Catalog Advanced Search

Search by Category
Search by Format
Sort By
Search by Type
Search by Keyword
Search by Category
Search in Packages
Search by Format
Search by Type
Search by Date Range
Products are filtered by different dates, depending on the combination of live and on-demand components that they contain, and on whether any live components are over or not.
Start
End
Search by Keyword
Sort By
  • Contains 3 Component(s), Includes Credits Includes a Live Web Event on 09/29/2022 at 8:30 AM (EDT)

    CCS is seen by many bodies such as the IEA and the IPCC as a one of the key enablers to decarbonising the economy. Transportation of CO2 is a key focal area in any CCS project but while dehydration of natural gas for transportation is well understood and regulated, the same cannot yet be said for CO2.

    CCS is seen by many bodies such as the IEA and the IPCC as a one of the key enablers to decarbonising the economy. Transportation of CO2 is a key focal area in any CCS project but while dehydration of natural gas for transportation is well understood and regulated, the same cannot yet be said for CO2. Dehydration specifications need to consider important project parameters such as ambient temperatures, CO2 pressures, contaminants, and materials of construction. Based on the selected specification, the most suitable method for implementing the dehydration should be selected, along with the optimum location of the dehydration equipment in the multi-stage pressure-boosting plant. These challenges and a methodology for overcoming them will be explored in this presentation.

    This webinar is categorized under the Projects, Facilities, and Construction technical discipline.

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

    Ross Weiter

    Ross Weiter has over 30 years of experience in all areas of the upstream oil and gas industry. This includes time spent in concept engineering, front-end engineering design, detail design, operation support and several years of site work. His experience includes many CCS studies for various clients such as Santos, Wesfarmers, Arctic LNG2, Woodside, ConocoPhillips, Chevron, Korea National Oil Company, BG and others. Ross spent most of his career working in Perth, Western Australia with three years in Muscat working for Petroleum Development Oman (PDO). Today he is a Principal Consultant at Advisian, where he is also the CCS Lead for the Asia-Pacific Region.

    Nikhil Joshi (Moderator)

    Nikhil Joshi is the Director of Innovation and Technology at Talos Energy. In his current role, Nikhil is focused on energy transition and use of current O&G skillsets to be applied towards carbon capture and sequestration, hydrogen, geothermal and wind power generation, among others. He has written over 50 technical papers and presented at several events and enjoys bringing non-conventional technical and commercial solutions to non-trivial challenges.

    SPE Webinars are FREE to members courtesy of the

    image
  • Contains 3 Component(s), Includes Credits Includes a Live Web Event on 08/18/2022 at 11:00 AM (EDT)

    This webinar will cover how physics and data-driven methods can be merged in practical ways for automating reservoir surveillance with applications to pressure transient analysis.

    This webinar will cover how physics and data-driven methods can be merged in practical ways for automating reservoir surveillance with applications to pressure transient analysis.

    This webinar is categorized under the Reservoir technical discipline.

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

    Dr. Sathish Sankaran

    Dr. Sathish Sankaran has over 20 years of diversified industry experience in technology development, consulting, project execution and management working on several international, deepwater, and US onshore projects. His areas of specialization include digital oilfield technologies, reservoir management, field development optimization, uncertainty analysis, production operations, and advanced process automation.

    At Xecta Digital Labs, he leads an engineering team in the development of digital solutions for energy industry by fusing physics and data analytics methods for applications in reservoir, production, facilities, and downstream processes.

    Sathish is a member of Society of Petroleum Engineers (SPE) and served in several roles including advisory positions, chairperson and committee member in industry initiatives, and authored industry reports on applications of data analytics in reservoir engineering.

    He has a B.Eng. (Honors) degree in Chemical Engineering from Birla Institute of Technology and Science (BITS – Pilani, India), M.S degree in Chemical Engineering from University of Cincinnati and Ph.D. degree in Chemical Engineering from University of Houston.

    SPE Webinars are FREE to members courtesy of the

    image
  • Contains 3 Component(s), Includes Credits Includes a Live Web Event on 08/11/2022 at 11:00 AM (EDT)

    Gas lift is becoming a big consideration in most of oil field as an economic, sustainable means of artificially lifting weak/dead oil wells. This webinar presents a case study from Khafji Joint Operation fields, utilizing the intelligent digital gas lift valve to optimize the design and performance of the gas lift wells.

    Gas lift is becoming a big consideration in most of oil field as an economic, sustainable means of artificially lifting weak/dead oil wells. This is especially considered in high volume wells. Gas lift is employed, by injecting gas into the well tubing through gas lift valves, to reduce the hydrostatic pressure of the produced fluid column in oil wells, leading to a lower flowing bottom-hole pressure. The increased pressure differential induced across the sand face from the in situ reservoir pressure, assists in lifting the produced fluid to the surface.

    Optimizing the level of injected gas is important in maximizing the production, and hence the financial performance of the well. The challenge for most oil and gas producers is that they do not effectively maximize production with the most efficient use of gas lift resources. The challenge is that there is a lack of accurate and timely production data from the well tests. The optimal inject rate for a well is based on a ratio of injected gas rate to the liquid production rate. Under injecting the gas decreases the well production rate. The objective of optimization in gas-lifted wells is to achieve optimal production rate with minimal gas injection volume to spare gas for other wells, when the compression capacity is limited. Optimally allocated injection gas helps reduce unnecessary strain on your facility and maximize performance, this in turn enhances the life of production assets significantly.

    This webinar presents a case study from Khafji Joint Operation fields, utilizing the intelligent digital gas lift valve to optimize the design and performance of the gas lift wells. The case study demonstrates the value proposition by using the digital intelligent gas lift system to maximize well performance whilst reducing injected gas, in addition to acquired real-time data that help assess the process. That optimization was achieved on well level by optimizing the well parameters such as point of injection, injection rate, and injection pressure. All these aspects have been investigated and presented in this study by using field data and flow simulations. Results showed the potential added value of the system.

    This webinar is categorized under the Production and Operations technical discipline.

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

    Abdullah Al Qahtani

    Abdel BenAmara (Moderator)

    Abdel BenAmara is Vice President for Silverwell’s Middle East and Asia Pacific regions. He started his nearly twenty-year career in the automotive industry before joining PCM, an artificial lift equipment manufacturer, in 2005. Here Abdel was Area Manager for Europe based in Paris, and was then assigned to manage PCM’s Middle East region and moved to the UAE in 2009. Abdel joined Silverwell in 2015 to kick-off regional growth in the Middle East and Asia. Abdel holds two Master’s degrees in Mechanical Engineering from ENIM France, and Bristol University in the UK.

    SPE Webinars are FREE to members courtesy of the

    image
  • Contains 3 Component(s), Includes Credits Includes a Live Web Event on 06/30/2022 at 1:00 PM (EDT)

    Flow assurance is a vital challenge that affects the viability of an asset in all oil producing environments. A proper understanding of asphaltene precipitation leading to deposition lends itself to reliable completions planning and timely remediation efforts. This ultimately dictates the production life of the reservoir.

    Flow assurance is a vital challenge that affects the viability of an asset in all oil producing environments. A proper understanding of asphaltene precipitation leading to deposition lends itself to reliable completions planning and timely remediation efforts. This ultimately dictates the production life of the reservoir.

    The Wireline Formation Tester (WFT) has traditionally aided the understanding of asphaltene composition in reservoir fluids through the collection of pressurized fluid samples. Moreover,the use of Downhole Fluid Analysis (DFA) during a fluid pumpout has augmented the understanding of soluble asphaltenes under in-situ flowing conditions. However, an accurate and representative measurement of Asphaltene Onset Pressure (AOP) has eluded the industry. Traditionally, this measurement has been determined post-acquisition through different laboratory techniques performed on a restored fluid sample. Although sound, there are inherent challenges that affect the quality of the results. These challenges primarily include the need to restore samples to reservoir conditions, maintaining samples at equilibrium composition, and the destruction of fluid samples through inadvertent asphaltene precipitation during transporting and handling. Hence, there is aneed for WFT operations to deliver a source of reliable analysis, particularly in high-pressure/high-temperature (HP/HT) reservoirs, to avoid costly miscalculations.

    A premiere industry method to determine AOP under in-situ producible conditions is presented. Demonstrated in a Gulf of Mexico (GOM) reservoir, this novel technique mimics the gravimetric and light scattering methods, where a fluid sample is isothermally depressurized from initial reservoir pressure; simultaneously, DFA monitors asphaltene precipitation from solution and a high-precision pressure gauge records the onset of asphaltene precipitation. This measurement is provided continuously and in real time. An added advantage is that experiments are performed individually after obtaining a pressurized sample in distinct oil zones. Therefore, the execution of this downhole AOP experiment is independent of an already captured fluid sample and does not impact the quality of any later laboratory-based analysis. Once the measurements are obtained,these can be utilized in flow assurance modeling methods to describe asphaltene precipitation kinetics, and continuity of complex reservoirs. For the first time in literature, this study applies these modeling methods in combination with the AOP data acquired from a downhole WFT.

    This approach has the potential to create a step change in reservoir analysis by providing AOP at the sand-face, along with insight that describe performance from asphaltene precipitation. The results of which have tremendous economic implications on production planning.

    This webinar is categorized under the Projects, Facilities, and Construction technical discipline.

    All content contained within this webinar is copyrighted by Rohin Naveena-Chandran and its use and/or reproduction outside the portal requires express permission from Rohin Naveena-Chandran.

    Rohin Naveena-Chandran

    Rohin Naveena-Chandran is a GOM Wireline & Perforating Business Development Manager for Halliburton. With experience spanning 18 years globally, he has supported operators in field operations and as a Technical Advisor. Over the past 13 years, he has worked within the GOM and has contributed to several innovative formation testing and sampling projects that have provided value to the industry. Rohin obtained a bachelor’s degree in Electrical Engineering from the University of Victoria and a master’s degreee in Electrical Engineering from the University of Waterloo.

    Nikhil Joshi (Moderator)

    Nikhil Joshi is the Director of Innovation and Technology at Talos Energy. In his current role, Nikhil is focused on energy transition and use of current O&G skillsets to be applied towards carbon capture and sequestration, hydrogen, geothermal and wind power generation, among others. He has written over 50 technical papers and presented at several events and enjoys bringing non-conventional technical and commercial solutions to non-trivial challenges.

    SPE Webinars are FREE to members courtesy of the

    image
  • Contains 3 Component(s), Includes Credits Includes a Live Web Event on 06/27/2022 at 10:00 AM (EDT)

    New energy related applications (e.g. CCS, H2 storage, geothermal) can certainly benefit of O&G experience in measurements, characterization and modelling. There are however many unexplored fields of application of reservoir modelling in O&G involving thermo-hydro-mechanical-chemical (THMC) coupling and time dependent behavior.

    New energy related applications (e.g. CCS, H2 storage, geothermal) can certainly benefit of O&G experience in measurements, characterization and modelling. There are however many unexplored fields of application of reservoir modelling in O&G involving thermo-hydro-mechanical-chemical (THMC) coupling and time dependent behavior. This is of paramount importance for new energy applications. Existing approaches are much more advanced than what we do currently in O&G, that’s often very basic. In this presentation, some examples will be shown followed by a discussion on how time and fluid dependent behavior can be included adopting a consistent theoretical framework.

    This webinar is categorized under the Reservoir technical discipline.

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

    Vincenzo De Gennaro

    Vincenzo De Gennaro has thirty years’ experience in theoretical and applied geomechanics, including heighten years’ experience in O&G industry related projects. He graduated as Civil and Geomechanical Engineer in 1992 and has been consultant engineer, PhD fellow then lecturer and lastly associated professor (research director) in geomechanics at the Ecole Nationale des Ponts et Chaussées - ParisTech (Paris, France). He joined Schlumberger in 2009 as Geomechanics and Unconventional Gas Specialist. He’s currently CCS subsurface and geomechanics advisor in Schlumberger. His activities encompass exploration, appraisal and production related projects, onshore and offshore drilling integrity studies, coupled reservoir geomechanics analysis (including compaction/subsidence studies), geomechanics for unconventional (completion quality evaluation and hydraulic fracturing modelling), sanding, underground gas storage (natural gas and anthropogenic CO2).

    Dr. Hamid Pourpak (Moderator)

    Dr. Hamid Pourpak is Senior Geomechanics Specialist working for TotalEnergies in France. He started his work at TotalEneregies in 2008 as geomechanics engineer. In 2014 he joined TotalEneregies R&D organization leading international unconventional geomechanics research projects. From 2018 to 2021, he is worked on unconventional operational topics. Today hamid is leading both conventional and unconventional geomechanics topics together with research projects. Before joining Total, he worked as a PhD student at IFP Energies Nouvelles (IFPEN) and holds a PhD degree in Geoscience from University of Poitiers (France) and a master’s degree in Rock and Soil mechanics from Ecole Centrale de Paris (Paris School). Hamid is an active member of ARMA, URTEC and also SPE communities. He is acting also as SPE geomechanics session program chairman. 

    SPE Webinars are FREE to members courtesy of the

    image
  • Contains 3 Component(s), Includes Credits Includes a Live Web Event on 06/14/2022 at 12:00 PM (EDT)

    Michael Godec provides an overview of carbon dioxide (CO2) capture, utilization, and storage processes, technology, and economics and Andrew Duguid describes the processes and challenges associated with permitting storage sites in the U.S.

    Michael Godec provides an overview of carbon dioxide (CO2) capture, utilization, and storage processes, technology, and economics. This includes a quick review of carbon capture technologies, CO2 transportation infrastructure to move the CO2 from where it is captured to where it will be securely stored, the mechanics of geological carbon storage, and what will be necessary to ensure secure geologic storage of CO2. He discusses why CCUS is critical for achieving significant emissions reductions globally, and the status of CCUS in the U.S., including highlights of some key projects. He  discusses the phases of a CCUS project, the criteria for a high potential CO2 storage site, and what is necessary for managing and minimizing the risks of a CCUS project. Finally, he describes some of the key factors influencing commercial project feasibility.

    Andrew Duguid describes the processes and challenges associated with permitting storage sites in the U.S. He discusses the regulatory challenges that come from separate sets of regulations that can govern a storage project, to allow CO2 capturers to qualify for credits and subsidies. The storage site will be permitted to allow injection by the US EPA, or states granted regulatory primacy, as part of the Underground Injection Control Program. To allow capturers to qualify for federal tax credits the project will develop a monitoring reporting and verification plan (MRV) that will also need to be approved by US EPA. Finally, Dr. Duguid  highlights how stakeholder engagement and attention to environmental justice considerations will be a key part of the regulatory process and project development.

    Michael and Andrew also talk about what’s new, now and next with respect to the topics outlined above.

    This webinar is categorized under the Reservoir technical discipline.

    All content contained within this webinar is copyrighted by Michael Godec and Andrew Duguid and its use and/or reproduction outside the portal requires express permission from Michael Godec and Andrew Duguid.

    This webinar is a collaboration between SPE, IOGCC and EDF.

    image

    Andrew Duguid

    Andrew Duguid is a Vice President at Advanced Resources International, Inc. Dr. Duguid has over 15 years of research and commercial experience in Carbon Capture, Utilization, and Storage (CCUS), CO2-enhanced oil recovery (EOR), well integrity assessment, and risk assessment topics.  Dr. Duguid has managed screening and modeling studies many ethanol plants and currently leads efforts to develop storage projects in Nebraska, Kansas, and Illinois. Dr. Duguid has acted as the principal investigator multiple US Department of Energy carbon storage projects, including the Phase I and II Integrated Midcontinent Stacked Carbon Storage Hub Carbon SAFE project. Dr. Duguid was heavily involved in the development of the Class VI Injection well permit applications the only two saline storage wells in the United States, the injection wells at ADM’s corn processing plant in Decatur, IL. Currently, Dr. Duguid specializes in developing projects taking advantage of 45Q tax credits and other incentives. Dr. Duguid has been a member of International Organization for Standardization (ISO), Technical Committee 265, Carbon Dioxide Capture, Transport, and Geological Storage, since 2013.  Dr. Duguid led technical panels on well infrastructure for the CO2-EOR workgroup (WG6) and saline storage (WG3).  He was also a member of the Quantification and Verification workgroup (WG4). Dr. Duguid is a member of the United States Mirror Committee, where he participated in the U.S. adoption of the CO2-EOR quantification and verification standard. He earned a Ph.D. and Master’s degree in Civil and Environmental Engineering and a certificate in Science, Technology, and Environmental Policy from Princeton University and Master’s degrees and a Bachelor’s degree in Civil and Environmental Engineering and Nuclear Engineering from the Ohio State University.

    Michael L. Godec

    Michael L. Godec, a Vice President with Advanced Resources International, has prepared numerous assessments of the potential sequestration capacity and economic potential associated with geologic storage in oil and gas fields, deep saline aquifers, gas shales, and unmineable coal seams. Mr. Godec has examined CO2storage and possible CO2-EOR opportunities for numerous proposed power plants and other industrial facilities, both in the U.S. and internationally, and is currently leading storage project assessments for commercial projects. He is recognized as a national expert on the Internal Revenue Code Section 45Q tax credits and their role in assisting in the large-scale commercial deployment of CCS and CCUS in the U.S. Prior to joining Advanced Resources, Mr. Godec directed the Oil and Gas Consulting Practice at ICF Consulting and its predecessor companies. Mr. Godec is the author or co-author of more than 50papers and articles. For 2009-2010, Mr. Godec was a Society of Petroleum Engineers Distinguished Lecturer on the subject “Environmental Performance of the Exploration and Production Industry: Past, Present, and Future.”Mr. Godec has an M.S. in Technology and Human Affairs from Washington University in St. Louis, and a B.S. in Chemical Engineering from the University of Colorado, Boulder.

    Laura Sorey

    Laura Sorey joined the Louisiana Department of Natural Resources, Injection & Mining Division in 2019 and is a geology supervisor for Louisiana’s UIC program where she manages the permitting and oversight of Class I, II, and V injection wells. She also helped develop Louisiana’s application for Class VI injection well primacy that is currently under review by the EPA. Before coming to LDNR, she worked as a geologist for EarthCon Consultants and as an asset development geologist for Chevron. Laura is a licensed Professional Geoscientist in Louisiana and serves as a Director for the Baton Rouge Geological Society. A native of Mississippi, she earned her BS in geology from Millsaps College and an MS in geology from Louisiana State University.

    David E. Riestenberg (Moderator)

    This SPE webinar is sponsored by the Environmental Defense Fund and the Interstate Oil and Gas Compact Commission.

    image
  • Contains 3 Component(s), Includes Credits Includes a Live Web Event on 06/09/2022 at 9:00 AM (EDT)

    This webinar reviews chemical applications for produced water management.

    This webinar reviews chemical applications for produced water management.  Roy Goodwin talks about the following:

    • Oil in water challenges in oil production
    • Reverse emulsion theory – types of reverse emulsion and stabilizing factors
    • EOR considerations – focus on polymer flood treatment considerations
    • De-oiler chemical treatment modes of action
    • Application guidelines relating to maximizing process equipment performance

    This webinar is categorized under the Production and Operations technical discipline.

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

    Roy Goodwin

    Roy Goodwin is a Production Optimization Scientist at Baker Hughes, dealing principally with upstream chemical application for oil treatment, flow optimisation and produced water management. Roy has 15 years’ experience dealing with a range of oil and water treatment challenges across the globe, including the Gulf regions (Saudi and surrounding countries), Africa and the North Sea (UK, Norway, Denmark).

    Before joining Baker Hughes in 2019 Roy worked within Clariant’s Oil and Mining Services division specialising in demulsifier and water treatment chemicals. Roy holds MSc from the Robert Gordon University in Oilfield Chemicals and has a BSc in Microbiology from the University of Glasgow.

    Patricia E. Carreras (Moderator)

    Patricia E. Carreras main interests are reservoir engineering, field development planning, reservoir simulation, public speaking, mentoring and coaching. She has worked for more than 25 years for major, independent and consulting oil and gas companies. Ms. Carreras has a vast international work experience developed in Houston, Ciudad del Carmen (Mexico), and Buenos Aires.

    She is an active member of the Society of Petroleum Engineers, currently serving as Deputy Chair for the Diversity and Inclusion Standing Committee, Chair for the Gulf Coast Section Continuing Education Committee, and contributor of the SPE Water Life Cycle and Strategy Technical Section. Ms. Carreras is a past member of the SPEI Business Management and Leadership Committee (BMLC). She is one of the authors of the first ever D&I survey launched in May 2020 by the SPE BMLC. She also volunteers as a mentor for the SPE eMentoring program. Ms. Carreras received the 2020-2021 SPE Gulf Coast Section Exemplary award.

    Ms. Carreras holds a Bachelor’s degree in Petroleum Engineering from the University of Buenos Aires, and a Master’s of Engineering degree in Petroleum Engineering from Texas A&M University.

    SPE Webinars are FREE to members courtesy of the

    image
  • Contains 3 Component(s), Includes Credits Includes a Live Web Event on 06/02/2022 at 11:00 AM (EDT)

    A new method of accurately measuring permeability, skin damage and anisotropy with a short duration pretest using probes of different shapes is shown in this presentation. Pretesting operations with a Formation Tester (FT) normally require a depth-based survey consisting of at least 10 pretests to find the most promising locations for more extensive testing, such as an Interval Pressure Transient Test (IPTT) or acquiring a formation fluid sample. While an IPTT can yield accurate results for permeability, skin and anisotropy when compared to core samples and larger scale tests, such as drill stem testing, an IPTT is extremely time-consuming compared to a pretest.

    A new method of accurately measuring permeability, skin damage and anisotropy with a short duration pretest using probes of different shapes is shown in this presentation. Pretesting operations with a Formation Tester (FT) normally require a depth-based survey consisting of at least 10 pretests to find the most promising locations for more extensive testing, such as an Interval Pressure Transient Test (IPTT) or acquiring a formation fluid sample. While an IPTT can yield accurate results for permeability, skin and anisotropy when compared to core samples and larger scale tests, such as drill stem testing, an IPTT is extremely time-consuming compared to a pretest.

    One of the biggest unknowns in pretesting results is the skin effect that is attributed to mud invasion causing near wellbore rockface damage and pore plugging which can result in an order of magnitude error in the permeability measurement. However, if pretests could obtain accurate and comparable results to an IPTT, the time saved in FT logging operations would be reduced by at least 50% in addition to extracting more useful data in a single run.

    The new technique shown uses a typical pretest sequence that normally takes 5-10 minutes and yields results that would take hours with an IPTT, or over 24 hours with the new FT Deep Transient Testing (DTT) method. The fundamentals of this new method are detailed in this presentation using a simple probe arrangement: a circular probe in conjunction with an oval-shaped elongated probe. More complex probes, such as the focused-radial probe, can enable more accurate results, which is illustrated.  Other extensions are demonstrated, including delineating bedding layers, dipping angle, and azimuthal probe orientations. Additionally, a modified version of this method can be applied in very low permeability formations for unconventional plays.

    This webinar is categorized under the Reservoir technical discipline.

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

    Mark Proett

    Mark Proett is a senior petroleum engineering consultant working in O&G upstream technology for over 40 years. He worked for Aramco Services Company (5 years), Halliburton (35 years) and Schlumberger (2 years). He is best known for his publications advocating automated testing methods, focused sampling and the viability of formation testing-while-drilling (FTWD), which was introduced in 2002. Proett has been awarded 80 US patents and authored more than 60 technical papers, most of which deal with sampling and testing analysis methods. Proett has been an SPWLA Distinguished Speaker and SPE Distinguished Lecturer. In 2008 he received the SPWLA Distinguished Technical Achievement Award, in 2013 he was given the SPE Gulf Coast Regional Formation Evaluation Award and in 2017 the SPE International Formation Evaluation Award. He has a bachelor-of-science degree in mechanical engineering from the University of Maryland and a master-of-science degree from Johns Hopkins University.

    Dr. Roberto Aguilera (Moderator)

    Dr. Roberto Aguilera is Professor of petroleum engineering in the Schulich School of Engineering at the University of Calgary, Canada. He is the 2019 recipient of the SPE Distinguished Achievement Award for Petroleum Engineering Faculty, the 2021 recipient of the SPE Reservoir Description and Dynamics Award, past Executive Editor of the SPE Journal, an SPE Distinguished Lecturer for the 2000-2001 season discussing Naturally Fractured Reservoirs, a member of the SPE Legion of Honor and an SPE Lifetime member. His research concentrates on Naturally Fractured and Unconventional Reservoirs worldwide. He has rendered consulting and/or training services in more than 50 countries worldwide through his firm Servipetrol Ltd.

    SPE Webinars are FREE to members courtesy of the

    image
  • Contains 3 Component(s), Includes Credits Includes a Live Web Event on 05/26/2022 at 1:00 PM (EDT)

    This presentation will cover several aspects of CO2 transport via pipeline. The presentation will start with a high-level comparison of natural gas transport vs. CO2 transport in pipelines. This will be followed by a review of CO2 properties and phase behavior as they relate to transport of CO2 via pipelines. Finally, the presentation will close with a discussion of the potential to re-use existing natural gas pipelines for CO2 transport.

    This presentation will cover several aspects of CO2 transport via pipeline. The presentation will start with a high-level comparison of natural gas transport vs. CO2 transport in pipelines, highlighting key similarities and differences that may impact the processing requirements upstream of the pipeline and the design of the pipeline itself. This comparison will serve to frame the remainder of the presentation which will focus on specific aspects of CO2 transport in pipelines. The first aspect of CO2 transport that will be covered is pre-conditioning of CO2 prior to transport, including a brief review of common impurities and processing options. This will be followed by a review of CO2 properties and phase behavior as they relate to transport of CO2 via pipelines. This review will include discussion of “typical” CO2 transport conditions, impacts of impurities on CO2 phase behavior, and any specific risks or challenges associated with transporting CO2 via pipeline. A general overview of pipeline design considerations (from process engineering perspective) will also be covered in the presentation. Specific examples, case studies, or operating scenarios may be reviewed to substantiate points in the preceding topic areas. Finally, the presentation will close with a discussion of the potential to re-use existing natural gas pipelines for CO2 transport.

    This webinar is categorized under the Projects, Facilities, and Construction technical discipline.

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

    Dr. Darshan Sachde

    Dr. Darshan Sachde is a Senior Process Engineer with Trimeric Corporation. Dr. Sachde has over 10 years of experience as a chemical process engineer, approaching six years with Trimeric. In addition to broad process engineering experience in oil refining, gas treating, sulfur processing, polymer processing, and semiconductors, he has a depth of experience in CO2 capture and sequestration (CCS). Specifically, he has supported CCS projects from early-phase concept development through FEED engineering, covering technical aspects including a variety CO2 capture technology, CO2 compression and purification, and CO2 transport by pipeline and other means (e.g., trucks). Recent relevant work includes supporting the University of Texas Bureau of Economic Geology (UT BEG) in evaluating re-use of existing oil and gas infrastructure in the Gulf of Mexico for CO2 transport and supporting several commercial clients in the evaluation of CO2 source to sink project evaluation and development.

    Dr. Sachde obtained his B.S. and PhD in Chemical Engineering from the University of Texas at Austin with his doctoral work focused on process development and simulation of amine scrubbing processes. He currently resides in the Austin, Texas area.

    Dr. Carolyn Koh (Moderator)

    Dr. Carolyn Koh is the William K. Coors Distinguished Chair & Professor of Chemical and Biological Engineering and Director of the Center for Hydrate Research at the Colorado School of Mines (CSM). She obtained her BSc (hons) and Ph.D. degrees from University of W. London and postdoctoral training at Cornell University. She was a Reader at King’s College, London University before joining the Colorado School of Mines. She has been visiting Professor at Cornell, Penn State and London University. She was a consultant for the Gas Research Institute in Chicago and is a Fellow of the Royal Society of Chemistry, Associate Editor of the Society for Petroleum Engineers Journal, Chair of the US DOE Methane Hydrate Advisory Committee (2019-2021), and many more.  She was elected Chair of the Gordon Research Conferences on Gas Hydrates in 2018 and Chair of the International Conference on Gas Hydrates (ICGH9) in 2017, and is Chairperson of the SPE Flow Assurance Technology Section in 2022. She has established internationally recognized gas hydrate research programs over the last two decades at King’s College, University of London and the Colorado School of Mines. She has received several awards, including the Young Scientist Award of the British Association for Crystal Growth, the CSM Young Faculty Research Excellence Award (2012), Dean’s Award (2016), IChemE Guggenheim Medal (2021), Yeram S. Touloukian Award - ASME (2021), and GPA Donald L. Katz Award (2021). She over 200 publications in refereed journals (h-index: 75, 29,815 citations – GoogleScholar).

    SPE Webinars are FREE to members courtesy of the

    image
  • Contains 3 Component(s), Includes Credits Includes a Live Web Event on 05/19/2022 at 11:00 AM (EDT)

    The webinar shows how innovations in non-destructive micron-resolution three-dimensional reservoir-condition X-ray imaging with associated analysis and modelling methods have transformed our understanding of flow in porous media. The speaker talks about traditional oil and gas applications but will also emphasize how the same techniques can be applied to the energy transition, and specifically to study multiphase flow in porous materials for carbon dioxide and hydrogen storage, as well as electrochemical devices.

    Flow in Porous Media in the Energy Transition:

    The webinar shows how innovations in non-destructive micron-resolution three-dimensional reservoir-condition X-ray imaging with associated analysis and modelling methods have transformed our understanding of flow in porous media.  The speaker talks about traditional oil and gas applications but will also emphasize how the same techniques can be applied to the energy transition, and specifically to study multiphase flow in porous materials for carbon dioxide and hydrogen storage, as well as electrochemical devices.

    Dr. Blunt shows how imaging can be used to enhance traditional core flood studies through providing insight into displacement processes.  An overview of the technology is presented with a perspective to the future.  Emphasis is placed on using fundamental insights to interpret and design a variety of porous media processes, as opposed to simply characterizing flow properties.  Specifically, Dr. Blunt shows how to design the pore structure and wettability to ensure either efficient trapping (retention of one phase) or flow (allowing two phases to flow through the porous material over a wide saturation range).  He  demonstrates how, in mixed-wet media, which are ubiquitous in natural and engineered settings, fluid-fluid interfaces have radii of curvature with opposite signs in orthogonal directions.  This gives the interfaces a negative Gaussian curvature and good connectivity, which is valuable in several important displacement processes.

    Benoit Noetinger talks about up-scaling issues related to Energy transition oriented applications of flow in porous media.

    This webinar is categorized under the Reservoir technical discipline.

    All content contained within this webinar is copyrighted by Dr. Martin Blunt, Benoit Noetinger and Ram Ratnakar and its use and/or reproduction outside the portal requires express permission from Dr. Martin Blunt, Benoit Noetinger and Ram Ratnakar.

    Dr. Martin Blunt

    Over the last ten years, Dr. Martin Blunt and his research team have pioneered the use of Xray micro-tomography to image rocks and fluid displacement within them. Displacement processes at reservoir conditions of high temperature and pressure can be imaged at micron spatial resolution over time periods of an hour to a few seconds, using a combination of laboratory and synchrotron-based instruments. 

    Dr. Blunt is Professor of Flow in Porous Media at Imperial College London, which he joined in 1999. He was elected a Fellow of the Royal Academy of Engineering in 2019. Before he joined Imperial, he was an Associate Professor of Petroleum Engineering at Stanford University in California. Before joining Stanford in 1992, he was a research reservoir engineer with BP in Sunbury-on-Thames. He holds MA and PhD (1988) degrees in theoretical physics from Cambridge University. Professor Blunt's research interests are in multiphase flow in porous media with applications to geological carbon storage, oil and gas recovery, and contaminant transport and clean-up in polluted aquifers. He performs experimental, theoretical and numerical research into many aspects of flow and transport in porous systems, including pore-scale modelling of displacement processes, and large-scale simulation using streamline-based methods.

    Benoit Noetinger

    Benoît Noetinger  graduated from the École Polytechnique in Paris, and holds a thesis at UPMC (now Sorbonne University) in liquid state physics, the work of which was carried out at the PMMH laboratory of ESPCI. He supported an HDR at UPMC in 2000.

    He joined IFPEN in 1989, to work on the development of up-scaling techniques allowing to carry out large-scale simulations of flows in porous media by using detailed information as well as possible, that are more and more numerous because of the improvement of acquisition techniques.

    Benoît has taken responsibility for various research projects involving industrial partners (PETROBRAS, TOTAL, Gaz de France), while co-supervising thesis projects allowing him to stay in close contact with  academic teams. He also developed original techniques from statistical physics to model flows in fractured media.

    Benoît was advisor of 8 PhD students and teaches in engineering schools such as Centralesupelec, les Mines de Paris, IFP School, UPPA. He taught at university of  Wyoming. He is invited visiting scientist at USTC Hefei,  China. He is member of scientific committees of conferences such as NTERPORE international conference on Porous media.

    He authored 7 patents and  70 peer-reviewed articles. He evaluated grant applications ANR, he carried out laboratory evaluations HCERES.  He is member of the editorial committee of CR Géosciences, published by French Académie des Sciences. He is chief editor of STET review, an open access without APC WoS journal devoted to energy transition supported by CEA and IFPEN.

    Dr. Ram Ratnakar

    Dr. Ram R. Ratnakar is a Subject Matter Expert of thermodynamics/PVT and a Sr. Researcher in R&D - Mathematics and Computation discipline in Shell International Exploration & Production Inc., Houston, Texas. He is serving as Editor-in-chief of Upstream Oil & Gas Technology Journal, Editorial advisor of J. of Natural Gas Science and Engineering, and a member of few SPE’s advisory committees: Reservoir Technical Discipline (RAC), Data Science and Engineering Analytics (DSEA), and Geothermal Energy (GE). He received his B.Tech. in Chemical Engineering from the Indian Institute of Technology, Delhi, India and Ph.D. in Chemical Engineering from University of Houston, Texas, USA. He has served as technical reviewer of various prestigious peer review journals, authored more than 50 technical articles, and contributed significantly to the areas of multiscale modeling, reactive-transport, PVT and new energy technologies such as hydrogen, dense energy careers, carbon capture and utilization, and electrification.

    Dr. Yucel Akkutlu (Moderator)

    Dr. Yucel Akkutlu is petroleum engineering professor and William Keeler faculty fellow at Texas A&M University. He is the holder of the John Edgar Holt ’27 Chair in the Harold Vance Department of Petroleum Engineering. His research focuses on reactive flow in porous media with applications into characterization and exploitation of unconventional oil and gas resources. He received the Society of Petroleum Engineers International Lester C. Uren Award for Distinguished Achievement in the Technology of Petroleum Engineering in 2020 and received 2015 AIME Rossiter W. Raymond memorial award for research. He was the executive editor of the SPE Journal 2013-2016. He was an SPE distinguished lecturer 2014-15.

    SPE Webinars are FREE to members courtesy of the

    image