Singapore Section


  • 2018 Revision to the Petroleum Resources Management System

    Thursday, August 30, 2018, 6:00 PM - 9:30 PM MY
    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.

    Contact Information

    singapore, Singapore

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

    Thursday, September 20, 2018, 6:00 PM - 9:30 PM MY
    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.

    Contact Information

    189848, Singapore

  • Erosion Due to Fine Particles in Multiphase Flow

    Thursday, October 25, 2018, 6:00 PM - 9:30 PM SGT
    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.  

    Contact Information

    Singapore, Singapore

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

    Thursday, November 1, 2018, 6:30 PM - 9:30 PM SGT
    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

    Contact Information

    Singapore, Singapore

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

    Friday, November 16, 2018, 6:00 PM - 10:00 PM SGT
    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

    Contact Information

    Singapore, Singapore

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

    Monday, December 10, 2018, 6:00 PM - 9:51 PM SGT
    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.

    Contact Information

    singapore, Singapore

  • The Problem with Silt in Low Resistivity Low Contrast Pay Reservoirs

    Thursday, January 24, 2019, 6:30 PM - 9:45 PM SGT
    Abstract   Clastic laminated reservoirs have historically posed difficulties in formation evaluation. Difficulties are largely due to convoluted log responses which preclude accurate assessment of key petrophysical properties such as thin sand bed porosity and water saturation. In South East Asian (SEA) basins the abundance of silt in reservoir and non-reservoir rocks adds another layer of complexity and directly affects the design of appropriate data acquisition programs. This paper describes the silty thin bed problem by assessing the efficacy and uncertainties of various log measurements to arrive at the correct petrophysical solution. A review of rock physics literature is presented to highlight the underlying reasons for log behavior in silty facies. Generally, laminated rocks are evaluated from two different approaches: (1) high-resolution or (2) bulk rock volume. High-resolution approaches include borehole image logs, de-convolution, and digital core imaging analysis. Bulk rock (or volumetric) approaches generally use Thomas-Stieber, multi-component resistivity, and nuclear magnetic resonance (NMR) techniques. Three wells drilled in different sedimentary basins in SEA were selected to demonstrate the theory, challenges, and pitfalls of the most common approaches and techniques.     The Thomas-Stieber approach is often regarded as the most suitable for a binary sand-shale system and if conditional assumptions are met, results in a linear trend from which net-to-gross can be calculated. Adding a third component, such as silt, violates the assumptions and distorts this trend into a non-linear "boomerang" shape.    Resistivity anisotropy, i.e., vertical/horizontal resistivity ratio (Rv/Rh), provides further necessary input for accurate formation evaluation in laminated sand-silt-clay systems. Vertical resistivity is a key measurement as it is very sensitive to hydrocarbons in thinly laminated sands. Additional information, like borehole image and NMR data, contribute to reducing net-to-gross uncertainty and understanding the reservoir geometry. Where available, the saturation height function results are compared to multi-component resistivity results. One very silty to fine-grained sand reservoir in Vietnam, displays anisotropy due to grain-size variation on a very fine level. In this example, the relevance of shale laminar volume is questioned and can only be justified with detailed core studies. It is, however, argued that reliable identification of hydrocarbon-bearing silt-rich sequences is only possible with multi-component resistivity data. In addition, quantification of sand lamina resistivity, Rsand, is possible in silty sands with variable amounts of irreducible water.    Although many papers discuss the thin-bed formation evaluation problem, very few publications address issues related to laminated sand-silt-clay reservoirs. This paper partly addresses this literature scarcity.   Bio: Alexander Belevich graduated from Kuban State University in Russia with University Degree in Formation Evaluation. Alexander has worked in various locations in Russia (Siberia, above the Arctic circle and Moscow). Later moved to Vietnam for a 4 year stint and has been working in Malaysia for the last 3 years as Asia Pacific regional petrophysics advisor, doing field studies, designing and supporting acquisition of wireline & LWD open hole programs. Has special interest in evaluation of LRLC reservoirs, interpretation of NMR and 3D Resistivity logs, log and core data integration.

    Contact Information

    Singapore, Singapore

  • Reservoir and Fluid Characterization with Formation Testers: Reducing Asset Uncertainties

    Tuesday, February 19, 2019, 6:00 PM - 10:00 PM SG
    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.

    Contact Information

    Singapore, Singapore

  • The Seapex Exploration Conference 2019

    Wednesday, April 3 - Friday, April 5, 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
    Singapore, Singapore

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

    Tuesday, April 16, 2019, 6:00 PM - 10:00 PM MY
    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.

    Contact Information

    singapore, Singapore