Singapore Section

  • Improving Reservoir Simulation Modeling with Seismic Attributes

    May 24, 6:30 PM - 11:59 PM (SGT)
    Abstract – Distiguished Lecture: Seismic attributes are being used more and more often in the reservoir characterization and interpretation processes. The new software and computer’s development allows today to generate a large number of surface and volume attributes. They proved to be very useful for the facies and reservoir properties distribution in the geological models, helping to improve their quality in the areas between the wells and areas without wells . The seismic attributes can help to better understand the stratigraphic and structural features, the sedimentation processes, lithology variations, etc. By improving the static geological models, the dynamic models are also improved, helping to better understand the reservoirs’ behavior during exploitation. As a result, the estimation of the recoverable hydrocarbon volumes becomes more reliable and the development strategies will become more successful. Biography – Dr. Isabela Falk: Isabela Falk is a Senior Geologist, currently the Subsurface Team Leader in a Schlumberger P&AM project in Romania. Previously she worked as a Project Geoscientist for Fugro-Jason in Germany and Holland. Prior to that, she worked as a Researcher Geologist in the Romanian National Gas Company: Romgaz. Isabela holds a PhD in Geology from the University Babes-Bolyai from Cluj-Napoca, Romania, since 2008. She has 20 years of experience in the Oil & Gas industry, specialized mostly in geological modeling, but is experienced also in seismic inversion. She made several scientific presentations in internal and international conferences and is a member of SPE, SEG and EAGE. Dinner and two drinks are provided.
    Singapore, Singapore

  • Designing Fit-for-Purpose Facilities in the Current Environment

    Jul 13, 6:00 PM - 9:00 PM (SGT)
    Joint presentations about facilities design that were given at the recent APE ATW in KL in April. Rolando’s talk is based on actual industry data and performance, and is quite thought provoking regarding why the industry wastes so much capex in its designs. Peter Kirkham   show a case study with  the evolution of Twinza’s Pasca A development over the past couple of years and the “appropriate scoping” into the concept.  Taking Charge in a Low Oil Price Environment Rolando Gachter, Independent Project Analysis Pte Ltd Abstract: High oil prices in the past have bailed out many marginal developments. Waiting for price drops  in  the supply chain to improve today’s opportunities is a passive approach to business success. To survive in a low-price environment requires: (1) a thoughtful and rigorous portfolio management approach; (2) making efficient scope selections; and (3) being smart about development strategies and project practices With this presentation we describe successful lean scoping approaches and sound development  strategies that have improved CAPEX efficiency by over 40 percent. Objectives and scope of  the proposed topic: • To examine why our project scopes have become so inefficient over the last 20 years by  measuring : • How much project scope has grown and explain why it has done so • How inefficient project scopes affected performance • Identify what needs to change in the scope development process and provide a framework  to deliver more competitive project scopes Methodology procedures and process of the topic: • 387 offshore oil projects (recent) for which we have full detailed cost, schedule, production,  and scope details were examined • Root causes of performance were established from detailed review of the project case  histories • Causes (and effects) of scope inefficiency are calculated Observations and conclusions of the proposed topic: • Weight increases over time for almost identical pieces of scope can be demonstrated. There  are three main drivers of inefficient scope decisions: • Systematic subsurface over-confidence • "Intense" reservoir depletion strategies • Increase risk aversion Recommendations to address these root causes are presented. Biography: Mr. Gächter has over seventeen years of capital project benchmarking experience, specializing in energy and minerals extraction projects. His experience includes large-scale project system benchmarkings for major oil and natural gas producers. His experience also extends to reviews of over 100 major capital projects worldwide in the petroleum exploration and production and mining sectors covering over $5 billion in capital expenditures. Mr. Gächter has managed the accounts of a diverse group of clients both big and small. These include a supermajor , a large national oil company, as well as smaller independent operators. He currently serves as a senior instructor of the IPA Institute which provides education to project professionals globally. Over the years Mr. Gächter has presented at various industry conferences and seminars including the United States, Europe, Africa, and the Middle East. Establishing Appropriate Development Concept and Cost – Pasca A Case Study Peter Kirkham, Twinza Oil Abstract: The days of $100+ oil are behind us (for now), but their legacy continues to live on in the development concepts and engineering practices that the environment spawned. In the rush to develop in the decade from 2003 to late 2014, oil and gas project costs spiraled out of control. There are many reasons for these increases such as cost escalation, poor project practices resulting from an overstretched industry, increasingly stringent engineering specifications, and perhaps most simply: high demand for limited contractor services. When considering the capital costs to use for exploration economics, it is common to use benchmarks, or perhaps a high-level factored cost estimate based on industry norms, unit rates and similar concepts used previously. But how relevant are these benchmarks today? If we just take conventional approaches to field development and base our capital cost estimates on historical data (thinking that it’s all we have, so we have to use it), then we consign ourselves to a conservative mindset. Exploration requires creative thinking, and without it no-one would ever imagine a new play system or dare to drill an exploration well. The economics to support such endeavours require a similar mindset. The Pasca A development offshore PNG started concept engineering in October 2014, just as the oil price began to fall. Unlike many other developments, the project was not shelved, and continues towards development. One of the reasons for this is the “fit-for-purpose” development philosophy that was adopted. Approaches taken during the Pasca A project are used to illustrate aspects of project development that others might adopt in a low price environment. • Clear objectives: Know where you are heading and the development priorities. • Integra ted team: Working together to deliver an optimised concept requires multi-discipline  knowledge and communication – particularly for those running the economics at the heart of  the project. • Keep scope under control: Don’t over-design; identify and quantify the trade-offs that result  from cutting scope. • Appropriate design requirements: Using off-the-shelf design and designing to industry  standards rather than bespoke solutions saves cost. • Collaborate with contractors: easy to say, harder to do, but keeping an open mind to  alternative concepts and embracing solutions that meet the functional requirements. • Understand the economic drivers: increasing NPV is not necessarily the best outcome. Biography: Peter is a petroleum engineer with 17 years industry experience across multiple engineering, technical and commercial disciplines. He is a member of the Society of Petroleum Engineers and currently serves on the committee for the Singapore Section. He started his career at Novus Petroleum as the Commercial Assistant to CEO and helped manage all aspects of a portfolio that included exploration, development and production operations for assets in Australia, Indonesia, Egypt, Pakistan, Oman and the United States. He was subsequently involved in the founding of Lodore Resources in 2004, a London-listed oil and gas explorer which drilled three exploration wells in the United States, two of which discovered gas. Peter was a Senior Project Analyst at Independent Project Analysis where he was involved in the evaluation of more than 65 oil and gas project developments ranging in size from 10s of millions to 10s of billions US dollars , and encompassing a wide variety of development concepts and countries. Today Peter is the Project Engineering Commercialisation Manager at Twinza Oil, based in Singapore. In this role , Peter oversees Twinza’s Pasca A project development in offshore PNG, and has been involved in most aspects of the project since early FEL 2.  
    Singapore, Singapore

  • Upscaling Formation Damage Laboratory Test Data to Full Well Perspective

    Aug 3, 6:00 PM - 9:00 PM (SGT)
    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.
    Singapore, Singapore

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

    Oct 23, 11:30 AM - 1:00 PM (SGT)
    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.  
    Singapore, Singapore

  • Vote for DLS

    Jan 25, 6:00 PM - 11:00 PM (SGT)
    Each year, SPE selects a group of professionals, nominated by their peers, to share their knowledge and expertise with SPE members through visits to local sections. If you enjoyed the presentations last year, you can find the slides at this address: You received an emailer with the bios and the abstracts for the distinguished Lectures for 2018. You can vote on this link. Please create a new column with your name as title, and vote for 10 topics from the most interesting (10), to the least (1).
    Singapore, Singapore

  • SPE Singapore, AIPN-YN Asia Chapter, SEAPEX and Energy Institute Networking Event

    Feb 8, 6:00 PM - 10:30 PM (SGT)
    Description Following the success of the November gathering, the Oil and Gas and Energy networks in Singapore have decided to continue in their collaboration aiming at providing networking opportunities for Young Negotiators, Young Professionals and students. Wood Mackenzie will be providing the talk in the February gathering, “What to look for in 2018”, reporting both from a global and regional upstream/energy perspective. Abstract: 2017 was the year the upstream industry began to feel a bit better about itself. So as we head into 2018 with prices bouncing above US$60/bbl, are there grounds for renewed optimism?  Wood Mackenzie thinks so. Investment is stabilising and new project sanctions are on the up, a key barometer for confidence in the sector. Tight oil will also enter its second great phase of growth – with implications for global oil markets. And 2018 is shaping up to be a massive year for portfolio renewal, with over 15 billion boe of discovered resource opportunities (DROs) up for grabs in Brazil and the Middle East.  Closer to home, will Asia Pacific join the recovery? Or do the fundamental barriers to investment in the region remain? Join us as we highlight our top global and regional upstream themes to look for in 2018. Bio: Andrew leads the Asia Pacific Upstream Oil & Gas research division, managing the analyst teams in Beijing, Delhi, Perth and Singapore.   Andrew joined Wood Mackenzie in 2005 as an analyst in the Europe Upstream team and moved to Singapore in 2010 where he has focused on upstream activity in South-Eastern Asia, primarily in Indonesia, Malaysia and Thailand. During his time with Wood Mackenzie, Andrew has worked on a number of consultancy projects, including fiscal benchmarking, corporate strategy analysis, growth opportunity screening, portfolio valuation and infrastructure studies. He has also spoken at a number of conferences around the region. Registration includes a buffet and one complimentary drink. Registration fees are as follows:   SPE, AIPN, SEAPEX and Energy Institute members ( please sign in using the "Sponsorship Package B"): S$25   Students and young professionals (sign in in the "Sponsorship Package A"): S$20   Young Professionals and AIPN Young Negotiators are those who are 40 years or younger or those with less than 5 years’ experience. All young professionals, regardless of membership type, should register under this category.   Non-members: S$35 (use "Sponsorship Package C" while registering)   All members and non-members should register online at the link as soon as possible as spaces are limited.  As this event is co-hosted by SPE Singapore, AIPN-YN Asia Chapter, SEAPEX and Energy Institute, SPE Singapore will disclose your contact information collected during the registration process to the co-hosts of the event - AIPN, SEAPEX, and Energy Institute, and will be used for the purposes of informing you of future events organized by each of these organizations. If you do not wish for your information to be used for such purposes, please contact Paulina Svoboda at .
    Singapore, Singapore

  • NUS PhDs, two talks on gas

    Mar 6, 6:00 PM - 9:00 PM (SGT)
    The NUS Center for Offshore Research and Engineering is leading the research in Petroleum Engineering areas in Singapore. Two of their brilliant students will present their research  - Gas Hydrates - Shale Gas Abstract Natural occurring methane hydrate (MH) is found abundantly in sediments and rocks under stable thermodynamic conditions. The majority of this resource is located under the permafrost layer and in the shallow depths of the seafloor in the deepwater regions. Over the past two decades, a variety of efforts were dedicated in laboratory researches and field production tests using different methods to examine the best production strategy that is economically viable for commercialization. In order to produce gas, the solid methane hydrate in pores of sediment or rock will need to be dissociated either by reducing the pore pressure, increasing the temperature, injection of inhibitors, or undergo gas exchange using carbon dioxide. It is possible to have a combination of these options in the gas production. Currently, the depressurization method is deemed the most efficient way to produce gas. This talk will first, briefly, share about the National University of Singapore (NUS) petroleum engineering program. ( , ). Then, the speaker of gas hydrates topic will proceed to share some of the general background of gas hydrates, and more specifically the research areas/efforts in the NUS ( ). Some previous technical gas production works, and insight on the current on-going approach (frackability of gas hydrate in sand) will be briefly described. Biography Jun Lin Too is currently a research fellow at the National University of Singapore (NUS). He has recently completed his PhD from NUS, and continues to work on the gas production efforts, extending from his research. He has presented his work on the gas hydrates recovery efforts in conferences, such as SPE URCE in Brisbane, Australia (2015), and in the 9th International Gas Hydrates Conference (ICGH9) in Denver, USA (2017). Previously, he holds a B.Eng. from NUS, and worked in a technical consulting company in the subsea and pipeline area for two years.  
    Singapore, Singapore