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Petroleum Geoscience Conference & Exhibition 2013
- Conference date: 18 Mar 2013 - 19 Mar 2013
- Location: Kuala Lumpur, Malaysia
- Published: 18 March 2013
1 - 20 of 103 results
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Geological Learnings from Lundin’s Five Years of Exploration in Malaysia
By R. JonesLundin Malaysia entered the country in 2008 and since then have acquired 10 3D seismic surveys and drilled ten exploration wells, with a high success rate. The focus areas are in basins generally thought to be marginal, but results show that aggressive and focussed exploration can still yield significant resources. Examples of the geological lessons learned and the prospects tested will be shown.
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Potential Use of 4D Seismic To Optimise EOR in A Mature Field, Offshore Sabah, Malaysia
Authors K. Boey, J.A. Harwijanto, C.W. Hong, C. Dinning and J. NguA repeat seismic survey has been planned in 2013 to support and to optimize the EOR field development of a mature, heavy oil field, offshore Sabah using water and ASP injections. This 4D seismic is to repeat the 1996 3D seismic as the base line. The 4D seismic is aimed to detect contact movements after 12 years of production, to identify un-swept parts of the main reservoir, to verify connectivity’s between compartments, to identify gas break-out and to optimize placements of water and ASP injectors. A few studies addressing the 4D signal detectability and survey repeatability have confirmed the feasibility of the project.
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Near Surface Modeling and Effect on 4D Repeatability In The Presence Of Shallow Gas Anomalies
Authors A. Sazykin, I. Eckhoff, R. Rashli, P. Smith, G. Nyein, M. Akalin, W. Tang, Y. Widjianto, Z. Dom, A. Ghazali and M. MustafaTime Lapsed 4D seismic surveys are now considered to be an invaluable and essential tool in order to capture, image and analyze valid changes in seismic signal induced by reservoir depletion, or by injection of water or CO2 into the reservoir. 4D monitoring has been proven to be very successful for offshore reservoirs (Haugvaldstad). However, in ultra-shallow water situations, the valid time lapse signal may be obscured with unrepeatable seismic noise, attributable to variations in near surface heterogeneity due to shallow channels with partial gas-saturation, acquisition geometries (e.g. undershoots), strong multiple contamination and ambient noise. These residual unrepeated noises represent the change at the reservoir level and will impact on the quality of the time lapse signal. Currently the best strategy to tackle near surface heterogeneity and other repeatable noises (e.g. multiples) is to repeat source and receiver location as accurately as possible during acquisition. Whilst it is desirable to acquire well repeated surveys, it is not always possible due to limits imposed by operational safety, weather, timing and other factors. Therefore, it is important to create a reliable near surface model and compensate residual differences through robust statistical methods.
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Time-Lapse Seismic Data Inversion Constrained by a Fluid-Flow Simulator for Reservoir Monitoring Applications
Authors L. Liang, Neil Hurley, A. Abubakar and T.M. HabashyWe present a fluid-flow constrained inversion approach for joint interpretation of time-lapse seismic data and production data. In this approach, the full-waveform seismic inversion is integrated into the conventional history matching process. Therefore, the interpretation of time-lapse seismic data is constrained by the fluid flow simulation in the reservoir, and it automatically takes into account both saturation and pressure effects. We use a synthetic crosswell example to demonstrate the advantage of this approach.
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The Maharaja-Lela 2010 Exploration Campaign: The Key Opener for an Additional Development
More LessThe Maharaja Lela Jamalulalam field (MLJ), located 50km offshore Brunei, was discovered in 1990 and has been producing oil, gas and condensates since 1999. It is constituted of a series of faulted panels where the hydrocarbons are trapped in two or three way closures against normal faults. The reservoirs are good quality shoreface sands. A new exploration campaign, targeting undrilled down-dip panels, started in 2004 with a new seismic acquisition. Following processing and interpretation, several successful exploration wells were drilled. In 2010, Total drilled the deepest well in Brunei, reaching its TD at nearly 5700m. In spite of the high pressures and temperatures (over 1100 bars 65 degrees Celcius), the proven gas columns are high, while the reservoir properties are preserved by overpressures. This very successful exploration campaign has enabled the Bloc B JV Partnership to identify sufficient resources to start an incremental development project of the MLJ Field and to extend Gas Deliveries to Brunei LNG plant. It also opened up additional exploration opportunities.
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Significant Hydrocarbon Accumulation in Deep Overpressured Play of West Baram Delta: A Breakthrough
Authors Mh Hafizan Wahab, A. Asraff, J. Juhari Ismail and C. Anwwar IbrahimTwo recent HPHT wells have successfully tested the deep seating overpressured playtype in West Baram Delta with significant discoveries of gas and condensate at depths of more than 4500m below mudline. The well recorded the highest reservoir pressure to date in Malaysia, approximately 14,000 psi approaching the operational limit of the Blow Out Preventer (BOP) used. Total of 200m nett gas sand were penetrated with all gas bearing reservoirs are filled with hydrocarbon to the structural spill (with average of 650m of vertical gas column), proudly standing as the longest clastic section ever drilled in the West Baram Delta province. The structure which was filled to spill is primarily, but not exclusively attributed to an excellent lateral seal of a growth fault system. This is further enhanced with the deposition of foreset shales on the hanging wall of the fault.Overpressure condition has also revealed the upside potential of the reservoir characteristics, i.e. significant improvement in the porosity preservation below overpressure zones, resulted to better producibility of the gas bearing reservoir. Understanding the play type behavior remains the critical challenge particularly in evaluating the structuration, trap integrity, and the seal capacity.
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The Awakened Giants
Authors Nur Fadzlinda Mohamad Khazali, S. Osman and C.S. AbdullahFEW PINNACLES WITH SEISMIC EXPRESSIONS PRESUMABLY ENHANCING THE 'BLOWN TRAP'FEATURES ARE PUT FORWARD. SIGNIFICANT CIRCULAR FAULT FRAMEWORKS IN THE OVERLYING OVERBURDEN SEQUENCE COMPLETE WITH A 'SEISMIC PLUME' EMANATING FROM THE PINNACLES CRESTS STRENGTHENED THE FAILED TRAP BELIEF. EARLY ASSESSMENT OF THE PINACLES WITH THE SIMILAR SEISMIC FEATURES LED TO DOWNGRADING OF THEIR HYDROCARBON TRAPPING POTENTIAL. THE UNDERSTANDING TRIGGERED TOTAL PETROLEUM SYSTEM RE-EVALUATION OF THE CARBONATE PINNACLES IN THE REGION. SINCE 2004, MORE THAN 15 PINNACLES WERE TESTED AND PROVING 18 TRILLION CUBIC FEET GIIP IN TOTAL, ACHIEVING AN EXPLORATION SUCCESS RATIO OF HIGHER THAN 80%.
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First Broadband Circular Shooting Survey in Malaysia: Integrating Survey Design and Modeling for Simultaneous Deployment
Authors S.K. Chandola, T. Velayatham, M. Tham, K. Hong Ho, L. Cheng Foo, N. Mahmud, S. Kumar and L. Chung TeckThe quality of the surface seismic imaged data depends on many factors. The images can be very poor if the survey is located in an area characterized by complex overburden and structural setting. In addition, the conventional data acquisition and processing methods may not be adequate to address the challenges posed by the subsurface geology and geophysical complexities. The integrated approach of survey design and modelling, unique acquisition technique, advance data processing workflows can help address these challenges. The case study presented here is one of the first to seamlessly deploy two of the most cutting edge acquisition technologies at the same time: i) circular shooting technique for extending the azimuth sampling and concurrently ii) constant gradient slant cable towing technique, whereby the streamer depths are shallow at the front and deep at the back to exploit the diversity in streamer notches to extend the bandwidth sampling. By doing so, it not only eliminates the need to acquire the survey twice but also enables one to realise the benefits offered by both technologies simultaneously.
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Variable Depth Streamer Acquisition – Benefits for Rock Property Inversion
Authors L. Michel Sdn Bhd, R. Hanumantha Sdn Bhd and F. Baillard Sdn BhdQuantitative interpretation teams face two challenges when using model-based inversion: to extract meaningful wavelets and to build accurate low frequency models. The use of variable depth streamer gives access to lower frequency and enable to use calibrated seismic velocities as an initial model. With constant depth streamer and sparse well-log, the well-derived low frequency model may be inaccurate and cause biased inversion results. Seismic data acquired using variable depth streamers are ideally suited for inversion as they provide directly the missing low frequencies, hence removing the need to build low frequency models from well data. In order to quantify the impact of the low frequency content on seismic inversion, comparative elastic inversion tests have been conducted using 2-D seismic data from Constant Depth Streamer (CDS) and Variable Depth Streamer (VDS) acquisitions using the exact same streamer geometry. Both datasets from offshore NW Australia were acquired simultaneously, with a constant streamer depth of 7m for the conventional acquisition and streamers’ depth ranging from 7.5 to 58 m for the VDS acquisition.
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Autonomous Nodal Marine Seismic Technology
Authors C.D.T. Walker and G.R. ArringtonBy eliminating the traditional sources of technical downtime in Ocean Bottom Cable (OBC) system, autonomous seismic nodes can deliver higher productivity and hence more cost effective ocean bottom data acquisition. HSE exposure and risk is reduced through the removal of a recording platform - either a recorder vessel or 2 ton recording buoys - in combination with the automation of the node handling system on the back deck of the vessel. Data quality is superior to that acquired with digital accelerometers since the noise floor of the omni-directional geophones used is substantially lower, especially at low frequencies, than that of the digital sensors commonly used in present day OBC systems.
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Comprehensive Geological and Geomechanical Fractured Basement Characterization and Modelling; Integrated Multidisciplinary Approach Using New Techniques
Authors R. Dashti, N. Pendkar, M.L. Lee, S. Marca and M. JohanssonIn this work, borehole image and sonic data from a highly deviated borehole were integrated with outcrop studies to characterize natural fractures and develop a 3D fracture network. Then geomechanical analysis was performed to determine the stress regime and magnitude around the wellbore which was then incorporated into the study to define the critically stressed fractures which are most prone to production as well as breakthrough.
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The Petroleum Systems of Onshore West Baram Delta, Northern Sarawak, Malaysia
Authors John Jong, P. Barber, L.H. Chim, Q.T. Tran, H. Kusaka, K. Muramoto and R. UchimuraA sequence stratigraphic investigation of the onshore Baram Delta integrated with modern biostratigraphic analysis suggests that the sedimentary section in SK333 has been affected by three major tectonic episodes of deformation:(i) Late Cretaceous to Eocene (79.5-36Ma) block faulting, (ii) Late Oligocene to Mid Miocene (30-20.5Ma) wrench movement and related folding followed by (iii) Mid Pliocene to Recent (4.0-0Ma) uplift and compressional folding. Subsequently, two optimum play trends have been mapped in SK333. These are the Miri–Asam Paya-Seria (MAS) and Engkabang Anticlinoria trend respectively, which are separated by the Badas Synclinorium, an abundant source kitchen area. To summarise the plays: The MAS Anticlinoria trend is an enhanced oil fairway with prolific oil charge from Late Miocene coals and peats on a confirmed oil migration fairway from the Badas Syncline. Reservoirs are excellent quality Mid Miocene to Early Pliocene shoreface-shelfal sands with deeper turbidite sand upside. The Engkabang Anticlinoria is mainly a deep tight gas play with inferred charge from overmature Eo-Oligocene basinal shales. This play is higher risk than the Miri Trend due to the potentially former depth of burial of the Eocene carbonate reservoir objective to approximately 5-6kms. This is inferred to have led to diagenetic inhibition of porosity.
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Subseismic Scale Fracture Characterization Combining Geomechanics and Tectonic History
Authors M. Lefranc, A. Dubois, J.P. Joonnekindt and L. MaertenThe 3D seismic data in fractured basement reservoirs can sometimes be challenging to interpret and allow identifying only the main faults affecting the naturally fractured reservoirs. Moreover, natural small-scale fractures are known to be capable of significantly altering the flow of hydrocarbons and are below the resolution of the seismic data in this type of environment. In order to palliate seismic data quality in these reservoirs and to obtain 3D properties related to fracture orientation and density at a subseismic scale, a geomechanics-based methodology has been developed. This methodology is based on the geomechanical properties of the rock, 3D fault geometry, and far-field stress associated with each tectonic event. The resulting properties can be combined with well log data and seismic attributes to condition a discrete fracture network model and predict the fracture porosity and permeability in challenging environments, like fractured basement reservoirs in SE Asia. It also provides robust fracture orientation distributions, which improve considerably the quality of the models in exploration fields where limited number of wells exists.
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Exploring a New Characterization, Modeling and Simulation Workflow for Vietnamese Basement Reservoirs
Authors T. Doan, C. Milliotte, S. Matthäi and L. PhuocHydrocarbon reservoirs offshore Vietnam are unique in that they are produced from structurally elevated igneous rocks that form faulted basement blocks on top of which the Cretaceous to Tertiary siliciclastic sediments were deposited to provide the source rocks of the oil. This paper explores how to construct, parameterize and simulate geologically realistic – albeit heuristic – models of basement and surrounding sediments in Vietnamese basement reservoir to gain answers to the following questions: How can we represent these structurally complex reservoirs in simulation models? Which new approaches can help property modeling? What are the typical drainage areas of wells drilled into basement faults? How much fluid do these produce from within the basement versus the surrounding sediments? How does flow rate affect ultimate recovery?
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Developing the Largest Carbonate Oil Field in SE Asia – Banyu Urip, Cepu Block
Authors F.W. Musgrove and M. SunMobil Cepu Ltd and partners in the Cepu KKS, East Java basin plan to start development drilling of the Banyu Urip field in 2012 with a targeted startup in 2014. This is a very important development for Indonesia to maintain the Indonesian national production target as this field will produce 165k BOPD initially. The Banyu Urip field was discovered in 2001 and has been certified by ITB with more than 1 Billion BBL in place making it the largest onshore oil discovery in Indonesia in the last several decades. Banyu Urip is a high relief Oligo-Miocene carbonate isolated platform onshore at approximately 4000 feet TVDSS. 30 producers will be required to meet the initial target (5500 BOPD ave per well). 13 water injectors will be required to meet aquifer pressure maintenance target. This paper will describe the field and development concept. The Banyu Urip Field is an isolated platform that rises almost 3000 feet from the surrounding carbonate platform. The platform is made up of repeated 150 foot thick cycles of shallow water carbonate that has been exposed to fresh water repeatedly and leached to form high quality reservoir rock with average 26% porosity and 100 mD permeability in the interior.
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The Rivers of Luconia: The Effects of Sea-Level Lowstands on the Stratigraphy of a Mixed Carbonate/Clastic Province; Miocene-Present, Offshore Sarawak, NW Borneo
By E. KosaCentral Luconia is a gas-producing carbonate province offshore Sarawak, NW Borneo, with some 250 carbonate build-ups, now mostly covered by clastics. Historically, these clastics have been interpreted as open-marine, pro-delta sediments deposited over drowned carbonates. Sequence-stratigraphic frameworks have been based on subdivision of the stratigraphy into regressive cycles punctuated by flooding surfaces. Recent studies have lead to re-interpretation of these strata as stacked delta lobes separated by sequence boundaries as well as by flooding surfaces, with palaeo-coastlines extending basinward of most contemporaneous build-ups. Carbonate build-ups are interpreted to have been periodically engulfed by clastics and land-locked during sea-level lowstands. Palaeo-rivers would consequently be expected to flow over the exposed shelves during forced regressions, producing erosional geomorphology at sequence boundaries. Shallow-marine, paralic and fluvial sediments would be expected in the uppermost parts of the stacked shelf units, which are indeed characterised by distinct upward-cleaning trends. This study documents evidence for fluvial and other erosional geomorphology and links this to hydrocarbon habitats, carbonate-clastic interactions and reservoir/seal distribution. Fluvial processes are shown to have exerted major control on carbonate inception in the Middle Miocene, as well as on hydrocarbon-retention capacity of the clastic overburden following later carbonate demise and burial.
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Diagenesis of the Central Luconia Carbonates: The Roles of Methane-Derived and High Temperature Fluids in Controlling Reservoir Properties
By M.Y. AliThis paper presents the results of a comprehensive diagenetic study and cementation history of the Central Luconia carbonates based on integration of petrography, SEM/BSEM, XRD, cathodoluminescence, electron microprobe, stable carbon, oxygen and sulfur isotopes, fluid inclusion microthermometry and absolute dating using strontium isotope technique.
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The Lower Miocene Great Barrier Reef of Sarawak, Malaysia: The Exploration Potential of Cycle II and III Carbonates
Authors E.W. Adams, P.F.M. Janssen, S. Ghani, S.J. Gough and P. WinefieldA play-based exploration (PBE) study carried out in Shell assessed the remaining exploration potential of onshore and offshore Sarawak and enabled identification of sweetspots in previously overlooked plays, the definition of an internally consistent new lead portfolio, and the addition of a ranked list of coveted acreage (Gough et al., 2012). Furthermore, using PBE workflows, a framework was established connecting the evolution of tectonic regimes and basin fill with carbonate occurrences and growth styles since the Late Eocene and provided the basis for a play-based assessment of the remaining exploration potential of carbonate plays in Sarawak (Adams et al., 2012). The main carbonate play in Sarawak are the well known and intensively studied Middle Miocene to Pliocene Luconia Province carbonates. However, the above mentioned regional PBE study refocused Lower Miocene carbonates which in eastern Sarawak developed extensively. Both onshore and offshore, these ‘older’ carbonates have been penetrated by several wells including recent high profile discoveries. This paper puts forward the stratigraphic, tectonic, and age context of these Lower Miocene carbonates and examines the variability in carbonate deposition on the Sarawak Shelf. Finally, the remaining exploration potential is discussed by comparing and contrasting northern Central Luconia with south-eastern and onshore Sarawak.
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Determining the Source of Low Level H2S Using Novel Sampling Techniques
Authors D.E. McKinney, H.L. Albrecht and B. OkohAs operators drill deeper into higher pressures and temperatures as well as begin exploiting resource plays such as gas shale and liquid rich shale, the concentrations of gas contaminants such as H2S and CO2 become more and more important, especially in prescribed low cost developments. To understand the source of H2S, sulphur isotope mapping of pyrite, organic sulphur, anhydrite and H2S is crucial. This paper discusses a case study of a discovered field where low level H2S (25-40 ppm) is present in the hydrocarbon accumulation. Proper planning and novel techniques for the sampling of the reservoir fluid, preservation of the H2S and analysis of the Sulphur-34 values for H2S are described along with the business impact of the results.
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Novel Chemical Tracers For Determining Residual Saturation
Authors M. Myers, C. White, L. Stalker, B. Pejcic and A. RossAlkyl monoester tracers (e.g. ethyl acetate) have previously been used in a single well chemical tracer test to determine residual oil saturation. We propose here to use diesters (e.g. propylene glycol diacetate) and triesters (e.g. triacetin) for determining residual oil saturation and residual carbon dioxide saturation. These tracers have a much lower flash point making them much safer and potentially expanding their application. Compared to the monoester tracers, the proposed tracers have similar reactivity, partition coefficients and water solubility. We have recently tested these tracers in the field to determine residual carbon dioxide saturation and obtained tracer breakthrough profiles suitable for analysis using computer simulations.
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