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)

OnePetroMarch, 2023

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.

OnePetro

doi: 10.2523/IPTC-23010-MS

IPTC

IPTC-23010-MS

International Petroleum Technology Conference

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)

Geophysics: Geophysics > Seismic Surveying > Seismic Processing (0.34)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > Malaysia > South China Sea > Malay Basin (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Management > Asset and Portfolio Management > Field development optimization and planning (1.00)

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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)

OnePetroMarch, 2023

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.

OnePetro

doi: 10.2523/IPTC-23010-EA

IPTC

IPTC-23010-EA

International Petroleum Technology Conference

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)

Geophysics: Geophysics > Seismic Surveying > Seismic Processing (0.34)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > Malaysia > South China Sea > Malay Basin (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Management > Asset and Portfolio Management > Field development optimization and planning (1.00)

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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)

OnePetroMarch, 2022

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.

OnePetro

doi: 10.4043/31590-MS

OTC

OTC-31590-MS

Offshore Technology Conference Asia

boundary, Drillstem Testing, drillstem/well testing, east fault block, fault block, hpht & high co2-h2 environment, jda area, muffin-x, muffin-x appraisal well, perforation, permeability, purpose tubing stem test operation, reservoir, sequence, unlock gas potential, Upstream Oil & Gas

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)

Geologic Time: Phanerozoic > Cenozoic (0.47)

Geophysics: Geophysics > Seismic Surveying (0.32)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines: Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)

Technology: Information Technology (0.48)

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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.

OnePetro

doi: 10.4043/28424-MS

OTC

OTC-28424-MS

Offshore Technology Conference Asia

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)

Geologic Time: Phanerozoic > Cenozoic > Neogene > Miocene (1.00)

Geophysics:

Geophysics > Seismic Surveying > Seismic Interpretation (1.00)
Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.88)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > Malaysia > South China Sea > Malay Basin (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)

Technology: Information Technology (0.35)

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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.)

OnePetroMarch, 2018

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.

OnePetro

doi: 10.4043/28581-MS

OTC

OTC-28581-MS

Offshore Technology Conference Asia

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)

Genre: Research Report (0.67)

Geophysics: Geophysics > Seismic Surveying > Seismic Interpretation (0.89)

Industry: Energy > Oil & Gas > Upstream (1.00)

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:

Reservoir Description and Dynamics > Reservoir Characterization (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
Management > Asset and Portfolio Management > Field development optimization and planning (1.00)

Technology: Information Technology > Modeling & Simulation (0.47)

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Abstract Tanjung Field is a brown field which pressure has already depleted and been supported by waterflooding for over a decade. To improve production, surfactant injection, is being studied to be employed in the field. The main objective of this study is to identify parameters that affect oil production increase. History match of the pilot test was carried out to improve the reliability of the reservoir model, hence improving the prediction result of surfactant injection forecast. History match of the pilot test has been carried out using CMG STARS commercial simulator by considering mechanism inferred from laboratory evaluation such as wettability alteration, surfactant retention, interfacial tension reduction and improvement of mobility control due to lower oil-surfactant emulsion viscosity. These parameters are initially perceived from laboratory result, upscaling and adjustment is applied to field model to further on do sensitivity study. Sensitivity analysis of every parameter is provided to better understand the effect of each mechanism that contributes to the oil incremental result. Stratigraphically, Tanjung Structure has 7 productive zones: Zone A, B, C, D, E, F and P. Reservoir Zone A has total estimated reserve of 193,732 MMSTB, with recovery factor of 16.3%. The zone consists of conglomerate sandstones with porosity of 21% and permeability ranging from 10 to 100 mD. The field produces light oil within 40 °API, 30% wax content and 1.14 cP of viscosity. T-119 is the well chosen to be injected due to its structural position that ease flow by gravity force to producer wells. Forecast simulation based on coreflood result has been conducted for pilot test. However, the result was very pessimistic in predicting incremental oil gain and breakthrough time after compared to pilot result. An attempt to history match the surfactant flood pilot is presented by considering phenomena that is not included in the forecast based on additional lab and field data.

OnePetro

doi: 10.2118/186325-MS

SPE

SPE-186325-MS

SPE/IATMI Asia Pacific Oil & Gas Conference and Exhibition

adjustment, adsorption, breakthrough time, capillary number, capillary number relative permeability, chemical flooding methods, enhanced recovery, forecast, History Match, Petroleum Engineer, residual oil saturation, sensitivity analysis, Simulation, support interpretation, surfactant flooding pilot test, tanjung field, Upstream Oil & Gas, waterflooding

Country:

Asia > Indonesia > Kalimantan (0.73)
North America > United States > Texas (0.69)
Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.63)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Indonesia > Kalimantan > Barito Basin > Tanjung Field > Tanjung Formation (0.99)
Asia > India > Rajasthan > Rajasthan Basin > Barmer Basin > Rajasthan Block > Mangala Field > Fatehgarh Formation (0.99)
Asia > India > Rajasthan > Rajasthan Basin > Barmer Basin > Rajasthan Block > Mangala Field > Barmer Hill Formation (0.99)
(2 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
Reservoir Description and Dynamics > Improved and Enhanced Recovery > Chemical flooding methods (1.00)

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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.

OnePetro

doi: 10.2118/186226-MS

SPE

SPE-186226-MS

SPE/IATMI Asia Pacific Oil & Gas Conference and Exhibition

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)

Genre: Research Report (0.54)

Geologic Time: Phanerozoic > Cenozoic (0.69)

Industry: Energy > Oil & Gas > Upstream (1.00)

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:

Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Formation test analysis (e.g., wireline, LWD) (1.00)

Technology: Information Technology > Architecture > Real Time Systems (0.69)

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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)

OnePetroNovember, 2016

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.

OnePetro

doi: 10.2523/IPTC-18676-MS

IPTC

IPTC-18676-MS

International Petroleum Technology Conference

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)

Geologic Time: Phanerozoic > Cenozoic (0.47)

Geophysics:

Geophysics > Seismic Surveying > Seismic Interpretation (1.00)
Geophysics > Seismic Surveying > Seismic Processing (0.71)

Industry: Energy > Oil & Gas > Upstream (1.00)

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)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)

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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)

OnePetroNovember, 2016

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.

OnePetro

doi: 10.2523/IPTC-18677-MS

IPTC

IPTC-18677-MS

International Petroleum Technology Conference

cross plot, dataset, deepest gas sand discovery, development plan, ds12, information, international petroleum technology conference, interpretation, malaysia-thailand joint development area, North Malay Basin, Reservoir Characterization, sequence, structural geology, Upstream Oil & Gas, well-x2st

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:

Geophysics > Seismic Surveying > Borehole Seismic Surveying > Vertical Seismic Profile (VSP) (1.00)
Geophysics > Seismic Surveying > Seismic Interpretation (0.89)

Industry: Energy > Oil & Gas > Upstream (1.00)

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) (0.97)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)

Technology: Information Technology (1.00)

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Integrated Sonic Shear Compressional Ratio for Seismic Rock Physics Calibration in the Development Gas Field a Case Study in Tapi Field of North Malay Basin

Fadjarijanto, A. (Carigali-PTTEPI Operating Company) | Pakpahan, O. (Carigali-PTTEPI Operating Company) | Kaewtapan, J. (Carigali-PTTEPI Operating Company) | Setiawan, A. S. (Carigali-PTTEPI Operating Company) | Simatupang, M. H. (Carigali-PTTEPI Operating Company) | Rahmadi, A. (Carigali-PTTEPI Operating Company)

OnePetroNovember, 2016

Abstract This paper presents a novel approach by integrating well log data evaluation to seismic rock physic calibration of field development plans. The result of the study was incorporated in the development drilling to optimizing well placement. To date, the well result demonstrates that the method was proven to determine the gas bearing sand distribution. As a consequence, drilling at a sweet spot location can be optimized. Reservoir fluid identification is a major role in the formation evaluation task. In the field with multiple stack sands and limited water salinity data, will cause more challenging to define fluid type. The result is very substantial to determine hydrocarbon in place, the volume of which will be used to take the decision to develop the gas field. The inherent uncertainty which comprises of sand and hydrocarbon distribution is a real challenge when identifying the sweet spot location in a development drilling campaign. Well log data provides essential information that will use for interpretation of lithofacies and fluid type. The elastic acoustic velocity of the formation taken by sonic tool is a common data that are considered in the petropysical evaluation. In essence, the advantage of ratio of sonic compressional to shear wave velocity is applied to identify gas bearing formations. This is based on the fact that compression wave is more sensitive to type of fluids than the shear wave when it travels into the poro-elastic formations. The same method is also relevant when applied to the seismic data. The seismic Vp/Vs ratio must be first calibrated with well data to provide a proper meaning. Thereafter, the seismic Vp/Vs ratio is exerted to determine gas bearing sand distribution. This information is expected to deliver a great contribution in the well placement optimization. The method is proven to reduce the uncertainty of lateral distribution at shallow reservoirs. The application of this method for deeper reservoir is still being investigated and further detail works will be done to confirm the findings.

OnePetro

doi: 10.2523/IPTC-18705-MS

IPTC

IPTC-18705-MS

International Petroleum Technology Conference

cross plot, data acquisition, development gas field, development well, equation, information, integrated sonic shear compressional ratio, international petroleum technology conference, interpretation, inversion, log analysis, Reservoir Characterization, resolution, seismic inversion, seismic rock physics calibration, structural geology, sweet spot location, Upstream Oil & Gas, well logging

Country:

Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.41)
Asia > Malaysia > South China Sea (0.40)
Africa > Middle East > Egypt (0.28)

Genre: Research Report > New Finding (0.54)

Geophysics:

Geophysics > Seismic Surveying > Seismic Processing (1.00)
Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (1.00)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) > Tapi Field > Malaysia-Thailand JDA > Block B-17 > Tapi Field (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)

Technology: Information Technology (0.95)

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Integrated Sonic Shear Compressional Ratio for Seismic Rock Physics Calibration in the Development Gas Field a Case Study in Tapi Field of North Malay Basin

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