (STEP). In these roles, Dr. Greenberg collaborates with teams of scientists, engineers, and policy makers working on several carbon capture and geologic storage projects, including the Illinois Basin – Decatur Project, CarbonSAFE Illinois, Wabash CarbonSAFE, and the Illinois Industrial Carbon Capture and Storage Projects. Over the last 15 years, she has consulted or contributed to more than 30 carbon capture and storage projects, especially in the areas of project development, risk reduction, and stakeholder engagement.

    Dr. Greenberg’s combination of advanced degrees in low temperature geochemistry and education provide a unique perspective on understanding public challenges related to balancing societal demands for energy with environmental concern. She currently is a Prairie Research Institute Science Fellow. Dr. Greenberg holds a Ph.D. in Secondary and Continuing Education and Master of Science degree in Geology from the University of Illinois, and a Bachelor of Arts degree in Geology from Alfred University in New York.

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  • Life Cycle Water Management: Internal and External Strategies

    Contains 3 Component(s), Includes Credits Recorded On: 09/05/2019

    This presentation covers the life cycle issues around water management for the upstream industry, with a focus on tools, strategies and ideas on how to reduce risk, cost and liability.

    Water is an essential aspect of oil and natural gas operations.  Water sourcing, transportation, storage, use, discharge, and disposal continue to be issues that companies are working on to reduce associated risk, cost and liability.  Ms. Cooper will talk about the life cycle issues around water management for the upstream industry, with a focus on tools, strategies and ideas on how to reduce risk, cost and liability.  In addition, she will focus on how to better share information around a company’s water strategy for internal and external purposes.  This means sharing ideas on how to best engage internal stakeholders and address questions and concerns of external stakeholders.

    Jill Cooper

    Senior Principal at Geosyntec Consultants, Recent Chair of the Energy Water Initiative, Contributor of Water Collaboratory Advisory Group

    Ms. Cooper has over 25-years of environmental and sustainability experience in government, industry and a law firm. Her focus is on sustainability, EHS, water management, audits and due diligence, management systems, compliance, regulatory affairs, and stakeholder engagement. Her experience with water and the oil and natural gas industry is diverse and extensive. When working in-house at oil and gas companies, she oversaw their environmental water teams and was involved in regulatory permitting, compliance, life-cycle water management, water data and reporting systems, and risk evaluations at the regional and corporate level.

    Her produced water experience includes water sourcing, transport, storage, usage, disposal and treatment for release to the surface or reuse. Until recently, she was the chair of the Energy Water Initiative – a group of 23 upstream oil and gas companies that discuss and work together on life-cycle water strategies. She is also regularly asked to speak on the topic of produced and life-cycle water management for the industry by: government, research institutions, trade associations, and others. Recently, she was asked to serve on the Water Collaboratory Advisory Group (Colorado universities’ joint research facility).

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  • Overview of ISO 27916 Standard as an alternative to EPA GHGRT Subpart RR

    Contains 3 Component(s), Includes Credits Recorded On: 08/20/2019

    This webinar will present context of the development of the ISO Standard 27916 and how it compares to and may be used as an alternative to GHGRP Subpart RR.

    With the recent expansion of the U.S. Internal Revenue Code (IRC) Section 45Q tax credit for CO2 storage, project developers are seeking this incentive to make the project financing viable. Guidance from the Internal Revenue Service (IRS) recommends that the Environmental Protection Association (EPA) CO2 reporting rules, particularly Subpart RR of the Greenhouse Gas Reporting Program (GHGRP), be used to quantify CO2 incidentally stored during CO2-EOR, as well as for the injection of CO2 for storage in depleted hydrocarbon and saline reservoirs.  There has been much debate over the use and application of GHGRP Subpart RR to CO2-EOR as the means of establishing incidental storage quantification mechanisms that may serve as an alternative to the GHGRP requirements. More than five years ago, the International Organization for Standardization (ISO) formed technical committee 265 (TC-265) dealing with carbon dioxide capture, transport and geological storage.   TC-265 was subdivided into six working groups, and international standards have been generated for post-combustion capture, pipeline transportation, geological storage (without storage quantification), and CO2-EOR (with incidental storage quantification, ISO 29716). This webinar will present context of the development of the ISO Standard 27916 and how it compares to and may be used as an alternative to GHGRP Subpart RR.

    Dr. Steven M. Carpenter

    Subject Matter Expert

    Dr. Carpenter is a seasoned executive with 30+ years of experience in the energy, mining, international, and federal contracting industry. He is an internationally recognized Subject Matter Expert on Enhanced Oil Recovery (EOR), climate change, carbon, and risk management issues. Dr. Carpenter currently is the Head of Delegation and Chair of the United States Technical Advisory Group (TAG) & National Mirror Committee (NMC) for ISO Technical Committee TC-265: Carbon dioxide capture, transportation, and geological storage; and the International Convener for ISO Technical Committee TC-265 Carbon dioxide capture, transportation, and geological storage, Working Group 2: Carbon Dioxide Transportation.

    Dr. Carpenter is the Chair of the CSA Groups Strategic Steering Committee on Natural Resources; a Trustee with the Energy Mineral Law Foundation; a Trustee with the International Pittsburgh Coal Conference at Swanson School of Engineering, University of Pittsburgh; received a lifetime appointment to the Executive Order of the Ohio Commodore; and is an active member of both the Society for Mining, Metallurgy & Exploration Inc. (SME) and the Society of Petroleum Engineers (SPE).

    Dr. Carpenter holds a Bachelor’s degree in Physics from Earlham College, a Master’s degree in Environmental Public Policy from Antioch University, and a Ph.D. in Transdisciplinary Approaches to CO2-EOR from the California Institute of Integral Studies.

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  • Using Well Heterogeneity as an Advantage to Designing Stage Specific Diverter Strategies

    Contains 3 Component(s), Includes Credits Recorded On: 08/19/2019

    This talk will discuss a methodology that examines well heterogeneity, and designs the diversion strategy based on the rock properties within each fracturing stage. In addition to rock properties, the method proposed utilizes stress shadows, perforation design, and modified pump schedules to ensure equal cluster stimulation in diverter applications.

    When hydraulically fracturing a horizontal wellbore with multiple perforation clusters, the fluid being pumped into the reservoir will preferentially take the path of least resistance. Perforations that are located in the lowest stressed rocks will take a larger amount of fluid, and those perforations located in highest stressed rocks will receive less, or in some cases none. One of the ways that engineers are trying to overcome these differences is the use of diverters. A fluid diverter is typically inserted at some point within a hydraulic fracturing pump schedule to seal off dominant fractures, allowing fluid to flow into under-stimulated fractures. 

    The problem with this methodology is that without reservoir knowledge, operators rely on rules of thumb developed through trial and error to determine when and how much diverter to use. Data has shown how this methodology can be ineffective, leaving some clusters over stimulated and others under-stimulated. Anecdotal evidence also supports these concerns  because equally sized diverter slugs do not always have equal pressure response.This talk will discuss a methodology that examines well heterogeneity, and designs the diversion strategy based on the rock properties within each fracturing stage. In addition to rock properties, the method proposed utilizes stress shadows, perforation design, and modified pump schedules to ensure equal cluster stimulation in diverter applications.

    The result of this workflow is a tool that has been used to maximize the effectiveness of diverters which has shown, through several case studies that will be discussed, to result in better producing wells at lower completions cost.

    Kevin Wutherich

    Chief Technology Officer, Drill2Frac

    Kevin has 20 years of industry experience both with an operator and in the service industry. Before joining Drill2Frac as the Chief Technology Officer, where he has worked for the last 2 years, he was the Director of Completions at Rice Energy where he led a team of engineers in creating the top performing wells in the region. Before that he held multiple positions including Stimulation Domain Expert over a fifteen-year career at Schlumberger. He is the lead inventor on seven patents related to fracturing procedures and tools, and has authored many SPE papers and contributed to several industry publications primarily focused on shale completions. Kevin has also been honored with multiple industry awards, most recently for his creation and development of  ”Engineered Diversion Strategies”, which was selected as the World Oil Awards “2018 Best Completion Technology”. Kevin received a Bachelor’s degree in Chemical Engineering from the University of Waterloo in Canada.

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