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PGCE 2005
- Conference date: 06 Dec 2005 - 07 Dec 2005
- Location: Kuala Lumpur, Malaysia
- Published: 06 December 2005
21 - 40 of 41 results
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Exploring for High Pressure and High Temperature (HPHT)<br>Hydrocarbon Pools: Technology Challenges Versus Pessimism - Guling Deep-1 Experience
More LessShallow and easy hydrocarbon accumulations are “almost extinct species”. Previously in Malay Basin, not many wells were drilled into and beyond the overpressured formation. The central part of Malay Basin still has untested high pressure and high temperature zones. Deep and overpressured formations will be among the next interesting exploration focus. Current technological developments compliment the drillability of such targets. Persistent general lack of serious commitment hindered the exploratory works. Last year PETRONAS (PMU) tested overpressured reservoirs at Guling Deep-1 location within budgeted time and AFE. The result surpassed pre-drill expectations and proved working petroleum system in the overpressured zones.
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The Prospectivity of Fractured Basement Play of The Malay Basin
More LessSince the 1980s Petronas Carigali Sdn Bhd has actively drilled exploration wells in the Malay Basin with basement rock as one of the secondary objectives. However, most wells were not very successful in testing the hydrocarbon potential in the basement rock. Among some highly debated issues highlighted were the ideal depths of penetration into the basement rock, type of basement play that has been drilled and hydrocarbon charging into the trap. The first discovery of basement play in the basin has undoubtedly proved the hydrocarbon potential in the basin fractured basement play.
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Depth versus Time Imaging of 3D seismic data – Tabu Field
Authors George McKinley and Chris Manuel and Rick WaliaThis paper describes the Kirchhoff Pre-stack Depth Migration processing of marine 3D seismic data acquired over the Tabu prospect, offshore Peninsular Malaysia and compares the results with the Pre-stack Time Migration. The survey covered an area of approximately 230 km2 and was processed through pre-stack time migration and Pre-stack Depth Migration processing flow. There are three target zones that can be identified on a crossline passing through the crest of the anticlinal structure: 1.5 s, 1-1.2 s, and 3.2 s. and the primary objective of the PSDM was to improve the stratigraphic definition of the reservoir obtained from the Kirchhoff pre-stack time migration processing. A new smooth velocity model approach was applied, where the initial model building consisted of a simple Dix conversion of the pre-stack time migration velocities and subsequent smoothing. The resultant velocity model is then perturbed to varying degrees in order to find the percentage of the velocity model which, when applied, will slightly over-correct the CRP gathers. The reason being as slightly overcorrected gathers provide optimum input to the inversion phase. There is a clear trend in the industry to analyze the physical parameters of the subsurface much more densely than previously done. For this kind of dense data, CGG has implemented a new methodology for imaging velocity analysis, based on the RMO inversion method and aimed at: • Improving resolution using the dense automated velocity analysis for model building.
• Reducing overall project turnaround by using automated picking and multi-layer inversion. Compared with the Pre-STM result, the Pre-SDM has resulted in the following: a. sharper fault definition; b. correction for the pushdown due to shallow gas pockets; c. a better understanding of the structure of the deeper events (in some cases a relatively flat structure interpreted at later times on the Pre-STM volume appeared to have a lot more folding associated with it than first thought).
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High resolution Biostratigraphy for enhanced reservoir<br>correlation in the Bergading field
Authors Shamsudin Jirin, Mahani Mohamed, Sanatul Salwa Hassan and Md Wakif SukaharDetailed correlation of reservoir sands is critical to field development and reservoir management. High-resolution biostratigraphy can provide this correlation by supplementing regional biostratigraphic markers with local bioevents, recognised from thin shales within reservoir intervals. This high-resolution data set could reduce risks in the drilling appraisal and development wells. Regional biostratigraphic markers are generally have a resolution of tens of meter or more. Though they permit regional correlation and mapping, they are too broad for correlation at the reservoir scale. Most reservoir objectives occur between these biostratigraphic tops. Therefore, a high resolution technique is necessary. An example of such application is in Tertiary reservoirs of the Bergading Field, Malay Basin where three regional and 59 semi-regional bioevents are used to enhance reservoir correlation. They comprise 43 palynological events i.e. mangrove and palynofacies events, and 16 marine events. These palynological events are believed to be caused primarily by changes in climate and relative sea level, while the marine events are caused by physical and chemical fluctuations in the sea-water mass through time. Palynomorphs, foraminifera and nannofossils imprint these changes onto the accumulating sediments and yield reproducible signals that can be interpreted and correlated across the field. Recognising and documenting these bioevents are the principles behind high resolution biostratigraphy. When integrated with wireline logs and seismic, such signals produce a more refined correlation and subdivision of sediment packages at the reservoir scale.
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Imaging through gas - a case study from the<br>North Sea. Anisotropic depth migration<br>processing of a 4C time-lapse survey
More LessIn late 1994 BP and partners Shell, Total, and Amerada-Hess embarked on what can be described as the industry’s ultimate seismic exercise – the repeated acquisition and processing of 4-component data over the Valhall field, offshore Norway, using a permanent sea-floor receiver installation. The 4D or time-lapse exercise was designed specifically to monitor and manage the Valhall field; a baseline 3D survey and a series of six repeat monitor surveys were acquired and processed at 3-month intervals, in the world’s first “Life of Field” or LoFS seismic program. This case study discusses the processing issues and workflows used to process the baseline and monitor surveys. The primary processing challenge involves imaging the reservoir in depth, in spite of the gas cloud, and required the development of velocity models for both the PP and the converted wave (PS) data. Subsequent 4D processing to compare the baseline survey with the repeated monitor surveys aims to capture true changes in the reservoir.
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3D Facies Modeling of J Reservoirs of Tinggi Field, Offshore Peninsula Malaysia
Authors Mohd Fauzi Abdul Kadir, Stan Rae and Muhd Kamal EmbongThis paper presents workflows and methods were adopted in constructing 3D-stochastic facies model of tide-dominated estuarine and tidal marine reservoirs within Group J of Tinggi field (Fig. 1). The Tinggi field is a mature oil field situated in the southeastern part of the Malay Basin, approximately 280 kms offshore east of Kerteh, Trengganu (Fig. 2). The 3D facies model built was conditioned to well observation, and conceptual facies model (Fig.3). A combination of RMS Facies:Belt and Facies:Composite methods were performed in the modeling (Fig. 4). During the modeling process, great efforts were made to optimise the workflow, and input parameters for each depositional system. This is to ensure that the input data were honoured, and the facies architecture and its characteristics are preserved (Figs. 5 & 6). Geological framework study was conducted in order to generate input for 3D facies modeling. This study, covering seven depositional sequences, was based on well logs, core data and 3D seismic attribute, revealed detailed reservoir facies architecture of tide-dominated estuarine and tidal marine
environments (Fig. 7). Sedimentological reservoir facies include tidal sand bars, tidal sand flats, highand moderate-energy subtidals. Distinctive sedimentological features for each reservoir facies can be observed from well data. Seismic attribute image extracted for the upper reservoirs provide important information about the distribution pattern of the subtidal facies (Fig. 8). Conceptual sedimentological facies model was built by integrating both well and seismic attribute data, as well as modern analogues, and a complete facies interpretation was performed at each well. Depositional model and paleogeographic history were constructed in order to have better understanding on reservoir sand-body geometry and orientation (Fig. 9). Prior to the facies modeling, a 3D structural/stratigraphic model was generated based on depth structure surfaces and fault polygons from two seismic horizons, subsequently was adjusted to well markers during stratigraphic modeling. The 3D model consists of eleven sub grids with 116 layers and about two millions cells (Fig. 10). In conclusion, better-defined facies distribution offered a realistic 3D static model and enhanced the understanding of reservoir properties distribution.
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New Insights on Depositional Styles from the Samarang Field Using Stratal Geometries and 3D Seismic Facies Analysis with a Neural Network Approach
In the Samarang field, log data suggest that the reservoir quality is controlled by an interplay between the tectonics, sediment supply, and available accommodation space. Previous studies referred to a so-called ‘homogeneous’ thick sand package with little variability while the present study unravels significant vertical and lateral heterogeneity. The larger and finer scale progradational units and the amalgamated, massive sands identified from well logs have distinct correlation to seismic stratal geometry and 3D seismic facies as highlighted from this analysis. The stacking pattern of these units is observed at multi-scales and can be related to small- and large-scale cyclicity and variations in the depositional environment.
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Structural lineaments of onshore Sabah and their relationship to the regional geodynamics of Southeast Asia
More LessThe present structural elements of Sabah are the overprint of several phases and episodes of orogenies and geologic events. Several regional tectonic events have converged in this region since early Tertiary producing well developed compressional and extensional structures. The continued regional collision and movement have altered most of the old structures. The pre-existing structures such as regional transcurrent faults provide weakest zones for stress transfer and determined the movement vectors. The study of synthetic aperture radar (SAR) images of onshore Sabah indicated several prominent structural trends. These trends, which have imprinted and reactivated throughout geologic time, are mostly related to the regional geodynamic evolution of SE Asia. The prominent features observed on the onshore Sabah are the structural elements related to the counter-clockwise rotation. The study of the lineaments and their kinematics indicate that most part of the onshore Sabah involved in these rotations. The counter-clockwise rotation of SE Asia occurred since Early Miocene (Hall, 1996) or perhaps
earlier. It is believed to be related to the collision of the northward moving Indo-Australian plate with the Eurasian plate and the Philippine Sea plate. The collision has caused SE Asia region to protrude southeastward and the Philippine Sea plate to rotate in clockwise direction. This rotation caused the area in eastern margin of SE Asia to move in counter-clock wise direction. In general the onshore Sabah can be divided into four structural blocks, Western, Northwest, Central and Eastern blocks (Figure 1). All of these blocks seem to rotate as separate unit in counterclockwise direction. The boundary between these blocks appears as linear features which are mostly
related to the transpression movement. Associated with it is the push-up restraining bends, oblique thrust faults and en echelon drag folds.
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Early generated hydrocarbons: origin and significance for coaly source rocks
More LessPetrographic investigation under normal reflected white light and blue light excitation were performed on a number of coals from the Sarawak basin and from the Batu Arang basin of Peninsula Malaysia. These are oil-prone coals that contain significant amounts of hydrogen-rich liptinitic macerals. The thermal maturity of the samples, based on vitrinite reflectance, ranges from Ro 0.35 to 0.50% and they are therefore thermally immature for significant oil and gas generation. The coal samples from the Sarawak basin, however, show microscopic features of early hydrocarbon generation. These include the presence of exsudatinite, oil droplets, and oil haze all of which occur in close association with the macerals bituminite, suberinite and phlobaphinite. In contrast, no distinctive oil generative features were observed in the Batu Arang coals even though they are of the same maturity as the studied Sarawak basin coals. This is therefore considered to be a consequence of the maceral composition of the Batu Arang coals, specifically the absence or trace occurrence of the macerals bituminite and suberinite.
The early generated hydrocarbons expelled by the oil-prone coals of the Sarawak basin were observed to impregnate the coal fabric and give rise to plastic behaviour in certain macerals1,2. These “oil-like” materials originate mostly from the maceral suberinite. The generated hydrocarbons impregnated the coal fabric as evidenced by the suppressed vitrinite reflectance values. Saturation of pores and surfaces of coal fabric eventually lead to a continuous bitumen network and subsequently fractured the coal fabric as generated materials lead to elevated pore pressure (Figure 1). This is envisaged as an effective means of expulsion of hydrocarbons from coaly source rocks. Coals from wells of offshore Balingian Province show similar oil-generative features as those observed in outcrops of onshore Sarawak. These features, however, are only distinct in early mature to mid mature (0.45-0.75%Ro) coals and are no longer distinct in the latter part of the oil window. It is therefore suggested that early generated materials have a significant role in hydrocarbon generation and expulsion from coaly source rocks.
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The Wave-Influenced Pahang Delta: Geomorphology, Facies and Sedimentation Trends
More LessDeltas are formed primarily by the action of a river (Barrell, 1912; Moore and Asquith, 1971; Bhattacharya and Walker, 1992). Variations in the proportion of wave, tide and river influence are thought to be the primary control on the delta morphology and facies organization (Wright and Coleman, 1973; Galloway, 1975). Recent work of modern deltas have recognized that many deltas exhibit a variety of morphologies and facies formed due the mixing of variable proportion of river-, wave- and tide processes, and longshore drift (Bhattacharya and Walker, 1992; Galloway and Hobday, 1996; Bhattacharya and Giosan, 2003). The mixture of delta types between and within discrete lobes manifests these variations. Deltas may also change from river-, wave- and tide-dominated phases in time, with changes in relative sea level, sedimentation rates and tectonics (Boyd et al., 1989; Bhattacharya and Walker, 1992; Dalrymple 1992). Wave influenced deltas are characterized by facies and morphologic asymmetries between the updrift and the downdrift sides of the delta (Bhattacharya and Giosan, 2003). Plan view of such deltas shows asymmetric distribution of environment and facies; the updrift side comprise of sandy strandplain deposit with the sand being derived from along-strike transport of older lowstand shelf sands, while the downdrift segment is constructed from immature, river derived sediment of both mud and sand. They form barrier islands and back-barrier lagoons and bays (Dominguez et al., 1987; Dominguez, 1996). The Pahang delta on the East coast of Peninsula Malaysia is an excellent example of modern, wave-influenced delta. Abdul Hadi and Mohamad Sakran (2004) describe the morphology and sediment dispersal trends along the Kuala Pahang coast. This paper attempts to analyze and discuss further the morphology, sedimentary processes and facies distribution, and the ongoing sedimentation trends of Pahang delta. This study is based on the analysis of topographic maps and aerial photographs (available for the last 30 years), field investigations and laboratory analysis of sediment samples collected along the Kuala Pahang coast, and analysis of recent satellite images of Kuala Pahang (1988-2000).
The Pahang Delta, the rivermouth of the longest river in Peninsula Malaysia (Pahang River), forms an assymetric deltaic cone at Kuala Pahang, on the east coast of Peninsular Malaysia (Figure 1, 2 & 3). The coastline between Tanjung Gosong-Kuala Pahang-Sungai Miang constitutes the central, most active part of the modern day Pahang delta. The coastline can be geomorphologically separated into : i) a northern, updrift sandy linear beach and strandplain complex, ii) a central river-mouth area at Kuala Pahang, and iii) a southern downdrift, well-vegetated micro-tidal, barrier-lagoon complex. The northern coast forms a broad strand plain consisting of multiple, beach ridges constructed from fine-grained, well-sorted and negatively skewed sand. Analyses of sequential topographic maps and aerial photographs shows that this wave-dominated beach forms an accreting coastline, receiving sand from river-mouths in the north and south, and reworking of shelf sediments. At Kuala Pahang, welldeveloped and extensive mid-channel, river mouth bars are of fine-to-coarse, moderately-sorted sand. The bars are progressively shifted seaward and drifted southward. The river-mouth area forms a transitory depositional basin for sediments from the Pahang River. Downdrift of the rivermouth, mud and sand drifted southward from the rivermouth formed several micro-tidal barrier-spit and lagoons complexes. The tide-influenced coast is an accreting beachfront, with mature barrier beaches and elongated lagoons. The sand here are moderate-to-poorly sorted. Three images of the Pahang coastline were acquired from MACRES; these images are from the year 1988, 1995 and 2000 (Fig. 3). Comparison of these images for the Pahang delta coastline from the year 1988, 1995 and 2000 clearly shows that the accretion and southward transport of sediment, which was also detected from the analysis of sequential topographic maps and aerial photos, is continuing. The most active site of accretion and transport is from the river mouth area at Pulau Syed Hassan, and at Tanjong Agas to Sungai Miang. These sites are clearly marked by the development of southward drifting sand spits. These images indicate that the delta is prograding in the southeastward direction via longshore drift, and in the north by the interaction of wave accretion and longshore transportation of sediments.
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Integration of Seismic Facies Body Extractions in 3D Reservoir Models
More LessThe interpretation and extraction of facies bodies from seismic attributes has become a key tool for optimal targeting of exploration, appraisal and production wells. During the past decade a large number of fields throughout the world have been discovered and successfully appraised using information on facies and reservoir distribution extracted directly from a variety of seismic attributes. As these fields enter into the production phase the seismic bodies also need to be properly integrated with existing well data in 3D reservoir models for in-place volumetric calculations, connectivity analysis and flow simulation studies.
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Nurturing Knowledge Sharing Practices to Close Knowledge Gaps and Building Capabilities in PMU
Authors Che Zan Hj Yassin, M. Rozaidee Harun and Ismail IsaThroughout years of exploration and development in E&P business, lots of successes and failures happen. Experiences staffs’ mobility have created knowledge gaps and therefore time consuming for building right capabilities timely to sustain the performance. These posters highlights on knowledge management initiatives and efforts implemented within PMU to support its business.
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Time-lapse study and acquisition of monitor survey over carbonate gas fields in Sarawak water, East Malaysia
Authors Bor-Seng Lee, Yip-Cheong Kok, Hua Zhu and Chee-Kiong NguTime-lapse feasibility study was carried out over two carbonate fields. The study indicated that 4D signal could be observed after 3 years of production over the fields. The 4D signal could be observed if the 4D non-repeatable RMS (NRMS) noise
level were 0.2 or less. Without previous 4D monitor survey been acquired in the area,
there was an uncertainty on how much repeatability was required to achieve a 4D
NRMS noise level of 0.2. A provisional value of 150m for delta source plus delta receiver (⊗S + ⊗R) error was used for planning purpose. In addition, the 4D monitor
survey could not be acquired at the same month as the base survey. This added
another uncertainty to the amount of repeatability that can be achieved in the 4D
monitor survey. To overcome these uncertainties and achieve as good repeatability as
possible, additional two streamers were deployed and a fair amount of time were
allocated to cater for 4D re-shoot of lines if required. The monitor survey started in
mid August 2005 and was completed in 20 days. The base survey lines (prime and
infill lines) were completed in 15 days while the remaining 5 days were used to
acquire 4D re-shoot lines. Feathering angle was used as immediate QC parameter while more comprehensive QC plots were generated after several lines were
completed before deciding on 4D re-shoot. 4D repeatability measurement of ⊗S + ⊗R at 2500m to 2575m offset indicated a better than 10m error were achieved for some of the line while majority of the lines were less than 75m. The survey achieved its 4D repeatability objective and preliminary processing has shown observable 4D signal.
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Integrated Multiwell Facies Analysis using Core, Borehole Images and Computed Logs - Muda and Jengka Fields
Authors Debnath Basu, Edna Malim, Tanwi Basu, Francis Advent, Ricky Majit, Alwin Djamaoeddin, Suwith Sitha and Nizam A. BakarThis study was commissioned in light of CPOC’s need to meet first gas production in 2008 from two gas fields, Muda and Jengka. The fields are within the Malay Basin and located in the Joint Development Area (JDA), straddling the border between Malaysia and Thailand, some 500km north of Kuala Lumpur.
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Evaluating Textural Changes and Bedding Characteristics Within Clastic Environments Using Electrical Borehole Images
Authors Steven M. Hansen, Edna Malim and Azlina HabibullahElectrical borehole images have been utilized to evaluate clastic environments for over 15 years. During this period an interpreter has classified textural changes only as visual features and all bedding characteristics manually. Now two new semi-automatic products have been developed to capture highresolution textural information from electrical borehole images, and characterize the bedding into bed thickness and bedding trends. These products will add attributes to image analysis that can supplant verbal descriptions of clastic textures. The first method, SandTex, analyzes the total image spectrum in a 1-in. interval around the well bore. An electrical heterogeneity index is calculated from the percentile resistivity distribution of the image spectrum. This resistivity spectrum can be divided into a well-sorted portion and the fractions that are either more resistive or conductive. The resistivities of these three fractions can then all be calculated. The second method, STRATA, is divided into two sections. The first section calculates a levelby-level percentages of sand, silt, shale, tight (cemented), and wet sand based on cutoffs applied to a calibrated image output and then integrates these outputs. The second section is used to calculate bedding density and thickness from three different methods. The bedding characteristics are computed from any or all of the following 1) changes in facies based on the cutoffs listed above, 2) the inflection point on a squared high resolution resistivity curve or 3) from a dip set whether hand picked or computed with an automatic dip computation algorithm. These outputs are calculated and displayed in measured depth (MD), true vertical depth (TVD), true vertical thickness (TVT) and true stratigraphic
thickness (TST).
These outputs, heterogeneity-index, fractional resistivities, variability, along with bedding measurement characteristics and associated open hole log data, can be combined to compute a facies description that captures the textural content of these clastic environments. This high-resolution analysis
can be used to verify the variations seen in nuclear magnetic permeability and relative pore sizes in a more precise geological context. By extracting pertinent information from electrical images, this technique makes image logs more accessible for use in petrophysical as well as geological analyses.
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Fault system analysis with automatic fault displacement estimates: an exploration case study from the Norwegian Sea
Authors A. Carrillat, H.G. Borgos, T. Randen, L. Sonneland, L. Kvamme and K. HanschA procedure for complex fault system analysis is presented where automated fault mapping technology has been coupled with an automated fault displacement estimate algorithm. This new technology is based on classification of seismic extrema identified on either side of the fault plane and allows generating a continuous measurement of the fault displacement along the fault plane and analyzing its variability in space. The driving concept is to enable a system level interpretation, where the interpreter or structural geologist focuses his attention and expertise on analyzing the fault system and quality control of the automatically mapped faults instead of doing manual interpretation work. The key elements characterizing a fault are now provided automatically and include for each individual fault plane: orientation, dip and azimuth, size, position, and statistics on displacement values such as minimum (10th percentile), median (50th percentile) and maximum (90th percentile) displacement. A visual representation of the fault displacement values on the fault plane helps understanding the orientation of paleo-stress and checking if is has a kinematic meaning. This new technology has been applied to a prospective field, characterized by deepwater, Cretaceous turbidite (probably distal) system off Norway and helped the characterization of two apparent polygonal fault networks located at different depth.
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M3 South Discovery in Central Luconia
Authors Donald Sim, Piet Lambregts, Guenter Jaeger and Nicholas TengIn 2003 SSB made a gas-condensate discovery, M3 South, in the prolific Central Luconia Province, 7 km south of the M3 gas field. M3S-1 was drilled in May 2003 on the crest of a steeply dipping carbonate pinnacle build-up. The well encountered 420’ of gas in a GDT situation and the well was abandoned after encountering drilling problems. Initial pressures from the exploration well suggested a much longer hydrocarbon column yet to be proven. An appraisal well was drilled in May 2004 with the successful deployment of pressurised mud cap drilling to handle occurring total losses. The appraisal well, drilled on the steep flank, successfully proved an 1100’ gas column. Pressure measurement suggests that M3 South is situated in a confined pressure setting, with a 400psi aquifer pressure increase from the surrounding fields (M1, Jintan, M3, M4). Gas analysis suggests that M3 South has a unique hydrocarbon source and migration pathway despite being located only several kilometres from producing fields. The steeply dipping flank of the pinnacle made seismic imaging and depth prognosis difficult. Initial PSDM imaging shows significant improvement in the internal imaging of the build-up. The exploration and appraisal campaign were planned using an integrated exploration, well engineering and development team. The benefit of this well coordinated effort was a smooth transition from exploration to production with the Field Development Plan being completed within 6 months after the appraisal campaign.
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Amplitude Extraction and Rock Properties Calibration (AVO Analysis)
More LessSeismic reflections are used in oil business to locate geological structures that have the potential to trap hydrocarbons. Geophysicists discovered that the presence of gas/oil often coincided with the presence of high amplitude reflections known as “bright spots.” The bright spot technique was found to have limitations in that factors other than gas or oil, could cause bright reflections. Wells drilled into “Bright spots” have encountered igneous intrusions, carbonates, hard streaks and wet sands. A more definitive test rather than bright spots detection on a stacked seismic section was sought for the direct detection of gas on seismic records. One such test is the analysis of amplitude variation with offset (AVO). Amplitude versus offset or AVO analysis has played an increasing role over time and is now becoming a routine part of exploration studies. The aim is to minimise the uncertainty associated with the prospect and improve the chance of drilling successful exploration wells. The overall objectives of the AVO analysis are as follows:
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2003 Petronas Tinjar 2d Land Seismic Survey Onshore Sarawak: Field Experiences
Petronas had acquired 520km of 2D Land Seismic Survey over Tinjar Province, onshore Sarawak in 2003 with the objective of identifying potential leads. Land seismic survey over Malaysia is rarely acquired by Petronas or other PSCs. The last survey was conducted over ten to fifteen years ago. The survey area covered different areas which include thick tropical jungle, swampy area and acacia plantations. A total of 520 kilometers of 2D seismic data was acquired within 9 months or equivalent to two hundred fifty five (255) days of operational work. Prospective areas or leads were identified based on Gravity and Magnetic Survey and Synthetic Aperture Radar (SAR) image studies conducted by Petronas. Trap styles in the Tinjar Province are large anticlinal trap with complex wrench-related faults. The structural closures are associated with NWSE dextral faults and NNE-SSW sinistral faults. Principal reservoir plays in the Tinjar province are the Oligocene-Lower Miocene (Cycle I/II) clastics located approximately 1500m deep. In the field, we were assisted by Petronas Representatives to explain regarding the
procedures and workflow sequences of Land seismic operations such as Rintis, Bridging, Recording, etc. In conclusion, we have gathered good field experience and better understanding of land seismic survey operations from the Petronas Tinjar Land Seismic Survey.
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Overview Of Recent Malaysia Oil & Gas Discoveries
More LessFrom the Petronas point of view, the bottom line is good and has been getting better for the last several years. Numerous exploration oil and gas discoveries have been made in Malaysia in Sabah, Sarawak and Malay Basins recently; and examples of many of these discoveries will be presented. The new discovery examples include novel play-types such as fractured basement, and new exploration concepts regarding carbonate pinnacle reef buildups and clastic turbidite fans. These discoveries were made in both shallow and deepwater environments - the larger of which continue to be located in deep water Sabah. The ability of the Malaysian petroleum industry to locate and discover both low CO2 gas structures within CO2 rich corridors, and oil prone discoveries where conventional wisdom expected gas-rich reservoirs will be mentioned. The multitude of new exploration trends available in conjunction with the inventory of undrilled prospects offers a myriad of opportunities for successful exploration, development and production in Malaysia. Some of these new opportunities will be presented.
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