Singapore Section

2018 Revision to the Petroleum Resources Management System

Abstract: The Petroleum Resources Management System (PRMS) is the most widely used international standard for petroleum reserves and resources classification.  It is used within the oil and gas community and is also referenced by many regulatory bodies, stock exchanges and government agencies. A revision of the PRMS was approved by the SPE Board in June 2018 and is now available on the SPE website.  The updated PRMS is a consensus of input collected from consulting and financial firms, government agencies, and E&P companies.  The process included a 90-day public comment period and required input from six sponsoring societies. The presentation will summarise the main changes in the 2018 revision and will also serve as a refresher on the main principles of the PRMS, what it is and why it is important to the oil and gas industry.   Biography: Doug Peacock is a Technical Director with Gaffney, Cline & Associates, based in Singapore, where has been for the past 13 years.  He holds a B.Sc. in Geological Sciences from Leeds University, UK, and a M.Sc. in Petroleum Geology from Imperial College, London. He has over 30 years’ experience in the oil industry in a variety of geoscience positions, during employment with service companies, operators and consultancies.  He has been involved in integrated applications, 3D modelling and reserves assessments throughout his career.   He was an SPE Distinguished Lecturer for 2010-2011 and from 2013-2016 was a member of the SPE Oil and Gas Reserves Committee.

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Reservoir Management Challenges in Commingled Wells … and ways to overcome them

Reservoir Management Challenges in Commingled Wells … and ways to overcome them   Speaker: Nick Last Well Test Knowledge International Perth, Australia   Abstract: Commingled completions are a cost effective strategy to produce from multiple independent stacked sand reservoirs. They are widely used across the Asia Pacific region, especially for gas production, and have been implemented in a variety of well types ranging from simple 2-7/8" monobores in the Gulf of Thailand to large bore sub-sea completions offshore Western Australia.  But commingling presents a number of reservoir management challenges, including allocation of production back to individual zones, identifying the distribution of resource between those zones, and dealing with water influx that can shorten the well's life dramatically. This talk highlights the differences in behaviour between commingled and conventional single-sand completions, and examines various surveillance and well analysis options that can shed light on the resource distribution and help to optimize ultimate recovery.   Bio: Nick Last started his career with Schlumberger in the North Sea in the 1980’s, working as a well test supervisor, logging engineer and well test interpretation specialist, before moving to Thailand as Location Manager. Since leaving Schlumberger he has consulted for numerous Operators throughout SE Asia and Australasia, specializing in developing testing and surveillance strategies and making sense of the resulting data. He has been wrestling with the challenges of commingled gas production for two decades, and has used that experience to teach numerous classes on well testing, production log and pressure transient interpretation, and commingled reservoir management. Nick is currently Director of Well Test Knowledge International in Perth, Western Australia.

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Erosion Due to Fine Particles in Multiphase Flow

Abstract: Pipeline production system often experiences complex multiphase flow and entrained fine-particles. The erosion due to solid fine particles presents one of the greatest threats to oil and gas flow assurance and consequently impacting material selection and wall thickness design. Limited literature is available on erosional effect caused by submicron particles such as fine sand, abrasive solid materials or gas bubbles. Previous studies on particles’ erosion are limited to particle size greater than 100 microns in single phase fluid flow. This is based on the assumption that potential for erosion by particle size smaller than 100 microns (specifically lesser than 62.5 microns) is insignificant. Additionally, very few studies have addressed the combined effect of erosion caused by micro-sized particles and multiphase flow.   Most predictive erosion models are limited to single phase flow for model simplification purposes. Hence, the effects of multiphase flow and its interaction with sand particles, specifically fine solids, are neglected. Therefore, an in-depth understanding of multiphase flow regimes and its interaction with micro-sized particles is an important enabler for more accurate erosion prediction. For more accurate flow modeling and erosion characterization, computer fluid dynamics (CFD) tool is required. In this study, Multiphase CFD (MCFD) is implemented for predicting micro-fine erosion, considering two phase flow pattern features. Concurrently, trajectories of fine particles’ bombardment on the pipe inner wall surface are captured using Lagrangian Particle Tracking Model. Analyses are carried out for water and gas flow at isothermal conditions, covering various particle size lesser than 62.5 microns in order to determine material removal rate. The results will be benchmarked against Tulsa multiphase erosion model prediction.   Based on the results, it is concluded that the erosional effect caused by micro-sized particles is strongly dependent on the flow patterns in the pipe, determined by superficial velocities of each phase. Additionally, erosional impact or material removal rate is predicted, which though small, is expected to significantly impact material design. The presence of these micro-sized particles acts as an enabler, which produces homogeneous “pits” on the surface of metal, significantly increasing the contact surface area for chemical and mechanical interactions to take place. The results from the proposed modeling using MCFD are expected to benefit erosion impact assessment in multiphase hydrocarbon production and piping systems.   Keywords- Erosion Analysis, Submicron Particles, Fines, Multiphase CFD, Flow Pattern Features       Author biography: Ngo Nguyet Tran is currently a Flow Assurance Engineer with WorleyParsons - INTECSEA division, based in Singapore. She earns a B.Eng (Hons) in Petroleum Engineering and M.Sc. in Mechanical Engineering – Flow Assurance Study from Universiti Teknologi PETRONAS, Malaysia. She has over four years’ experience in transient multiphase flow and flow assurance related issues. Other technical experience in subsurface-surface modeling and CFD modeling. She is a member of the SPE Singapore Section Committee.  

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YP Networking with the other Singapore Energy Networks. Digital Innovation Organization at BP

The collaboration between the Singapore Energy Networks (SPE, AIPN, SEAPEX and EI) is bringing together one of their great networking session again, supported by a hot-topic talk: BP’s priorities around digital innovation (including blockchain, AI, smart contracting, robotics etc). Speaker: Claus Nehmzow,  Topic: Digital Innovation Organization at British Petroleum Thursday, 1 November 2018 6:30 p.m. Venue: The Screening Room, Studio, Level 2 12 Ann Siang Road, Singapore This event is intended to be less technical than the SPE talks, and are therefore a great  entry door to networking for young professionals, and a good opportunity for professionals interested more in networking than technical content. The topic, digital innovation at the organisational level, should be of interest to almost anyone that want to open their perspectives and bring some out-of-the-box elements to their thinking process. To register please use this link . SPE members benefit from a reduced rate of SGD30. The SPE discount code to use on registration (at the link above) is SPE40 . Biography: Claus is responsible for the Asia Pacific region of BP’s Digital Innovation Organization ﴾DIO﴿. Claus heads all the DIO activities, from sourcing innovation to helping the business units in the region identify their needs and implement Proof of Concept projects. DIO uses digital innovation to meet BP’s business challenges.  The team looks at a wide variety of sources of innovation outside of the energy industry, including the entertainment, consumer electronic, and military sectors. It nurtures collaborative relationships with the most innovative technology suppliers, consultants, venture capitalists, incubators, accelerators, academics, business practitioners, and industry and government organizations. As a leading expert in innovation, Claus was invited to speak at the: - Asia Downstream Summit Singapore June 2018 - Keynote presentation at Downstream Asia Week 2016 in Singapore - Advisory panel for Launchpad @OneNorth, for Industry and Trade Minister Teo Ser Luck  - Financial Times Smarter World Summit Singapore - Chief Innovation Summit Singapore - Commercial UAV Show Asia, Singapore - Opening of investment fund of Intellectual Ventures, Singapore - Future Tech Enterprise Singapore - DHL Asia Pacific Innovation Centre Innovation Summit 2015, Singapore

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Can humans create earthquakes? An overview of how hydraulic fracturing can induce seismicity

As part of our collaboration with the NUS, we are very happy to be welcoming Dr Fehler at our November meeting. Mike Fehler’s research is concerned with seismic and electromagnetic Imaging and microearthquake monitoring and interpretation around the production of hydrocarbons, in geothermal energy production and reservoir characterization. Abstract: Hydraulic fracturing is a method routinely used in oil and gas extraction and in the development of engineered geothermal systems. This method increases the permeability of source rock, making it possible for oil, gas, or heat, to be recovered. While applied frequently, there are many aspects of hydraulic fracturing that are not well understood, such as the induced seismicity produced during these operations. While this induced seismicity is useful to monitor the hydraulic fracturing processes, it may also cause fear to nearby communities. We will discuss several cases where induced seismicity has been observed that illustrate several aspects of the seismicity. We will discuss the mechanisms of hydraulic fracturing and how earthquakes are caused by it. Finally we will discuss the benefits of studying the induced seismicity. Michael Fehler After receiving his Ph.D. in Geophysics from MIT in 1979, Fehler worked as Assistant Professor at Oregon State University for five years before becoming a Staff geoscientist at Los Alamos National Laboratory in 1984. At Los Alamos, he was the Leader of the Geophysics Group and later the Division Director of the Earth and Environmental Sciences Division. In 2008 he returned to MIT where he is a Senior Research Scientist and the Deputy Director of ERL. In addition to his work at MIT, Fehler is Technical Project Manager for Phase I of the SEG Advanced Modeling project (SEAM) an industry consortium for geophysical modeling. Fehler was Editor-in-Chief of the Bulletin of the Seismological Society of America for nine years beginning in 1995 and president of the Seismological Society of America from 2005-2007. *** Advance registration is not required, come early to avoid disappointment Entry includes buffet dinner and two drinks. You can pay cash or credit card at the door. Students can get free entry (no drinks vouchers included) at the door. *** You are also welcome to the workshop on the topic of "Induced Seismicity Accompanying Gas Injection into a Depleted Oil Reservoir" that will be taking place at NUS, Room  EA-06-02 , Faculty of Engineering, on Wednesday 14th of November 2018 at 4:30 PM to 6 PM. Pre-registrations is not required and admission is free. Enquieries to Ms. Ivy Poh Tel: 6516 6853, Email: ceepab@nus.edu.sg

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Conventional & Unconventional Reservoirs; What is In and Out in Today’s Pressure and Rate Transient

Conventional & Unconventional Reservoirs; What is In and Out in Today’s Pressure and Rate Transient Analysis Medhat (Med) Kamal Chevron (Emeritus)     Abstract:   Transient data is rich in information about the dynamic characteristics of the well/reservoir system. It has been used extensively by petroleum engineers since the 1920’s. Sustained development in this area is necessitated by three factors: (1) changes in the types of reservoirs we produce (e.g. conventional, unconventional) and their stages of recovery (e.g., primary, secondary), (2) new tools (e.g. formation testers, permanent downhole gauges), and (3) advances in solution techniques (e.g., use of computers, deconvolution). Today, the value and use of transient data are at an all-time high. Several crucial technology advancements were achieved during the last 10-15 years. The aim of this lecture is to update the audience about the increased capabilities of Pressure and Rate Transient analyses (PTA and RTA respectively) and how to use them to optimize reservoir management. After a brief review of existing methods in PTA / RTA, new developments will be discussed with special emphasis on integration and the role of the engineer to obtain a sensible and consistent reservoir model. Practical applications will be discussed including: characterizing unconventional reservoirs by combining multiple measurements, determining permeability and fluid saturations  under multi-phase flow conditions, integrating the analytical and numerical solutions, combining single and multi-well tests to characterize the reservoir anisotropy, calculating the average reservoir pressure under non-uniform production and boundary conditions, and using continuous measurements of well pressures to integrate PTA and RTA to characterize reservoirs. For each case, best practices and their limitations will be presented.          Biography:   Medhat (Med) Kamal is a Chevron Emeritus Fellow and SPE Honorary member with over 40 years of industry experience in well testing, reservoir description and production and reservoir engineering. He is the editor and lead author of SPE Monograph 23 “ Transient Well Testing ”, and has published 35+ technical papers in SPE journals. He holds BSc (Hons.) from Cairo University, and MS and PhD from Stanford University in petroleum engineering. Kamal was an SPE board member and served as the Executive Editor of SPEREE. He received several regional and international awards including the Cedric Ferguson Medal and SPE Formation Evaluation Award.

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Reservoir and Fluid Characterization with Formation Testers: Reducing Asset Uncertainties

Society of Petroleum Engineers Distinguished Lecturer 2018-19 Lecture Season   Reservoir and Fluid Characterization with Formation Testers: Reducing Asset Uncertainties                                               Cosan Ayan     Abstract:   Formation Testers (FT) have been around for more than 50 years. Early 1990’s, have seen the emergence of pumpout wireline formation testers (WFT) which modernized their applications, including better fluid sampling, permeability and anisotropy measurements and basic downhole fluid analysis. Now, the technology is advancing further in both hardware and software as we are entering a new era in formation testing. While the industry is pushed to reduce costs, compromises on reservoir and fluid characterization can have detrimental effects in new projects and emerging FT applications are well poised to provide critical answers to reduce asset uncertainties.   In this lecture, we will briefly focus on existing and emerging hardware/software on formation testing but our focus will be on applications of acquired and interpreted data for reservoir and fluid characterization.  We will discuss pressure gradient analysis and implications of gradient errors for reservoir engineers.  We will review the effects of OBM contamination on fluid uncertainties and the choice of inlet types on cleanup behavior.  Emerging downhole fluid analysis sensors will be discussed and a new deep transient testing method will be introduced.  In-situ stress testing with WFT will be outlined with drilling and reservoir engineering applications. We will discuss these points with field examples. Finally, desired features of next generation WFT will be outlined.   Biography:   Dr. Cosan Ayan was a Reservoir Engineering Advisor for Schlumberger Wireline Headquarters based in Paris, France, who has opted for early retirement in June 2017. Cosan had several international assignments covering Houston-USA, Indonesia-Jakarta, United Kingdom-Aberdeen, UAE-Abu Dhabi, and Egypt-Cairo. He holds BS degree from Middle East Technical University, Ankara, MS and Ph.D. degrees from Texas A&M University, College Station all in Petroleum Engineering. He is the author of more than eighty-five technical papers on Well Testing and Reservoir Engineering and was a SPE Distinguished Lecturer during 2005-2006. Cosan served as an Executive Editor for SPE REE Journal from 2007-2010 and edited SPE e-book volumes on “Getting Up-To-Speed: Formation Testing”. Cosan received the SPE Formation Evaluation Award, September 2015.

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Formation Evaluation and Petrophysics: From Technical to Business Impact

Abstract: It is commonly accepted that petrophysics/ formation evaluation is critical for quantitative full field evaluation, yet the perception among some is that its mostly about expensive logging, calculating net-to-gross, porosity and saturation. However, from a business perspective, it’s much more than that. Petrophysics is integral throughout the life cycle of the field, and one of the aims of this talk is to show that by engaging your petrophysics teams early, and keeping them engaged through the process, significant business uplift can be achieved. In particular, this talk will highlight a concept known as the “petrophysical value chain” as it relates to exploration, development and production. This talk will also use show some real world examples of how logs, if incorrectly interpreted, can result in lost opportunities, and that sometimes, the interpretation is itself bounded by the complexities of the operations itself, requiring more than just logging to get to an answer that makes (economic) sense. Finally, there will be a discussion on how petrophysicists must avoid the “silo” effect that can come with being practitioners of this discipline. About the Speaker: Munish Kumar is currently a Sr. Petrophysicist with Total Asia Pacific Exploration, based in Singapore. His focus is on operational petrophysics and formation evaluation of assets in Asia, Australia and the Pacific region. Prior to this, he was a Sr. Petrophysicist with ExxonMobil (Exploration, Development and Production) in Australia and Houston, working on fields in Alaska, Gulf of Mexico, Mexico, W. Africa, Indonesia, Papua New Guinea, North West Shelf and Gippsland Basin, Victoria. He has a PhD in Physics and Engineering (Applied Mathematics) from the Australian National University (2010) and a BEng (Hons) in Electrical and Computer Engineering from the National University of Singapore (2005). His interests include multiphase flow in reservoir systems, core analysis , computer vision and image analysis, machine learning applications and data analytics as a means to analyze complex petrophysical problems.

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Big Data Analytics: What Can It Do For Petroleum Engineers And Geoscientists?

Big Data Analytics: What Can It Do For Petroleum Engineers And Geoscientists?                                               Srikanta Mishra     Abstract:   Big data analytics has become quite the buzzword in recent years, and its growing application in E&P operations promises to be an exciting new development.  It involves: (1) acquiring and managing data in large volumes, of different varieties, and at high velocities, and (2) using statistical techniques to “mine” the data and discover hidden patterns of association and relationships in large, complex, multivariate datasets.  The ultimate goal is to extract as much intelligence from our ever-expanding trove of data to improve operational efficiencies and make better decisions for optimizing the performance of petroleum reservoirs.  However, the subject remains a mystery to most petroleum engineers and geoscientists because of the statistics-heavy jargon and the use of complex algorithms. In this talk, I will provide a “gentle” introduction to big data analytics by focusing on: (a) easy-to-understand descriptions of the commonly-used concepts and techniques, (b) broad categories of E&P problems that can be solved with big data analytics, and (c) case studies demonstrating the value-added proposition for big data. The one key idea I would like to offer as a takeaway is this : There is significant potential for data analytics to provide insights that can be translated into actionable information in E&P projects, but petroleum engineers and geoscientists need to have a fundamental understanding of data-driven modeling concepts, their applicability and limitations.     Biography:   Dr. Srikanta Mishra is Institute Fellow and Chief Scientist (Energy) at Battelle Memorial Institute, the world's largest independent contract R&D organization, where he manages a geoscience-oriented technology portfolio related to computational modeling and data analytics for geological carbon storage, shale gas development and improved oil recovery projects.  Dr. Mishra is the author of “Applied Statistical Modeling and Data Analytics for the Petroleum Geosciences” recently published by Elsevier, and has also taught multiple short courses on uncertainty quantification, statistical modeling and data analytics.  He holds a PhD degree in Petroleum Engineering from Stanford University. The SPE Singapore is introducing a new payment option: You get a 10% discount on your entry if you transfer the money directly onto the SPE account: Payee name: Singapore SPE, DBS Bank Ltd, Account number: 0060123937 Student: S$27, Members: S$45, Non-Members: S$67.5 Pay at the door prices: Student: S$30, Members: S$50, Non-Members: S$75 Includes buffet and 2 drinks.  Please include your SPE member ID  for Students and Members, and your name in the message to the Payee.

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Democratization of LNG - Small Scale LNG and Feedstock Demand

Abstract: LNG is known as a transition fuel in our quest to reduce emissions and avoid catastrophic and runaway global warming.   While large gas to power projects (Gigawatts size) receives attention, LNG’s success will eventually be measured how it is used for small scale purposes and as feedstock to replace the high carbon liquid fuels. This means, LNG needs to be democratized.       For instance, in ASEAN context, the goal is to supply electricity to the remaining masses and to ensure energy security with the right mix. LNG fits nicely into this goal. However, the challenge is to supply LNG to areas with poor infrastructure where it can fire up small factories and micro power plants. For instance, in Indonesia, there are many power plants which are diesel fired in remote areas. There is a good economic case for LNG to displace diesel for these power plants if the correct value chains are configured. Further, to substitute other liquid fuel (Naphtha), LNG has to evolve into feedstock.   This presentation will discuss: Challenges in the democratization of LNG Small scale LNG uses and challenges Possible use of LNG for other purposes like feedstock   About the Speaker: Rao Shivaprakash is currently a Senior Associate at Advisian, WorleyParsons Group. He leads the Hydrocarbons consultancy team in Advisian’s global center of excellence for LNG regasification based in Singapore. He has worked in many diverse roles within LNG, Hydrocarbons, Petrochemical and Specialty Chemicals Industry over 23 years. Shiva holds a MBA in Finance and accredited degree in Chemical Engineering.   His key strengths include strategic analysis, project management and implementation. ​​​

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Site visit: Schlumberger on Benoit Rd

Schlumberger started out in 1970 with a warehouse in Singapore to sell electric submersible pumps (ESPs) to Indonesia. This soon expanded into an assembly and repair plant serving not just Asia, but the Middle East, Europe and Africa as well. Today, the world’s leading Oil and Gas technology services company has located 6 of its regional business units in Singapore, altogether employing about 1,600 employees. In particular, its Artificial Lift and Testing & Services business units have anchored global responsibility for manufacturing, engineering and R&D of several of its product lines here. With most of the world’s wells requiring artificial lift to boost or enable oil production by overcoming insufficient downhole pressure, Schlumberger’s ESPs have seen healthy demand over the years.Singapore’s manufacturing expertise and strong research capabilities have supported the French company’s push to produce high-quality systems, while constantly improving on them through cutting-edge innovation.With its official opening in 2006, Schlumberger’s Singapore Integration Centre expanded by almost 50% to accommodate the increased production of ESP systems. The company has also opened regional Centres of Excellences for drilling systems and surface systems here. These Centres serve both Asia Pacific and the Middle East.The most recent addition to Schlumberger’s Singapore operations is the Singapore Well Testing Centre, which opened in 2014. The first and only one of its kind in Asia, this Centre of Excellence undertakes global responsibility for the management, research and new product development, engineering and manufacturing of 2 key products: surface testing equipment and topside multiphase flowmeters. To register your interest, please send your full name, IC, phone number, SPE membership number, if applicable, the company you work for, and a sentence explaining why you would benefit from this visit, to paulinasvoboda@gmail.com.

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PVT talk + AGM

September's annual general meeting from 5:45 PM to 6:15 PM followed by the talk: A case study on quality checking fluid & PVT data for reservoir simulation and history matching Brief Description : Quality check of fluid composition and PVT data is a critical component in any EOS modeling project especially for projects involving EOS modeling for multiple fluids. This session will dive into a real case demonstrating the consideration going into quality checking historical fluid data to enable spot the outliers to allow develop common EOS model for history matching purposes.   Short Biography: Adil is a Chemical engineer with over 15 years of experience in Fluid domain including Fluid property measurements and Fluid behaviour modelling. His measurement experience covers wet chemistry, TBP, PVT analysis, EOR and Flow Assurance analysis andSampling. He has carried out several EoS modelling projects for reservoir and flow assurance evaluation studies. Adil has previously worked with Intertek & Schlumberger Reservoir Sampling and Analysis Group. He is currently the Regional manager for Calsep for Asia Pacific region.

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Development of Organic Shales Outside North America

Abstract:    The success of organic shale development in North America has brought a great interest in organic shale exploitation internationally. The employed drilling and completion practices are based on the techniques that have been successful in US, and hydraulic fracturing treatments are primarily dominated by slickwater owing to its low cost and benefit in maximizing the stimulated reservoir volume (SRV). However, the international shale plays are usually in high tectonic stress environment, complex geological structures, and frequently contain natural fractures, which are quite different from most of the plays in US with relatively simple structure and more relaxed stress environment. These complexities have resulted in additional challenges in both reservoir understanding and completions, and ultimately production performance. Proppant placement issues and casing deformation are commonly experienced in slickwater treatments in these tectonically active plays, and production results were below expectations in the early phase of the development. Numerous studies have been performed and revealed the stress sensitivity in all the wells in which the fracture system starts to deteriorate when the effective stress reaches the critical value, resulting in many perforation clusters not contributing to production. This leads to an important conclusion that fracture conductivity is equally important as the SRV for high stress organic shale plays, and the treatment strategy shall be recalibrated from current slickwater treatments. The presentation provides an overview of challenges in these organic shale plays with high tectonic stresses, and highlights a few important findings and practices that would address the problem and improve production performance.   Biography:   Liu Hai is Technical Advisor on production and stimulation in Schlumberger, and Domain Manager for Middle East and Asia region. He has been with the company for 17 years and worked in various positions in Asia, Middle East and Texas. Previously he was with the Production Technology Research Institute of PetroChina Xinjiang for 6 years.  His primary areas of expertise are in reservoir, production and stimulation. He has authored or coauthored more than 20 technical papers. He holds a BS degree in computer science from Xi’an Petroleum College of China, and a MS degree in petroleum engineering from Heriot-Watt University.

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Production Optimisation of Conventional and Unconventional Wells with ESP Real Time Data

Abstract:   Optimising production has always been important, but there is naturally a greater focus on high rate wells, such as those produced with ESPs (Electrical Submersible Pumps). A key driver is arresting decline while minimising infill drilling, which is often achieved by identifying wells with skin to identify stimulation candidates and increasing drawdown on wells with good pressure support. With unconventionals, accelerating production while minimising power consumption become dominant goals. This presentation explains how real-time gauge data enables high-frequency, high-resolution downhole flow rate measurements on ESP wells. Thereby providing both rate and pressure, which are essential to enabling inflow characterisation and thereby identifying optimisation opportunities without the need for traditional buildups, which cause production deferment.   Fortunately, technology advances have improved real time data quality in terms of both sampling frequency and metrology.  There has also been a reduction in the cost of measurement, transmission and storage, which signals the true dawn of the digital age. The presentation therefore also reviews how real time data enables increases in well uptime and ESP run life as well as minimising power consumption.  Using material from recent SPE papers, both theoretical methodology and real case studies are presented to illustrate the value of real time data for both conventional vertical wells and unconventional multifracked horizontal wells.  While the case studies are based on ESP applications, the lessons learnt on how to extract value from real-time data can be applied to other artificial lift techniques, especially since inflow characterisation is generic.   Biography:   Lawrence has over 33 years of experience in production operations of which 27 years have been focused on artificial lift in a variety of roles ranging from field and application engineer to his current role as Global Domain Head, which is Schlumberger’s most senior technical position in the Artificial Lift Division.  He has published over 16 SPE conference papers and 3 patents covering all aspects of ESP operation such as inflow characterization and advanced completions.  This body of work is particularly noteworthy as it combines theoretical explanations and field case studies using real time data.

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New Year Social

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Compositional Simulation that is Truly Compositional

Abstract:    Current compositional simulators include compositional equation-of-state fluid models, but do not account for compositional effects on relative permeability, capillary pressure, and grid-block flux calculations.  Relative permeability, for example, is still based on “old thinking” related to labeling of phases as “oil, gas, and water.”  Labeling causes significant discontinuities that can result in inaccuracies and instability in simulations of compositional processes, such as those for enhanced oil recovery (EOR).    This presentation will show you why labeling is “old thinking” and how labeling generates discontinuities and simulation errors in compositional processes.  Several example cases, including water-alternating-gas and surfactant flooding, are given using a new type of compositional simulator with all labels removed.   One component of the novel simulator is the development of an equation of state (EoS) for relative permeabilities that eliminates phase labeling.  The relative permeability model is physically based and captures complex hysteresis effects through saturation and phase connectivity as well as changing wettability, interfacial tension, and pore morphology.   Results show increased robustness, improved accuracy, faster computational times, and less instabilities when phase labeling is removed.   Biography:   Russell T. Johns is the George E. Trimble Chair of Energy and Mineral Sciences at the Department of Energy and Mineral Engineering at The Pennsylvania State University. He also holds the Energi Simulation Chair in Fluid Behavior and Rock Interactions.  He recently served as Chair of the Petroleum and Natural Gas Engineering Program, and is currently the Editor-In-Chief for SPE journals.    Prior to his current position at Penn State, he served on the petroleum engineering faculty at The University of Texas at Austin for fifteen years.  He also has nine years of industrial experience as a petrophysical engineer with Shell Oil and as a consulting engineer for Colenco Power Consulting in Baden, Switzerland.  He holds a BS degree in electrical engineering from Northwestern University and MS and PhD degrees in petroleum engineering from Stanford University.  He has over 250 publications in enhanced oil recovery, thermodynamics and phase behavior, unconventional gas engineering, multiphase flow in porous media, and well testing.  Dr. Johns received the SPE Ferguson medal in 1993, the SPE Distinguished Member award in 2009, the SPE Faculty Pipeline award in 2013, the 2016 SPE international award in Reservoir Description and Dynamics, and the 2018 Wilson Excellence in Research award from the College of Earth and Mineral Sciences.  He is currently director of the Enhanced Oil Recovery consortium in the EMS Energy Institute at Penn State University.

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