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PGCE 2004
- Conference date: 15 Dec 2004 - 16 Dec 2004
- Location: Kuala Lumpur, Malaysia
- Published: 15 December 2004
21 - 37 of 37 results
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Exploration : Catching the Next Wave
By W. HoogeveenThe oil and gas industry, and in particular, exploration, is challenged to continuously deliver new volumes in a world where heartlands are getting tired and the big finds are becoming increasingly difficult to make. The industry’s exploration efficiency is driving us towards smaller and, in many cases, more remote, accumulations. But there are still ample resources yet to be discovered. Knowing where the hydrocarbons are, however, is not enough. If we apply the filters of “Accessibility” and “Profitability” we are left with what we call the “new battlegrounds” for exploration. These are the backdrops against which the oil and gas industry will have to operate to fuel the energy demand. In Shell, we have taken stock of where we are and where we want to be to rise to the challenge. Shell’s strategic thrust is to have more upstream and profitable downstream. The bulk of our investment will be in upstream exploration, production and gas supply business. Our exploration strategy has evolved from a focus on asset-driven near field exploration and a very large global spread, to shifting our focus to more material exploration opportunities, in fewer countries and in choice basins. With increased focus on material opportunities, emerging plays, and fostering core knowledge and skills, we believe we
are poised to catch the next wave of success through partnership with others. The “new battleground” pushes us to go deeper, be faster and cheaper. As a global leader in Deepwater exploration and development, we have the people, we have the technological edge and we also have the commitment backed by our track record and successes.
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The Allocation of Exploration Dollars in a High Oil Price Environment
By P. EbdaleThe high oil prices of the late 70’s resulted in exploration investment trends in the 80’s that destroyed value for the industry. The oil price is rising again and many are suggesting that the industry may be operating in an environment where oil is priced in excess of $ 30 a barrel for a significant period of time. Will we learn from the mistakes of the past? The complex question of the allocation of exploration dollars across an international portfolio involves the convolution of many factors; economics, company strategy and the ability to secure quality acreage, to name but a few. By simplifying the question to two geographic/geologic provinces, namely the deepwater Gulf of Mexico and South East Asia, an analysis of the key decision criteria can be conducted, these can then be compared and contrasted while referencing against a prognosed high oil price. Does the exploration investment climate favour the United States over SE Asia? If so why, and will history repeat itself?
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Remote Detection of Hydrocarbon Microseepage: An Alternative Exploration Tool For Onshore Exploration
By M.R.Ch. KobMicroseepage is a common phenomenon (Saunders et al., 1999) and more than 85 % of known oil and gas fields show some degree of hydrocarbon microsepage (Richer, 1982). This microseepage is associated with hydrocarbon accumulation below the surfaces, causing detectable anomalies on the surface. And these surface manifestations of hydrocarbon accumulations has long been studied and documented through surface analyses such as geochemical, Geophysical, geomorphological studies and etc.
The association of hydrocarbon induced surface anomalies with the tonal anomalies as seen on the satellite images has been studied quantitatively and documented. It has also been used to explain the distribution of the hydrocarbon microseepage in the producing basins, such as Tucano basin in Brazil. Successful prospecting using surface studies and remote sensing has increased globally. It has been documented in the USA, Libya, Caspian Sea region, Brazil and China with high success ratio compared to when only conventional methods are applied. The prospecting method using surface studies and remote sensing are comparatively cheaper and faster than the conventional seismic method. It also enables a wider search area and more cost-effective. It also supplements the conventional methods by providing surface “DHI’ s”, which can remarkably reduce uncertainties and risk, and subsequently increase the success rate in exploration. The current advances in remote sensing imaging and digital image processing provide plenty and vital information on hydrocarbon below the surface, if it is properly calibrated and applied.
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Gas Hydrates in Seabed Sediments, Offshore Trinidad/Barbados
Authors B.B. Bernard, J.M. Brooks and N. Summer and S. FlanaganMany of the discoveries and studies of gas hydrates in shallow seafloor sediments in the Gulf of Mexico and West Africa have resulted from Surface Geochemical Exploration (SGE) coring studies conducted by the authors. In the present study, we provide new information on the distribution, occurrence, and chemical nature of gas hydrates offshore Trinidad and Barbados.
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Coal Depositional Settings of Mukah-Balingian, Sarawak: Implications for Coaly Petroleum Source Rocks of the Balingian Province
Authors Ch.S. Ni and W.H. AbdullahThe coals and coaly sediments analysed in this study are from the Neogene (Miocene-Pliocene~ coal-bearing sequences of the Begrih-Liang and Balingian formations which outcrop within the onshore part of the Balingian Province. Most of the samples analysed are from the Sulau Coal Quarry and outcrops along the Mukah-Selangau Road. Using a combination of lithofacies studies, organic petrological analyses, and organic geochemical characteristics of these coal-bearing sediments, the environment of deposition for both the Balingian Formation and the Begrih-Liang Formation appears to have been within fluvial-deltaic. However, there seems to have been greater marine influence in the Begrih-Liang Formation compared to the Balingian Formation. Although most of the coals studied are of an autochthonous origin (formed beneath the plant cover from which they were derived), some are hypautochthonous deposits (originated from material that was transported from its immediate source but accumulated within the same sedimentary environment). The autochthonous coal deposits are relatively thicker and commonly associated with rootlets within the underlying clay while the hypautochthonous coal deposits are relatively thin and associated with significant amounts of clay minerals.
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Chasing Subtle Plays in a Mature Carbonate Province
Authors P. Lambregts, G. Jaeger and D. Sim and S. GuestThe Central Luconia Province is a stable Late Tertiary platform, flanked by two area’s of active deltaic sedimentation, located offshore Sarawak. It is characterised by widespread carbonate deposition, which started in the Early Miocene, and during Middle to Late Miocene high-relief carbonate build-ups developed with some reaching a thickness of more than 1500m. This carbonate depositional phase ended with a series of regressive events, and the build-ups became subsequently covered by marine shales derived from prograding deltas. These high relief carbonates formed the historic exploration objective since the mid- 1960’s, with some 40 Tscf reserves discovered to date. This play, which was evaluated on 2D data, is well understood and very mature. The success rate of this play has been decreasing, culminating in a 5 well drilling campaign in 2000, without a commercial success. The play appeared creamed with limited volume potential left. The advent of larger production-oriented 3D surveys provided new insights into the early phases of carbonate growth and allowed the identification of subtle traps adjacent to the prolific discoveries. Making use of constrained sparse spike inversion a porosity sweetspot, encased in a potential low permeable facies, was identified near the large Eli Field. This was subsequently drilled as a secondary objective of a deeper test. The result of this well proved that a sealing tight carbonate facies is present as the GWC extends 250 ft below the structural closure, making this discovery a true stratigraphic trap. This discovery has resulted in a different way of looking at carbonates, moving away from high relief 2D structural evaluation towards subtle, 3D based, facies mapping. Several other low relief build-ups have been identified since on 2D and
late 2003 the first exploration 3D has been acquired to mature this play further.
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Applying GIS Tools to Focus Exploration in NW Borneo — A Timely Catalyst for Consolidation
Authors A. Chan, N. Wong and P. Kelly and R. KnightFor decades, NW Borneo has, and continues to prove a high value hydrocarbon province to Shell. Although there has been a shift in focus in recent time, away from the conventional shelfal plays towards the highly successful deepwater acreage, the volume and hence the challenge remains for exploration to maximise any remaining potential in the Inboard area. Under this remit, regional geology is critically underpinning Shell’s evaluations in this area, and ArcGIS proving an excellent platform for the compilation, manipulation, and analysis of data, derived from a wealth of sources: the power of GIS is that it allows the quick assimilation of information, from a diversity of projection systems, into one unified view. Although utilised for many years by non-Petroleum companies, the value-adding potential of GIS has only recently been recognised by the Oil Industry, with Shell one of the forerunners in it’s subsurface application. The eloquence of this tool is in allowing the individual to control the type and style of data to be imported and rationalised: data configuration tends to be rapid, with the search facilities ideal for creaming-off and spatially visualising any single element from complex and often huge databases. Seismic, well, geophysical, geological, geochemical, play, engineering, production, commercial, or portfolio data can be compiled, decimated, screened and efficiently re-assembled in a seemingly limitless number of permutations by the user. Your own creativity is the limitation. Links to Openworks and a spectrum of in-house corporate databases is allowing a wealth of information, traditionally remote to the GIS environment (e.g. interpreted horizons) and often the user (!), to be quickly incorporated in any evolving project work. One of the key benefits of ArcGIS to SSB Exploration has been the rejuvenation and compilation of strategic play maps, by allowing rapid data screening, and providing amongst others a medium for corporate memory capture and simple documentcopy management. A diversity of data including structural maps, play success rates, gross depositional facies belts, charge domains, rock property data, and hydrocarbon quality information is being assimilated, allowing pan-shelfal prospect maturation activities to be placed in a more coherent framework.
Simply, ArcGIS is an incredibly fast, nimble and thought-provoking tool, which should form an integral part of any Exploration (& Production) outfit, when tackling the uncertainties of the subsurface.
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Phu Khanh Basin, a Frontier Deepwater Basin in Vietnam
By P. ChungkhaThe Phu Khanh Basin is a north to south elongated, approximately 300km long and 100km wide, extensional basin. It lies in approximately 20-2,500m of water in the Vietnam continental shelf area, which comprises a series of Cenozoic sedimentary basins, located within a transitional zone from the continental crust of the Indochina Craton to the oceanic crust of the South China Sea. The Phu Khanh Basin is bounded to the north by the north-east to south-west trending Da Nang Shear Zone, on the east by the steep continental slope of the South China Sea, on the west by the Da Nang Shelf and is separated from the Cuu Long Basin to the south by the north-west to south-east trending Tuy Hoa Shear Zone.
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PETRONAS Visualisation Centre (PViC)
Authors F.S. Jamean and Z.M. NorLocated on the 22nd Floor, Tower 2, PETRONAS Twin Towers, PETRONAS Visualisation Centre is a state-of-the-art advanced visualisation facility aimed for use by PETRONAS, PSC Partners and partner suppliers. The centre is equipped with sophisticated infrastructure and multi vendor visualisation software to facilitate collaboration sessions for prospect selection and viewing well location picking, well planning sessions and facilties design reviews, among others. Built in a record period of four months, the centre was officiated by PETRONAS President and CEO, YBhg Tan Sri Dato Sri Hassan Marican on 18 August,2004 with the audiences of internal guests and key personnel from PS contractors in Malaysia. Being the first of its kind in PETRONAS, the centre was built to provide PETRONAS and E&P companies in Malaysia with access to a highly visual, three-dimensional environment which will allow technical personnel to collaborate and create additional values from their activities in exploration, development and production of hydrocarbon resources. The centre is powered by SGI Onyx35O Computing System with two 1R4 graphics pipe for high quality visualisation. Three 6000 lumens rear projected projectors with curved screen provides brighter image and quieter working environment. The centre is also equipped with active and passive stereo setup which gives immersive effect. PViC is a multi software and multi vendor centre which allows E&P people from various fields to gain advantage from utilising the centre.
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Geothermal Resources Potential in Apas Kin, Sabah
By K.B. HassanThe geothermal investigations of the Tawau-Semporna area, in the state of Sabah, have been discussed by many workers, who include Lim (1988); Sanudin et al., (1990); Lim et al., (1991); Tjia et al., (1992); Liau (2001); Takashima et al (2001); Ang
(2002); Lim and Takahashi (2003), Takashima et al (2003), Kamaludin (2004), Javino et al (2004) and others. The earlier works, mainly done during the 80’s, had investigated on the surface water chemistry, aerial photo interpretation and limited petrographical, structural analysis and geophysical surveys. Starting after 2000, interests on the prospects of geothermal resources of the Tawau-Semporna area were revived. Follow-up investigations, even though piecemeal, have accumulated encouraging data. The TL dates, determined by Takashima et al (2001, 2002, 2003), have added to alternative interpretations on the age sequence of the rock formations in the area. The isotope and geochemical water sampling carried out in 2003-2004 have shed further lights on the thermal water properties of the area (Javino et al, 2004). The Apas Kin area shows the best resources potential among the Tawau-Semporna geothermal manifestations. The chemical geothennometers of Na-K-Mg show reservoir temperatures ranging 180-210°C. Meanwhile the isotopic geothermometers ~O (S04-H20) estimated the reservoir temperatures ranging 152-196°C. The geothermal potential of the Apas Kin area is recommended best harnessed for electricity generation. Even though geothermal power generation is a new ‘thing’ for Malaysia, it has in fact benefited many countries over the world since the 70’s. It has the advantages in that it’s a clean fuel (what is emitted is just steam-or plain water), thus very environmentally friendly, reliable power generation, cheaper electricity production costs in the long run, require less land area for geothermal power plant and many others. Conforming to Malaysia’s policy on renewable energy and the promoting for a more environmental healthy power source, it is thus recommended that the Apas Kin geothermal resources be tapped and harnessed accordingly.
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Rock & Fluid Acoustic Models Inboard Sabah in Support of Seismic Amplitude Calibration Studies
Authors R. Ngu, S. Dolan, T. Johnson and Ch.-H. Hoo and F. HoCalibration of seismic amplitude response requires accurate models of the acoustic properties of sands, their bounding shales, and pore fluids at varying conditions of pressure, temperature and depth of burial. Such models are constructed from careful, rigorous and integrated analysis of geological, petrophysical (LWD/wire-line & core data) and seismic data. Progress in describing and modeling the acoustic properties of sandstone reservoirs, their bounding shales and pore fluids in Inboard Sabah area will be summarized in this poster. The fundamental workflows of building rock and fluid model that has been developed are: Edit and QC well logs against the core data. Perform basic petrophysical evaluation (Fig 1). • Establish fluid property model via laboratory measurements (PVTsim), and mineral property model via petrology studies (XRD analysis). • With the fluid property model, correct the bulk density log for invasion. With fluid and mineral property models, perform Gassmann Substitution for hydrocarbon-saturated intervals to 100% brine. Perform event-extraction on log properties and derive rock property model (Fig 2 & 3). Perform seismic amplitude calibration studies. The plan is to constrain each field in the Inboard Sabah area by a set of high-quality rock and fluid property relationships, which are used for pre-drill prediction of reservoir quality in neighbouring exploration prospects.
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Inversion of a 3D Seismic Dataset Offshore Sarawak: F23 Case Study
Authors J. Majain and A. NadadaserThe F23 field lies in Sarawak waters within Block SK-308, some 150 km offshore Sarawak. F23 is an isolated, platformtype Miocene (Tortonian-Messinian) carbonate build-up. The original depositional texture controls to a large extent the pore types and therefore the porosity/permeability character of the various lithofacies in F23. The large variability seen in porosity! permeability character within a specific lithofacies is related to textural variations associated with depositional cyclicity. The distribution of the porosity/permeability within the carbonate build-up will affect the development strategy of F23. A seismic inversion project was therefore carried out on the F23 field with the following objectives: - To generate an acoustic impedance dataset suitable for stratigraphic interpretation which was used to fine-tune the structural interpretation of the build-up - To generate a porosity volume for analysis for the porosity! permeability trend to assist in the design of the future development wells The Jason CSSI inversion was carried out attempting to meet the above-mentioned objectives. The data used were a full stack seismic volume, well logs from ten wells, five seismic horizons and a seismic velocity volume The essential processes in the project consist of seismic-to-well ties, wavelet estimation, construction of earthmodel and finally the generation of the acoustic impedance data. Based on the cross-plot of the inverted P-impedance and well porosities, a regression curve was derived for the conversion of the inverted P-impedance volume to the porosity volume. The refined structural interpretation based on the inverted P-impedance seismic and the porosity volumes were subsequently exported to Petrel for the building of structural framework and for the property modelling for the F23 static model. The current poster will show the seismic inversion workflow and the results of the F23 seismic inversion project.
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Acoustic Impedence Inversion and AVO Analysis of Pre-SDM versus Pre-STM Data
Authors A. Duen-Woei and Ch.E. Harris and L.H. KuangBoth Guntong and Irong Barat fields are located off the East Coast of Peninsular Malaysia in the southeastern part of the Malay Basin. EMEPMI acquired the most recent 3-D seismic over the hong Barat and Guntong field in 1998. These data were processed through Pre-Stacked Time Migration (Pre-STM) and subsequently re-processed through Pre-Stacked Depth Migration (Pre-SDM), in 2001 and 2002 respectively, in order to address remaining imaging issues assocaited with faults and continuity below shallow gas. EMEPMI Geophysical Application group analyzed the Ore Stack Depth Migrated (Pre-SDM) data over these two fields to determine whether these datasets were suitable for reservoir characterization. The results were compared to the equivalent analysis using Pre-Stack-Time-Migrated (Pre-STM) data. Pre-Stack AVO and Post-Stack amplitude analysis was performed over the Irong Barat C (TB-C) development area to confirm the robustness of the Pre-SDM amplitude observations for the H20 reservoir. Acoustic impedance inversion was performed over the Guntong field for both the Pre-SDM and Pre-STM datasets. The results from both field studies indicate that the Pre-STM and Pre-SDM data are in general agreement. However, the Pre-SDM data seems to have a more consistent and geologically meaningful amplitude response than that of the Pre-STM data. The result of AVO analysis over Irong Barat was subsequently used in the DHI risking analysis and as partial justifiaction for full funding of the TB-C development. The Pre-SDM acoustic impedance (Al) inversion volume over Guntong is currently being interpreted.
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4D Feasibility Study in Carbonate Field for Reservoir Management
Authors Ch. Odukwe, K.Y. Cheong, H. Zhu and J. Ngu and M. LawsonThe use of the 4D seismic method for reservoir management has been well known in the Oil Industry for a number of years. The method provides a geophysical measurement of fluid and rock property changes during the lifecycle of a producing field and allows cost effective and timely reservoir management decisions. Most of the success stories from 4D work in the past have been in clastic reservoirs where the seismic response to production is greater than in carbonates. A 4D seismic study on a carbonate field in the region has shown to be successful in imaging a GWC rise and this has led to increased confidence in the use of 4D for other carbonate fields. M4 is a newly developed carbonate gas field with oil rim that came on stream in 2002. The field is a reefal fiat top
carbonate built-up. It is developed with two sub-sea horizontal wells located at the top of the structural high. There is no other observation well for reservoir dynamic behavior monitoring. It is therefore critical to know the GWC movement in establishing the security of supply from this reservoir and to put in place mitigating measure as earlier as possible. A 4D seismic survey is planned for the field in 2005/2006. This feasibility study was carried out to provide support for the planned 4D seismic survey with the objective of 1) Assessing whether a 4D signal could be detected and 2) Predicting the best time for the Monitor survey. The workflow and findings of the 4D feasibility study will be outlined in the Poster.
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Angsi Field —World’s Largest Platform Based Fracturing Operations
Authors M.A. Ismail and H.M. NoorThe Angsi field is the largest integrated oil and gas development in the region and the first tight gas development in Malaysia. Itis located 165km off the East Coast of Peninsular Malaysia in a water depth of 70m. Angsi Project is a joint venture between PETRONAS Carigali Sdn Bhd ( PCSB ) and ExxonMobil Exploration and Production Malaysia Inc. EMEPMI), operated by PCSB. A dedicated project management team consists of technical personnel from PCSB and EMEPMI was formed to oversee the timely and prudent development of the field.
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Awakening Barton: Multiple Scenario Modelling
Authors K. Hedeir and F. Kandau and A. WidjiastonoThe Barton Field is one of the mature oil fields in SM-EP located offshore Sabah, approximately 220-km northeast of Labuan Island with a water depth of 130 ft. The 3 main reservoirs (G, H, and I) are developed from two mini platforms and a total of 13 producing wells. Barton has been producing with gas lift under natural depletion since April 1982 (20 years of production) with a drive mechanism governed by good gravity segregation and moderate aquifer support. The reservoir pressure from this primary depletion development has decreased from 1058 psi to 550 psi. The reservoir characteristics of the field, and its current condition as a mature, relatively low-pressure field, make it a suitable candidate for a secondary recoveiy project through pressure maintenance, provided the subsurface complexities are well understood. Subsequently, an integrated modeling exercise, through building of multiple geologic realisations, was launched to assess which of the pressure maintenance options, such as gas injection, hybrid gas and water injection and water injection, would give the best results in terms of recoverable reserves and associated economics. An opportunity framing exercise has identified two groups of uncertainties in the form of structural (structural interpretations
and quantifications, fault identifications and sealing capacity) and resevoir geological (facies identifications, correlations, sandbody geometry and orientation) uncertainties. These key uncertainties are mapped and captured systematically in a series of 3D realisations and modeling workflow. Integration of the latest results from cores, biostratigraphy, seismic, juxtaposition plot, bubble-plot, and pressure data as well as analogues formed a sound technical basis for the current modeling. Five out of a total of twenty-two realisations were successfully history-matched. The results thus used for the basis for evaluating developments options, of which water injection is identified to be the most optimal. The first well of Phase 1 of the 2-phase Barton Filtered Minimal Seawater (BTFMS) project will be drilled in Q4 2004. Good and constant communication between team members and geologists in a ‘ring-fenced’ environment as well as the availability of a powerful 3D modelling tool (PETREL) are parts of the enabling factors to the success of the study. This study is an example of how multi-disciplinary integrated approached helps in proper handling of uncertainties, which leads to a robust field development plan.
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Petroleum Systems of the North Malay Basin
Authors M. Madon, P. Abolins, R.A. Hassan, A.M. Yakzan and J.-S. Yang and S.B. ZainalThe North Malay Basin comprises a 100 km-wide centrallbasinal gas-prone area, flanked on both sides and to the south by mixed oillgas zones. Non-associated gas fields in the central zone (Cakerawala to Bujang Trend) are reservoired mainly in groups D and E, in anticlinal traps formed by basin inversion during late Miocene times. This distribution may be biased by the depth of well penetrations in the basin centre due to the onset of overpressure. Oil occurs in faulted traps along the Western Hinge Fault Zone (Kapal to Beranang Trend), and is especially abundant on the NE ramp margin (Bunga Pakma-Raya Trend) where a separate kitchen may be present. Oil geochemistry reveals three main sources for the oils: lower coastal plain, fluvial marine and lacustrmne source rocks. Most of the oils and condensates in the basin centre and on the Western Hinge Fault Zone are lower coastal plain oils, indicating charge from the basin centre. Lacustrine oils are restricted to the Bunga Pakma-Raya Trend on the NE flank,
indicating charge from the basin centre as well as input from a small sub-basin to the northeast. Marine influence was found in oils from the most central position in the basin (Cakerawala-Bumi area). Vitrinite reflectance and basin modelling indicate that hydrocarbons were generated from source rocks within two main stratigraphic intervals: Group H and Group I, which are presently in the peak oil generation and gas generation stages, respectively. Figure 1 shows the distribution of oil and gas fields in relation to present-day groups H and I maturity.
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