Singapore Section

Upscaling Formation Damage Laboratory Test Data to Full Well Perspective

Abstract: The impact of formation damage on overall well productivity or injectivity depends on the magnitude and distribution of the damage. Computational Fluid Dynamics (CFD) simulation provides a means to upscale suitable laboratory test data to quantify the impact of formation damage on well performance, by representing the degree of restriction and the geometry of the damaged zone or zones in a full well simulation. Different magnitudes of damage derived from laboratory test data can be simulated and the impact on overall well performance predicted for different completion environments. This presentation will illustrate some applications of CFD modelling to upscaling of laboratory measured formation damage, and attempt to tackle the issue of the interface between well construction and well deliverability.   BIO: Rick Lemanczyk is Principal Petroleum Engineer in Lloyds Register Energy’s Consulting Division, based in Kuala Lumpur, and has a career spanning over 39 years in various aspects of production technology.  After graduating with a D.Phil. in Physical Chemistry from Oxford University, Rick began his oilfield career with Schlumberger from 1977-1992 in a variety of positions: wireline engineer, well stimulation R&D department head and regional laboratory manager. Between 1994 -2006 he worked for Edinburgh Petroleum Services Ltd. ( now a Weatherford company), providing technical support, business development, consulting and training in the areas of production optimization, artificial lift, sand management, well stimulation, completion analysis and formation damage.  In LR Senergy Rick’s current role is to coordinate the company’s rock properties and production chemistry activity in the Asia Pacific region.  Throughout his oilfield career Rick has conducted many training courses and lectured widely on Production Technology subjects. In 1992-94 he was a Senior Research Fellow at Heriot-Watt University in Edinburgh, and in 2016-17 Adjunct Professor at Heriot-Watt’s Malaysia campus. He was nominated as an SPE Distinguished Lecturer in gas lift optimisation for 2010-2011.

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Distinguished Lecture Dave Stern: Creating Geologically Realistic Models Used for Reservoir Manageme

A delicious lunch buffet and an informative lecture by the DL Dave Stern on Creating Geologically Realistic Models Used for Reservoir Management Abstract To make sensible reservoir management decisions, it is necessary to predict future reservoir performance.  This allows testing and optimization of reservoir management strategies before making large investments.   When displacement mechanisms change or geologic description is different from current well locations, this prediction is usually done with reservoir simulation models.   Because geologic features determine the connectivity and productivity of the reservoir, it is important to ensure that models realistically represent the reservoir description in order to provide plausible predictions.   Challenges associated with constructing these models include: Uncertainty in the geologic description – measurements are sparse, and do not always resolve the relevant features . It isn’t always known which features are relevant to reservoir performance.   Geometry and stacking of geologic objects like channels and lobes are difficult to represent in cellular models Multiple descriptions may exist that are consistent with available data This presentation describes how reservoir models are used in making reservoir management decisions, and outlines a strategy for creating realistic reservoir models.  Examples are provided of applying some elements of this strategy. Biography Dave Stern is a career researcher at ExxonMobil’s Upstream Research Company (URC) He joined URC in 1984 with a PhD in Chemical Engineering from University of California at Berkeley and a BS in Chemical Engineering from MIT.  Research areas include experimental measurement of gas injection performance, development and use of simplified models for reservoir management, gridding and scale-up, and history matching. He led a team that developed tools for construction of simulation models from detailed geologic models, worked with software developers to implement that technology, and trained the rest of the corporation in its use.   Dave is the author of an SPE distinguished author paper on practical aspects of gridding and scale-up, describing learnings from that experience. Dave also led a team that developed tools and methods for history matching, with emphasis on preserving geologic realism during the history match process.   The team worked with software developers to implement the tools, and trained the rest of the corporation in their use.   He is currently a Reservoir Engineering Advisor to a large project that develops and maintains software for reservoir modeling and simulation. Dave is a career-long member of SPE, and has served as session chair or discussion leader in SPE forums on gridding and scale-up, reservoir modeling for asset teams, and data analytics.  

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2018 Revision to the Petroleum Reserves 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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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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The Seapex Exploration Conference 2019

The SEAPEX Exploration Conference is a not-to-be-missed biennial event for upstream oil and gas industry professionals and investors. With a line-up of more than 30 presentations from across Asia-Pacific, SEAPEX 2019 will disseminate critical upstream knowledge, provide firstrate networking opportunities and promote investment in the region. Please note that SEAPEX membership is required for attendance and is included in the registration fee. Sign up now and enjoy the early bird discount rate as well as the benefits of SEAPEX membership until October 2019. For details about the South East Asia Petroleum Exploration Society, visit www.seapexconf.org

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.

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