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Kelantan
Successful Development of the Deepest Oligocene Syn-Rift Sediment in the Malaysia-Thailand Joint Development Area: Is the Deeper Zone Our Future?
Setiawan, Avidianto Suryo (Carigali-PTTEPI Operating Company Sdn. Bhd) | Simatupang, Martin Hendra (Carigali-PTTEPI Operating Company Sdn. Bhd) | Rachmadi, Arif (Carigali-PTTEPI Operating Company Sdn. Bhd) | Apiwathanasorn, Sippakorn (Carigali-PTTEPI Operating Company Sdn. Bhd) | Moh. Said, Samsul Bari (Carigali-PTTEPI Operating Company Sdn. Bhd)
Abstract Field X, located in the offshore Malaysia-Thailand Joint Development Area (MTJDA), comprises multiple stack gas reservoirs with a combination of trap styles. This paper highlights the challenges and lessons learned in successfully developing the deepest Oligocene syn-rift sediment in the MTJDA, which was initially discovered by the one appraisal well drilled in 2010. A further comprehensive evaluation was performed to justify the deepening of development drilling in 2019 (as appraisal cum to development) and 2021-2022 (as infill wells) with promising results. The discovery of hydrocarbon resources in the deepest Oligocene syn-rift sediment at MTJDA was part of an appraisal program by deepening the development well. The two wells discovered and proved the presence of multi-stack gas sands in this deepest section (3800-4000 mTVDSS). The clastic sediment deposits in a fluvio-deltaic system. The reservoir properties of this syn-rift sediment are better than the early post-rift sediment (early Miocene). The production test confirmed the initial gas flow rate of about 15 MMscfd. A comprehensive analysis was performed to evaluate a sizeable volume before more development wells were proposed for this deepest sediment. The initial understanding of Late Oligocene syn-rift sediment was very minimal at the beginning of the project. One of the neighbouring well information suggests lacustrine delta environments based on core data. However, a fair-quality seismic amplitude shows a broader channel belt (over 3km width) which usually exists in the braided stream. In view of the two appraisals cum to development wells' successful discovery, more than five wells were proposed to penetrate this zone as a deepening target from the existing discovered zone. The fit for purpose well designed with a monobore concept, was selected. Upon completing the development drilling with denser well spacing, it suggests the discontinuity of blocky sand presence with multiple fluid contact (stratigraphic compartmentalization), which is usually found in narrower channel reservoirs at the deltaic system rather than the braided stream. The good reservoir properties observe from the open hole log, formation tester, and production test. The success story of these wells opens future opportunities to plan more deep well to develop Oligocene sediment, which prove to be a good hydrocarbon producer. This paper updates the previous understanding of geology, such as the depositional environment, and the understanding of reservoir productivity of the Oligocene sediment in MTJDA. It also proved sizable reservoir quality with extensive lateral presence and good productivity. Hence, the company foresee a promising future from this deep reservoir to prolong its long-term development plan.
asia government, asset and portfolio management, deepest oligocene syn-rift sediment, ds12, ds12 reservoir, international petroleum technology conference, Malay Basin, malaysia government, malaysia-thailand joint development area, mtjda, North Malay Basin, reservoir, Reservoir Characterization, sediment, seismic processing, seismic surveying, structural geology, successful development, thailand government, united states government, Upstream Oil & Gas
Country:
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.87)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.87)
- North America > United States > Kentucky > Butler County (0.24)
Geologic Time:
- Phanerozoic > Cenozoic > Paleogene > Oligocene (1.00)
- Phanerozoic > Cenozoic > Neogene > Miocene (0.89)
Successful Development of the Deepest Oligocene Syn-Rift Sediment in the Malaysia-Thailand Joint Development Area: Is the Deeper Zone Our Future?
Setiawan, Avidianto Suryo (Carigali-PTTEPI Operating Company Sdn. Bhd) | Simatupang, Martin Hendra (Carigali-PTTEPI Operating Company Sdn. Bhd) | Rachmadi, Arif (Carigali-PTTEPI Operating Company Sdn. Bhd) | Apiwathanasorn, Sippakorn (Carigali-PTTEPI Operating Company Sdn. Bhd) | Moh. Said, Samsul Bari (Carigali-PTTEPI Operating Company Sdn. Bhd)
Abstract Field X, located in the offshore Malaysia-Thailand Joint Development Area (MTJDA), comprises multiple stack gas reservoirs with a combination of trap styles. This paper highlights the challenges and lessons learned in successfully developing the deepest Oligocene syn-rift sediment in the MTJDA, which was initially discovered by the one appraisal well drilled in 2010. A further comprehensive evaluation was performed to justify the deepening of development drilling in 2019 (as appraisal cum to development) and 2021-2022 (as infill wells) with promising results. The discovery of hydrocarbon resources in the deepest Oligocene syn-rift sediment at MTJDA was part of an appraisal program by deepening the development well. The two wells discovered and proved the presence of multi-stack gas sands in this deepest section (3800-4000 mTVDSS). The clastic sediment deposits in a fluvio-deltaic system. The reservoir properties of this syn-rift sediment are better than the early post-rift sediment (early Miocene). The production test confirmed the initial gas flow rate of about 15 MMscfd. A comprehensive analysis was performed to evaluate a sizeable volume before more development wells were proposed for this deepest sediment. The initial understanding of Late Oligocene syn-rift sediment was very minimal at the beginning of the project. One of the neighbouring well information suggests lacustrine delta environments based on core data. However, a fair-quality seismic amplitude shows a broader channel belt (over 3km width) which usually exists in the braided stream. In view of the two appraisals cum to development wells’ successful discovery, more than five wells were proposed to penetrate this zone as a deepening target from the existing discovered zone. The fit for purpose well designed with a monobore concept, was selected. Upon completing the development drilling with denser well spacing, it suggests the discontinuity of blocky sand presence with multiple fluid contact (stratigraphic compartmentalization), which is usually found in narrower channel reservoirs at the deltaic system rather than the braided stream. The good reservoir properties observe from the open hole log, formation tester, and production test. The success story of these wells opens future opportunities to plan more deep well to develop Oligocene sediment, which prove to be a good hydrocarbon producer. This paper updates the previous understanding of geology, such as the depositional environment, and the understanding of reservoir productivity of the Oligocene sediment in MTJDA. It also proved sizable reservoir quality with extensive lateral presence and good productivity. Hence, the company foresee a promising future from this deep reservoir to prolong its long-term development plan.
asia government, asset and portfolio management, deepest oligocene syn-rift sediment, ds12, ds12 reservoir, international petroleum technology conference, Malay Basin, malaysia government, malaysia-thailand joint development area, mtjda, North Malay Basin, reservoir, Reservoir Characterization, sediment, seismic processing, seismic surveying, structural geology, successful development, thailand government, united states government, Upstream Oil & Gas
Country:
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.87)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.87)
- North America > United States > Kentucky > Butler County (0.24)
Geologic Time:
- Phanerozoic > Cenozoic > Paleogene > Oligocene (1.00)
- Phanerozoic > Cenozoic > Neogene > Miocene (0.89)
An Overview of Successful Fit to Purpose Tubing Stem Test Operation on MUFFIN-X Appraisal Well to Unlock Gas Potential of Deep Formation with HPHT & High CO2-H2S Environment in MTJDA, North Malay Basin
Setiawan, Avidianto Suryo (Carigali-PTTEPI Operating Company Sdn Bhd) | Apiwathanasorn, Sippakorn (Carigali-PTTEPI Operating Company Sdn Bhd)
Abstract This paper will share a success story of a well-test operation performed on MUFFIN-X, an appraisal well located at the northern part of the Malaysia-Thailand Joint Development Area (MTJDA). The well was drilled in Q4-2020 and penetrated two fault blocks of northern MTJDA to appraise the area for further field development study and proposal. The objective of the test itself is to acquire new data to reduce the subsurface uncertainties and unlock the gas potential from deep formations of the area, which is well known for its multilayer reservoirs, High Pressure-High Temperature (HPHT), and high CO2-H2S content. These conditions are the key challenges to developing the area. To cope with the challenges, Carigali-PTTEPI Operating Company (CPOC) has been using a Tubing-Stem-Test (TST) approach that provides secured wellbore conditions and multiple accessibilities to multiple reservoirs, straightforward operation, and realistic production simulation. The TST of MUFFIN-X was designed to complete each zone within 24-to-36 hours for deliverability and pressure transient tests. The TST performed on MUFFIN-X has successfully unlocked 20 MMscf/d of gas and 5000 bbl/d of oil potentials from the deep formations of the block. The job was completed 16 hours earlier than the design, bringing approximately 40K USD of cost optimization.
Country:
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.81)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.81)
SPE Disciplines: Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
Prospectivity and Resource Potential of the Malaysia-Thailand Joint Development Area JDA: Results from an Integrated Play Based Exploration Project
Ali, M. F. (Malaysia-Thailand Joint Authority) | Hernandez, J. (Schlumberger) | Brink, G. (Schlumberger) | Koronful, N. (Schlumberger) | Xue, F. (Schlumberger) | Jiang, L. (Schlumberger) | Bencomo, J. (Schlumberger) | Ishak, A. Z. (PETRONAS) | Skulsangjuntr, J. (Malaysia-Thailand Joint Authority)
Abstract The study area of this paper is located in the mature North Malay Basin, within the offshore Malaysia-Thailand Joint Development Area (MTJDA). Exploration activities have been conducted since 1971 and several gas fields have been developed, mostly at relatively shallow stratigraphic levels of Late Miocene sequences. The study area covers 7250 km, which includes exploration and production areas covered by approximately 300 wells, 6400 km of 3D surveys and 10664 km of 2D seismic line. The multi-disciplinary team was tasked to establish the overall hydrocarbon potential of the area, including potential new play-openers and covering the area outside of existing PSC acreages. The workflow initially focused on post drill analysis of the existing wells whereby new complete petrophysical analyses for 74 exploration and appraisal wells were incorporated. Geological and geophysical interpretation focused on delineation of regional structural setting and development of a seismic sequence stratigraphic framework. This comprised of interpretation of key selected surfaces at wells and on seismic in the Oligocene and Miocene succession of the North Malay Basin. Upon completion of the tectono-stratigraphic interpretation, litho- and chrono-stratigraphy, sedimentology and sequence stratigraphy, analyses of seismic attributes and gross depositional environments (GDE), velocity model construction, depth conversion, isopach maps, regional overpressure trends; hydrocarbon play analyses could then proceed as supported by comprehensive petroleum system modelling and a regional CO2 study. Source rock hydrocarbon generation and migration timing are favourable throughout the Oligocene to Pliocene at all prospect levels. At lead and prospect scales, work on seismic inversion, AVO analyses and pore pressure modelling were undertaken preceding prospect volumetrics, risking and ranking. Primary target play types are predominantly comprised of stacked, stratigraphic structural combination traps of tidedominated estuarine reservoirs, deposited within a high frequency 4-order sequence. This comprehensive play based evaluation approach has successfully identified remaining hydrocarbon prospectivity, not only at deeper undrilled stratigraphic levels, but also at current producing shallow sequences. Several potential drillable prospects were further analyzed for future exploration, often with strong stratigraphic elements, as well as unconventional new play-types enabled by conceptual geological models and supported by existing data analysis and interpretation. Furthermore, a robust petroleum system modeling has enhanced and supported prospective plays in this basin, facilitating realistic yet-to-find resource estimates over the entire area, with good future prospectivity remaining in the area. Apart from the various collaborative technical studies carried out during the project, the imperative factor behind the success of this project was the synergy and co-operation among the team members, with regular technical and management reviews.
Exploration Project, Hydrocarbon Prospectivity, integrated play, interpretation, Malay Basin, malaysia-thailand joint authority, malaysia-thailand joint development area jda, Miocene, North Malay Basin, Offshore Technology Conference, Reservoir Characterization, resource potential, sequence, stratigraphic level, structural geology, study area, Upstream Oil & Gas
Country:
- Asia > Malaysia > South China Sea (0.48)
- North America > United States > Texas (0.35)
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.25)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.25)
Geophysics:
- Geophysics > Seismic Surveying > Seismic Interpretation (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.88)
SPE Disciplines:
Success Story of Integrated Reservoir Characterization and Reservoir Management Approach to Deliver Infill Wells in the MTJDA Area, North Malay Basin
Setiawan, A. S. (Carigali-PTTEPI Operating Company Sdn. Bhd.) | Simatupang, M. H. (Carigali-PTTEPI Operating Company Sdn. Bhd.) | Rachmadi, A. (Carigali-PTTEPI Operating Company Sdn. Bhd.) | Ratanavanich, S. (Carigali-PTTEPI Operating Company Sdn. Bhd.) | Pushiri, M. F. Mohd (Carigali-PTTEPI Operating Company Sdn. Bhd.)
Abstract In the event of high gas demand, infill well drilling is one of the best option to increase gas deliverability. Finding infill well opportunity in a brown field is a challenging task. Reservoir continuity, heterogeneity of the rock properties, pressure depletion and identifying undrained area are the major concern for infill wells candidate selection. A robust reservoir characterization and dynamic information are essential to provide some key understanding about the field. The area of interest, Muda field, is located in the Block B-17 of Malaysia-Thailand Joint Development Area (MTJDA) which has been producing for more than 5 years. Integration of multidisciplinary data is very important to identify the potential hydrocarbon bypassed area. To start with, the geological model was built and constrained with seismic attributes after calibration to the well data. The high uncertainty of reservoir presence in the model was assessed by combining the sand distribution and porosity variation. Subsequently, history matching was performed to calibrate the model with actual production flow rates and reservoir pressure. A reasonably good history match was achieved and provides a certain degree of confidence in production forecast. As a result, it shows some potential undrained areas to be selected as the area of infill well candidate. The infill wells were drilled within 1 to 2 years later and the well results has demonstrated a successful delivery of infill well as expected both in encountered netpay and production. This paper discusses a successful collaboration between multidisciplinary team members in the subsurface division to deliver infill well candidate by building a comprehensive reservoir model which integrate of all hard data from geological concept, seismic attribute, well and production. Five successful infill wells were drilled in accordance to this campaign, expected potential and volume are generally as expected with some surprises in some interval. The gas potential comes from these infills are very important to fulfil gas deliverability. It is foreseen that additional infill wells are expected and evaluated using the 3D reservoir model.
asset and portfolio management, deliver infill well, Drillstem Testing, drillstem/well testing, fault block, history matching, hypothesis, infill well, integrated reservoir characterization, Malay Basin, Modeling & Simulation, Muda Field, North Malay Basin, Offshore Technology Conference, productivity, reservoir, Reservoir Characterization, Reservoir Management Approach, reservoir model, sequence, Upstream Oil & Gas
Country:
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.92)
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.61)
Oilfield Places:
- Asia > Malaysia > South China Sea > Malay Basin (0.99)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) > Muda Field > Malaysia-Thailand JDA > Block B-17 > Muda Field (0.99)
SPE Disciplines:
Successfully Unlocking New Deep Reserves and Overcoming High-Temperature Environment Using Novel Advanced Hostile Wireline Formation Tester in North Malay Basin, Malaysia-Thailand Joint Development Area
Costam, Y. R. (PTTEPI Operating Company) | Fadjarijanto, A.. (PTTEPI Operating Company) | Zakaria, Z. U. (PTTEPI Operating Company) | Setiawan, A. S. (PTTEPI Operating Company) | Pushiri, M. F. (PTTEPI Operating Company) | Carigali, C. Jiraratchwaro (PTTEPI Operating Company) | Lee, C. Y. (Halliburton) | Iyer, M. S. (Halliburton) | Zuilekom, T. V. (Halliburton) | Parashar, S.. (Halliburton) | Bagir, M.. (Halliburton) | W. Z .M, Ivan (Halliburton)
Abstract Gas fields in a Malaysia-Thailand joint development area (MTJDA) are well-known to have the presence of high CO2 concentration and high-temperature reservoir characteristics. Sophisticated tools are necessary to measures important data to support further development and reservoir management of this field. Thus, reservoir data, such as pressure and fluid type, become crucial in terms of achieving production targets. Fields operated by this operator are located in the North Malay Basin, a few hundred kilometers from the onshore border of Malaysia and Thailand. High bottom hole temperatures (BHTs) limits data gathering runs and challenges associated with fresh water made it more crucial to identify and qualify fluid types for further field development. The extensive wireline formation pressure testing and sampling (WFPT&S) program is mandatory to evaluate the viability of field development. Additional challenges included low porosity-low mobility reservoirs where fluid collection at low contamination in reservoirs with elevated temperatures of approximately 410°F (210°C) is considered a necessity. This operator pioneers the use of novel hostile wireline formation testers globally. Reliable pressure and downhole fluid analysis data should lead to production optimization. The ability of fluid characterization using a pump-out formation tester coupled with downhole fluid identification has been introduced to help improve decision making and provide real-time data and the capability to pump out high-temperature formation fluid and acquire samples that meet expected contamination levels. As a result, fluid contact, formation pressure, fluid type, reservoir mobility, and CO2 content, which are the primary drivers of production optimization and field development are able to be determined successfully. In addition, new deep reserves could potentially be discovered in the MTJDA concession that are economically accessible with extreme high-temperature tools. This paper discusses the use of a novel hostile wireline formation tester to collect low contamination samples at a predetermined level in hostile reservoir conditions with elevated temperature of 410°F (210°C). Challenges, considerations, and results are detailed. This novel tool has proven lower CO2 content than expected in deeper reservoirs with elevated temperature up to 410°F (210 °C). This is the deepest well ever drilled by this operator in a development drilling campaign.
advanced hostile wireline formation tester, fluid sample, Formation Fluid, formation tester, formation testing, hostile environment, hostile formation tester, identification, log analysis, Malay Basin, malaysia-thailand joint development area, North Malay Basin, operator, overcoming high-temperature environment, Petroleum Engineer, pressure gradient, real time system, reservoir, Upstream Oil & Gas, well logging
Country:
- Asia > Malaysia > South China Sea (0.62)
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.46)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.46)
- North America > United States > Montana > Roosevelt County (0.24)
Oilfield Places:
- Asia > Malaysia > South China Sea > Malay Basin (0.99)
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) > Malay Basin > Malaysia-Thailand JDA > Malaysia-Thailand Joint Development Area (MTJDA) (0.98)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) > Malay Basin > Malaysia-Thailand JDA > Malaysia-Thailand Joint Development Area (MTJDA) (0.98)
SPE Disciplines:
Unlocking Future Petroleum Potentials with Exploration Discoveries in North Malay Basin, Malaysia-Thailand Joint Development Area
Adnan, M. Mohd (Carigali-PTTEPI Operating Company) | Ismail, W. Wan (Carigali-PTTEPI Operating Company) | Kaewtapan, J. (Carigali-PTTEPI Operating Company) | Setiawan, A. S (Carigali-PTTEPI Operating Company) | Tanprasat, S. (Carigali-PTTEPI Operating Company)
Abstract A comprehensive technical evaluation was conducted after the completion of six exploration and appraisal wells to assess the future petroleum potentials in North Malay Basin, offshore Malaysia-Thailand Joint Development Area (MTJDA). This paper focuses on major discoveries and findings from key wells, namely Well-E3, Well-A2ST, and Well-T3 to better understand the petroleum potentials for the subsequent development planning. Well-E3 and Well-A2ST were drilled to investigate the stratigraphic trap play in the eastern flank of MTJDA and to explore the hydrocarbon potential in deeper depositional sequence below DS10 interval. The seismic dataset and amplitude analyses were used to identify channel fairways and qualitatively predict sand presence for well planning optimization. Both wells encountered gas-bearing sands with proven stratigraphic trap style, requires channel orientation oblique with the axial anticline structure. Full integration of well log dataset, formation pressure test and seismic attribute analyses have proven the exploration intervals with gas-bearing sands discoveries. In addition, rock physics analysis was performed to differentiate gas from wet sand and coals. Well-T3 was drilled in the western flank to appraise the seismic anomaly associated with hydrocarbon sand and to investigate the CO2 content in the southernmost extension of hydrocarbon accumulation. The anomaly is observed as two distinct sand fairways of channel-bar complex. The northern lobe was dissected by deep seated fault system with high CO2 content. The southern lobe appears to be free from deep seated fault system. Well-T3 was drilled in the area where CO2 pathways was expected to have no connection with deep seated fault system and lower CO2 content than the main area. Formation pressures, samples and seismic anomaly supported the hypothesis that the northern and southern culminations are not connected with significant stratigraphic heterogeneity interpreted. An important oil discovery was also observed from pressure gradient and samples as the first oil discovery in the western flank. Full integration of the well log dataset, formation pressures, seismic attribute analyses and rock physics modeling have resulted in an improved understanding of reservoir distribution and reduced the degree of uncertainty in reservoir connectivity, thus allowing a more robust development strategy. The new discoveries of proven stratigraphic trap in the eastern flank with deeper hydrocarbon culminations and proven oil discovery in the western flank with enhanced understanding of CO2 content have triggered more future petroleum potentials in MTJDA acreage.
co 2, discovery, eastern flank, fault system, flank, international petroleum technology conference, joint development area, malaysia-thailand joint development area, North Malay Basin, petroleum potential, Reservoir Characterization, southern lobe, structural geology, Upstream Oil & Gas, well-a2st, well-t3, western flank
Country:
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.65)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.65)
- Asia > Malaysia > South China Sea (0.61)
Geophysics:
- Geophysics > Seismic Surveying > Seismic Interpretation (1.00)
- Geophysics > Seismic Surveying > Seismic Processing (0.71)
Oilfield Places:
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) > Malay Basin > Malaysia-Thailand JDA > Malaysia-Thailand Joint Development Area (MTJDA) (0.98)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) > Malay Basin > Malaysia-Thailand JDA > Malaysia-Thailand Joint Development Area (MTJDA) (0.98)
Deepest Gas Sand Discoveries in North Malay Basin: Integration of Geophysical Applications and Well Data Leading to an Effective Evaluation for a Robust Development Plan, Malaysia-Thailand Joint Development Area
Adnan, M. Mohd (Carigali-PTTEPI Operating Company) | Ismail, W. Wan (Carigali-PTTEPI Operating Company) | Setiawan, A. S. (Carigali-PTTEPI Operating Company)
Abstract Integrated geophysical applications and well datasets play an important role in understanding reservoir distribution and decision making for a robust development plan. A technical assessment was completed in a gas field in the North Malay Basin to describe the reservoir heterogeneity in the Early Miocene to Late Oligocene reservoir intervals. The field is a North-South oriented plunging anticline with stratigraphic trap configuration, discovered in 2007 by Well-X1. The assessment has resulted in a proposal of an appraisal well in 2014, Well-X2ST to delineate the northern hydrocarbon extent and to assess the hydrocarbon potential in the exploration interval of deeper sequences. The new well datasets were acquired and the results were utilized to further evaluate the field. This paper focuses on the deepest reservoir sequence, DS12, encountered by the appraisal well in the eastern flank of the Malaysia-Thailand Joint Development Area (MTJDA). Rock physics modeling and seismic attribute datasets with well log and pressure data integration were utilized to better understand sand distribution for the upcoming development planning. Due to the thinly bedded nature of the reservoirs, the seismic could not be fully utilized to evaluate internal stacking geometries. This was further complicated by attenuation from the overlying thick shale. However, attribute analysis was effective to determine overall sand presence where the bed thickness ranges from 10 to 15 meters and the seismic detection limit is approximately 8 meters. Rock property analysis was performed to calibrate both acoustic impedance and Vp/Vs to gamma ray for indication of sand presence. The Vp/Vs derivative was used instead of acoustic impedance because of the extra information obtained in both the elastic and AVO domain. In addition, rock physics modeling was performed to differentiate gas from wet sand and shale. The seismic datasets were used to qualitatively condition a geologic model to better distribute sand presence for well planning optimization. Development wells are planned to target good quality sands to maximize recovery efficiency The success of proving the deepest reservoir sequence in the eastern flank of MTJDA, utilizing geophysical application and well data integration, have resulted in an improved understanding to outline deep reservoir distribution in the surrounding area and mitigate uncertainties in the development plan.
Country:
- Asia > Malaysia > South China Sea (0.63)
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.45)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.45)
Geologic Time:
- Phanerozoic > Cenozoic > Neogene > Miocene (0.75)
- Phanerozoic > Cenozoic > Paleogene > Oligocene (0.54)
Geophysics:
Oilfield Places:
SPE Disciplines:
Successful Application Of Ultrasound Technology To Detect Sand Producing Intervals In The Wellbore
Mohd Daud, Farik (Carigali Hess Operating Company) | Jusoh, Hasni (Carigali Hess Operating Company) | Mohamed, Azhan (Carigali Hess Operating Company) | Then, Eii Feng (Carigali Hess Operating Company) | Batumelai, Sathish Kumar (TecWel AS)
Abstract Sand production in oil and gas wells not only poses a serious threat to hydrocarbon production, but can also cause extensive damage to equipment, such as subsurface tubing, surface valves and pipelines. Produced sand is also an environmental hazard, and needs to be disposed of in an environmentally safe way. Effective sand management is therefore a major concern in the oil and gas industry. The key challenge is to optimize hydrocarbon production by minimizing the production of sand and in doing so reduce the damage caused to well completions and surface equipment. On a sand-prone well, this is typically done by identifying a maximum sand free rate (MSFR), and then limiting production to this level. Conventional sand detection methods rely on surface measurements. However, these methods do not provide a complete picture of the sand production down hole. To gain a more comprehensive understanding of the problem, sand needs to be detected at its point of entry into the well bore. In this way, the best remedial treatment can be designed. To answer this requirement, an ultrasonic sand detection tool has been developed. The tool detects ultrasound energy generated by sand grains as they enter the well bore and strike the tool in a radial manner. Sand moving parallel to the well bore axis is not detected, thus the tool can indicate the exact entry point of sand, anywhere along the producing interval. The operator can then specify the most appropriate and cost effective remedial action, such as installing sand screens or applying chemical treatments. By employing such a tool, the cost of remedial action can be minimized and hydrocarbon rates can be optimized to achieve sand-free production. The tool can also be used to evaluate the performance of sand screens and other control devices, and if run in tandem with production logging tools, can monitor sand production in conjunction with well performance. This paper presents the results of a case study where a downhole ultrasonic sand detector was used to monitor sand production in five gas-producing wells from the Northern Malay Basin. The methods behind this "sand survey" are presented, along with a description of the tool. Introduction and Background Carigali Hess Operating Company Sdn. Bhd. (Carigali Hess) operates the Cakerawala, Bumi, Suriya and Bulan gas fields in Block A-18 of the Malaysia-Thailand Joint Development Area (MTJDA). Figure 1A shows the geographical location of the MTJDA in relation to Malaysia and Thailand, while Figure 1B illustrates the current arrangement of platforms and pipelines operated by Carigali Hess in the block.
carigali hess, detect sand producing interval, detector, flow assurance, flow rate, international petroleum technology conference, iptc 14737, perforation, production control, production logging, production monitoring, Reservoir Surveillance, sand control, sand detection, sand detector, Sand entry, sand ingress, sand production, successful application, ultrasound energy, ultrasound technology, Upstream Oil & Gas, wellbore
Country:
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.74)
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.45)
Oilfield Places:
- Asia > Malaysia > South China Sea > Malay Basin (0.99)
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) > Malay Basin > Malaysia-Thailand JDA > Block A-18 > MTJDA > Cakerawala Field (0.94)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) > Suriya Field > Malaysia-Thailand JDA > Block A-18 > Suriya Field (0.94)
- (3 more...)
SPE Disciplines:
The Practical Applications Of Coupled Models From Reservoir To Sales Point For Fields With Highly Variable CO2 Content
Ong, Cheng-Sun (Hess Corp.) | Maroongroge, Vichai (CarigaliHess Operating Company) | Tan, Leong Hooi (CarigaliHess Operating Company) | Chin, Yee Hoe (CarigaliHess Operating Company)
Abstract This paper presents an integrated production model construction workflow with actual field application from four fields with multiple stacked reservoirs and with varying carbon dioxide (CO2) content (up to 60%) located in the Malaysia-Thailand Joint Development Area (MTJDA). The subsurface-to-surface linked coupled models are history matched to field performance and reconciled to the surface gas utilization (fuel, flare, drop-out, etc.) under specific operating conditions to meet sales specifications. The capability of the subsurface-to-surface linked coupled models is further enhanced with the modeling of the CO2 membrane unit to aid in development planning. This integration is expected to help to maximize the economic value from the assets by accurately predicting the reservoir performance with respect to the surface network constraints. The objectives of this project are to: Produce more reliable sales forecasts Generate representative reserves recovery estimates Equally compare different projects in different fields Estimate the timing of future developments to meet existing Gas Sales Agreements The construction workflow can be described in four steps: Project Definition Test of Concept Quality Control Forecast. Project work scope calls for a coupled model that is able to generate a fully-automated combined field deliverability forecast at specified sales CO2 content that takes into account the CO2 removal unit, intra-field pipeline network, and every developable reservoir within the area. This custom built simulation model is capable of generating incremental production profiles from the integrated dynamic simulation models (as opposed to tank models) to the sales point and its configuration allows a "plug and play" option to allow additional models to be integrated easily. This is an example of effective use of current simulation techniques to robustly and efficiently address the challenges of developing complex assets with highly variable CO2 content.
asset and portfolio management, co 2, constraint, delivery quantity, field data, forecast, integration, limitation, Modeling & Simulation, Petroleum Engineer, practical application, production control, production monitoring, reservoir simulation, Reservoir Surveillance, sale gas, sale point, simulation model, spe 148259, specification, tank model, Upstream Oil & Gas, utilization, variable co2 content, workflow
Country:
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean (0.24)
- Asia > Thailand > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.24)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.24)
SPE Disciplines:
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