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Collaborating Authors
Gulf of Thailand
Pore Pressure Estimation by Using Machine Learning Model
Booncharoen, Pichita (Chevron Thailand Exploration and Production) | Rinsiri, Thananya (Chevron Thailand Exploration and Production) | Paiboon, Pakawat (Chevron Thailand Exploration and Production) | Karnbanjob, Supaporn (Chevron Thailand Exploration and Production) | Ackagosol, Sonchawan (Chevron Thailand Exploration and Production) | Chaiwan, Prateep (Chevron Thailand Exploration and Production) | Sapsomboon, Ouraiwan (Chevron Thailand Exploration and Production)
Abstract In the past few years, over hundreds of wells were drilled in Gulf of Thailand, had faced with the depletion and lost circulation issues resulted from a lack of pressure data. A prior research of reservoir depletion pressure (Fangming, 2009) in oil field, China was obtained from multivariate statistic and regression by using density and neutron porosity log curves in logging-while-drilling data. However, the relative errors are 7.5% from the actual formation pressure. Thus, there are several latent variables in the model like drilling parameters (Rehm, 1971) which part of formation pressure. From 2018 initiative model in Satun-Funan, the classification model was obtained by using mud gas, porosity, water saturation, net sand thickness, net-hydrocarbon-pore thickness and neutron-density separation. However, the limitation is drilling parameters could not account by classifier, and accurate only original pressure category. So, this study has expanded scope to include other reservoir properties and drilling parameters then applied with machine learning on offset well dataset by using three regressors such quantile, ridge and XGBoost regressors. The pore pressure estimation model aims to improve efficiency for making decision in execution phase, increasing confidence in perforation strategy. The model parameters, pay thickness, porosity, water saturation, original pressure from local pressure profile and total gas show are accounted into this model. As of regressor assumption, some facts are conducted to logarithm and perform 2nd polynomial feature for model flexibility. There are three steps for building model such as data manipulation, analysis and deployment. Two purposes of pressure prediction impact algorithm selection, for operational phase, quantile regressor is implemented to provide conservative prediction while Ridge or XGBoost regressors are alternatives for perforation strategy, provide mid case result of pressure prediction. Overall model performance was measured using root mean square error (RMSE) on train & test dataset which show approximately 1.2 and 1.5 ppg range of accuracy respectively from total 12 drilling projects in Pattani basin. Overall model fitting is within reasonable range of generalization capacity to apply with unknown data point (test set). The future model will continue to improve accuracy and manage imbalanced dataset between original pressure and depleted sands.
Artificial Intelligence, Completion Installation and Operations, drilling operation, drilling parameter, formation pressure, information, international petroleum technology conference, log analysis, machine learning, Model Performance, perforation strategy, Pore Pressure Estimation, prediction, pressure prediction, regression, regressor, Reservoir Characterization, reservoir property, sand thickness, Thickness, Upstream Oil & Gas, water saturation, well logging
Country:
- Asia > Thailand > Gulf of Thailand (0.37)
- North America > United States > Louisiana (0.34)
- Asia > Vietnam > Gulf of Thailand (0.26)
- (5 more...)
Oilfield Places:
- North America > United States > Louisiana > China Field (0.99)
- Asia > Vietnam > Gulf of Thailand > Pattani Basin (0.99)
- Asia > Thailand > Gulf of Thailand > Pattani Basin (0.99)
- (4 more...)
SPE Disciplines:
Technology: Information Technology > Artificial Intelligence > Machine Learning > Statistical Learning (1.00)
A Cambodian concession has commenced production after years of delays in a venture between Singapore's KrisEnergy and the government. The crude comes from oil fields in Block A, comprising 3083 km2 of the Khmer basin in the oil-rich Gulf of Thailand, off the southwestern coast of Sihanoukville. The concession will progress in phases once new wells are commissioned and completed. Kelvin Tang, chief executive of KrisEnergy's Cambodian operations, called the 29 December event "an important strategic milestone" for the company, while Prime Minister Hun Sen hailed the first extraction as "a new achievement for Cambodia's economy" and "a huge gift for our nation." When Chevron found oil in the block in 2004, the kingdom was hailed as the region's next potential petrostate; the government estimated hundreds of millions of barrels of crude beneath its waters.
Country:
- Asia > Cambodia > Preah Sihanouk Province > Sihanoukville (0.27)
- Asia > Cambodia > Gulf of Thailand (0.27)
First steel has been cut for the minimum facilities wellhead platform (Mini-Platform) for Apsara, the first oilfield development offshore Cambodia. The Apsara field in Cabodia Block A lies over the Khmer Basin in the Gulf of Thailand. KrisEnergy, the operator of the field, said that, due to the unproven production performance of the basin, Apsara will be developed in several phases to mitigate risk. The initial Mini Phase 1A simplifies the original Phase 1A development with a smaller platform, fewer initial development wells, and the use of leased shuttle tankers as opposed to the original plan for a permanent floating storage and offloading vessel (FSO). The Mini-Platform under development is a similar structure to the original 24-slot platform, except that it is smaller and houses fewer wells.
SPE Disciplines: Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems (1.00)
First steel has been cut for the minimum facilities wellhead platform for the Apsara field offshore Cambodia, the country's maiden oil development. Operator KrisEnergy said production is scheduled to begin in the first half of 2020.
How to Obtain Quality PVT Samples for Heavy Oils in the South East Asia Region
Platt, Chris J. (KrisEnergy) | Chevarunota, Natasha (KrisEnergy) | Taksaudom, Pongpak (KrisEnergy) | Daungkaew, Saifon (Schlumberger) | Duangprasert, Tanabordee (Schlumberger) | Khunaworawet, Tanawut (Schlumberger) | Lerdsuwankij, Thiti (Schlumberger) | Wattanapornmongkol, Sawit (Schlumberger) | Thongpracharn, Payap (Schlumberger)
Abstract Exploration activity is always associated with many challenges such as uncertain pore pressure, and uncertain formation depths and characteristics. Unconsolidated formation could cause more serious troubles for drilling, formation evaluation, and production such as borehole washout, wellbore collapse, and sanding if proper planning is not in place. In addition, a viscous oil can add another complication for fluid sampling operations. An unsuccessful logging program could have a major impact on the field development plan (FDP) and further field investment decision (FID). In the Gulf of Thailand (GoT), high temperature Pattani basin discovery wells, reservoir fluids are mainly gas and condensate. There are numbers of waxy oil reservoirs1–5 in certain area in the GoT, notably in the cooler peripheral Tertiary basins. However, the subject field is the first one that was identified as having productive heavy oil reservoirs. The viscosity variation ranges between 1 and 100 cp2–6. It was observed that there was a depth related variation with deeper reservoirs having higher viscosities, and therefore, reservoir fluid information is crucial for the FDP and FID resulting from a field extension drilling campaign in early 2018. This paper will discuss step by step (1) reservoir characterization challenges (2) proposed methods to obtain reservoir and fluid information, as well as the interval pressure transient test, (3) the actual field results, (4) recommendations and way forward for similar reservoirs. Different proposed options are also discussed with field examples to obtain high quality PVT samples. Pumping to clean up high viscous oil contaminated tends to attract finer particulates towards the probe and into the flowline, causing plugging issues in other probe types even though a modified sand filter was added. In the end, the 3D Radial probe was proven in making this exploration campaign a success story for acquiring the heaviest oil samples to date in the GoT. The 3D Radial probe equipped with mesh filter plays an important role to restrict ingress of small sand particles, thereby allowing both sustainable pumping speed and flowing pressure. The single packer design also helps to support the formation preventing drawdown collapse. Coupled with larger flow area of the probe itself, the 3D Radial Probe has ability to control flowing pressure to stay above the sand break-away pressure even as more viscous formation oil enters. However, job objectives were achieved, which were formation pressure acquisition, high-quality fluid sampling, and Interval Pressure Transient Testing (IPTT) as well as Vertical Interference Testing (VIT). This paper also discusses the comparison between Downhole Fluid Analysis results and PVT lab analyses. Limitation and challenges for downhole measurements for this heavy oil environment. Advantages and disadvantages for different testing methods for this heavy oil reservoir will also be discussed.
bitumen, complex reservoir, Daungkaew, Drillstem Testing, drillstem/well testing, Exhibition, flowline, information, international petroleum technology conference, IPTT, log analysis, mobility, objective, obtain quality pvt sample, Offshore Technology Conference, oil sand, pressure transient analysis, pressure transient testing, Probe, PVT measurement, Reservoir Characterization, sand 2, sand particle, Saturn probe, Technology Conference, Thailand, Upstream Oil & Gas, viscosity, well logging
Country:
- Asia > Vietnam > Gulf of Thailand (0.24)
- Asia > Thailand > Pattani > Pattani (0.24)
- Asia > Thailand > Gulf of Thailand (0.24)
- (3 more...)
Oilfield Places:
- South America > Venezuela > Anzoátegui > Eastern Venezuela Basin > Maturin Basin > Cerro Negro Area Field (0.99)
- Asia > Vietnam > Gulf of Thailand > Pattani Basin (0.99)
- Asia > Thailand > Gulf of Thailand > Pattani Basin (0.99)
- (3 more...)
SPE Disciplines:
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Pressure transient analysis (1.00)
- (3 more...)
How to Obtain Quality PVT Samples for Heavy Oils
Platt, Chris (KrisEnergy) | Chevarunota, Natasha (KrisEnergy) | Taksaudom, Pongpak (KrisEnergy) | Daungkaew, Saifon (Schlumberger) | Duangprasert, Tanabordee (Schlumberger) | Khunaworawet, Tanawut (Schlumberger) | Thiti Lerdsuwankij, Thiti (Schlumberger) | Wattanapornmongkol, Sawit (Schlumberger) | Thongpracharn, Payap (Schlumberger)
Abstract Exploration activity is always associated with many challenges such as uncertain pore pressure, and uncertain formation depths and characteristics. Unconsolidated formation could cause more serious troubles for drilling, formation evaluation, and production such as borehole washout, wellbore collapse, and sanding if proper planning is not in place. In addition, a viscous oil can add another complication for fluid sampling operations. An unsuccessful logging program could have a major impact on the field development plan (FDP) and further field investment decision (FID). In the Gulf of Thailand (GoT), high temperature Pattani basin discovery wells, reservoir fluids are mainly gas and condensate. There are numbers of waxy oil reservoirs1–5 in certain area in the GoT, notably in the cooler peripheral Tertiary basins. However, the subject field is the first one that was identified as having productive heavy oil reservoirs. The viscosity variation ranges between 1 and 100 cp2–6. It was observed that there was a depth related variation with deeper reservoirs having higher viscosities, and therefore, reservoir fluid information is crucial for the FDP and FID resulting from a field extension drilling campaign in early 2018. This paper will discuss step by step (1) reservoir characterization challenges (2) proposed methods to obtain reservoir and fluid information, as well as the interval pressure transient test, (3) the actual field results, (4) recommendations and way forward for similar reservoirs. Different proposed options are also discussed with field examples to obtain high quality PVT samples. Pumping to clean up high viscous oil contaminated tends to attract finer particulates towards the probe and into the flowline, causing plugging issues in other probe types even though a modified sand filter was added. In the end, the 3D Radial probe was proven in making this exploration campaign a success story for acquiring the heaviest oil samples to date in the GoT. The 3D Radial probe equipped with mesh filter plays an important role to restrict ingress of small sand particles, thereby allowing both sustainable pumping speed and flowing pressure. The single packer design also helps to support the formation preventing drawdown collapse. Coupled with larger flow area of the probe itself, the 3D Radial Probe has ability to control flowing pressure to stay above the sand break-away pressure even as more viscous formation oil enters. However, job objectives were achieved, which were formation pressure acquisition, high-quality fluid sampling, and Interval Pressure Transient Testing (IPTT) as well as Vertical Interference Testing (VIT). This paper also discusses the comparison between Downhole Fluid Analysis results and PVT lab analyses. Limitation and challenges for downhole measurements for this heavy oil environment. Advantages and disadvantages for different testing methods for this heavy oil reservoir will also be discussed.
bitumen, complex reservoir, Daungkaew, Drillstem Testing, drillstem/well testing, Exhibition, flowline, fluid sampling, information, international petroleum technology conference, IPTT, log analysis, objective, obtain quality pvt sample, oil sand, packer, Petroleum Engineer, pressure transient analysis, pressure transient testing, Probe, Reservoir Characterization, sand particle, Saturn probe, sidetrack well, Thailand, Upstream Oil & Gas, viscosity, well logging
Country:
- Asia > Vietnam > Gulf of Thailand (0.24)
- Asia > Thailand > Pattani > Pattani (0.24)
- Asia > Thailand > Gulf of Thailand (0.24)
- (3 more...)
Oilfield Places:
- Asia > Vietnam > Gulf of Thailand > Pattani Basin (0.99)
- Asia > Thailand > Gulf of Thailand > Pattani Basin (0.99)
- Asia > Myanmar > Gulf of Thailand > Pattani Basin (0.99)
- (2 more...)
SPE Disciplines:
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Pressure transient analysis (1.00)
- (3 more...)
Abstract Detailed knowledge of fill-spill history and charge entry points to fields is rarely available, due to lack of suitable data sets and methodologies. This paper describes the application of a reservoir geochemical work flow (multi-variate statistical analysis of geochemical data) to unravel the fill history of a highly complex oil field in the northern Gulf of Thailand, and the implications of these results in assessing charge risk in adjacent and near-field prospects. The Jasmine-Ban Yen field, Pattani Trough, Gulf of Thailand, produces from stacked Middle to Late Miocene clastic reservoirs, draped over a highly faulted structural nose. In an earlier study, 59 oils from across the field underwent standardised fingerprinting, biomarker and bulk isotope analysis. Here, geochemical parameters considered resistant to secondary processes such as biodegradation, underwent hierarchical cluster analysis and classification into fluid families. Distinct families potentially represent fluids that share a common history. The results were synthesised with spatial information, seismic data, reservoir pressures, petroleum systems modelling, and observations drawn from the field's production history, to elucidate the fill-spill history of the field. All oils were expelled from similar lacustrine organofacies at similar maturity, which is broadly consistent with a single source pod charging the field. The closest mature kitchen is thought to be located in the Northern Pattani Trough, some 20 to 25 km to the south. A sub-regional Middle Miocene lacustrine seal, the "hot shale," focusses oil into the Jasmine-Ban Yen field, and forms the seal for 30% of the STOIIP. Fluids also occur in reservoirs above this seal, which could be emplaced either through vertical fill and spill via high offset faults, possibly aided by locally high CO2 increasing buoyancy pressure by formation of a gas cap, or laterally, via spill from adjacent fault blocks. Detailed knowledge of charge history remains elusive; however, the occurrence of consistently different fluid families above and below the hot shale seal, with fluids below represented by consistent families over a lateral distance of 12 km, supports an interpretation of multiple entry points into the field. Aromatic maturity parameters indicate that four Ban Yen samples are of slightly elevated maturity, suggesting that late charge accesses the field above the hot shale. The possibility that the differences between families are related to biodegradation was investigated and discarded. Families probably represent discrete, lateral spill pathways reflecting multiple charge entry points and are differentiated by subtle variations in organofacies related to oxicity and contribution from plant material. Comparable migration above and below the hot shale into B5/27 is a possibility, and exploration prospectivity is risked accordingly. Placing statistically derived fluid families into a spatial, geological and production context enables unravelling of migration vectors in complex fields. Furthermore, inferences may be drawn from such a study that can help guide risk assignment to offset exploration prospectivity.
Artificial Intelligence, biodegradation, entry point, fluid family, geochemical characterization, hot shale, Hydrocarbon Migration, jasmine-ban yen field, lower reservoir, machine learning, maturity, migration, organofacies, reservoir, Reservoir Characterization, statistical analysis, structural geology, superfamily, Thailand, Upstream Oil & Gas, variation
Country:
- Asia > Thailand > Gulf of Thailand (0.70)
- Asia > Vietnam > Gulf of Thailand (0.55)
- Asia > Myanmar > Gulf of Thailand (0.55)
- (3 more...)
Oilfield Places:
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Dampier Basin > WA-20-L > Legendre Field > Angel Formation (0.99)
- Asia > Vietnam > Gulf of Thailand > Pattani Basin (0.99)
- Asia > Myanmar > Gulf of Thailand > Pattani Basin (0.99)
- (3 more...)
SPE Disciplines:
Abstract It has been recognized from the early stages of exploration in the 1980s that gas bearing reservoirs with condensates were located at depths of approximately 4,000 to 5,000 feet in parts of the Pattani Trough, Gulf of Thailand. However, even though the entire pay window is evaluated for each prospect area, no regional study on the shallow hydrocarbons has been made due to the majority of hydrocarbons residing in deeper zones. In the Gulf of Thailand there are two major Cenozoic sedimentary basins, the Pattani Trough and the Malay Basin. In the Pattani Trough, commercial production started at the Erawan gas field in 1981 and subsequently more than 20 oil and gas fields have been discovered and have continued producing hydrocarbons at the current date. The Pattani Trough is a rift type-sedimentary basin and the maximum thickness of sediments is more than 10 km. The geological column is divided into five sedimentary units from Sequence 1 to 5 in ascending order. Two major unconformities are identified: one is called the Middle Cenozoic Unconformity (MCU) and the Middle Miocene Unconformity (MMU). The latter unconformity is located between Sequence 4 and Sequence 5. Oil and gas are mainly trapped in fluvial to deltaic sandstones of Sequence 3 and Sequence 4 located between 5,000 to 9,000 feet. Structure is characterized by many normal faults. Based on the more than 800 wells and 3D seismic data, detailed studies on well correlation, dip-meter, micropaleontology, regional isopachs and sand-shale ratio were made and it was concluded that the these shallow hydrocarbons are closely related to the incised valley-fill sediments located in the lower part of Sequence 5 immediately above the MMU. Hydrocarbons generated in the deeper levels have migrated upward through faults and moved into and are possibly trapped in the incised shallow reservoirs. Previous wells were drilled in the highly faulted areas where most of the oil and gas is trapped and there are no wells drilled in the monocline areas. Although the detailed areal distribution of the incised valleys is not clearly identified, hydrocarbons are expected in monocline areas if conditions are favorable. Since the MMU is widely developed in the South East Asia, this type of exploration concept focusing shallow hydrocarbons can be applied not only for the undrilled area of the Pattani Trough but also for the mature sedimentary basins such as the Malay and Nam Con Son basins.
Country:
- Asia > Vietnam > Gulf of Thailand (1.00)
- Asia > Thailand > Pattani > Pattani (1.00)
- Asia > Thailand > Gulf of Thailand (1.00)
- (3 more...)
Geologic Time:
- Phanerozoic > Cenozoic > Paleogene (1.00)
- Phanerozoic > Cenozoic > Neogene > Miocene > Serravallian (0.35)
- Phanerozoic > Cenozoic > Neogene > Miocene > Langhian (0.35)
Oilfield Places:
- North America > Canada > Saskatchewan > Western Canada Sedimentary Basin > Alberta Basin > Viking Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Viking Formation (0.99)
- Asia > Thailand > Gulf of Thailand > Pattani Basin > Contract Area 2 > Satun Field (0.99)
- (10 more...)
SPE Disciplines: Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Gulf of Thailand Super Cube - Technical Challenges in the Reprocessing of 40 3D Seismic Surveys, 15000sq.km.
Phan, Ying Peng (CGGVeritas) | Lee, Kok Moo (CGGVeritas) | Soh, Kim Kee (CGGVeritas) | Sun, Jason | Livesay, George Allen (Chevron Corp.) | Hsiao, Helmut (Chevron) | Jitharn, Kantarakorn (Chevron)
Abstract In early 2008, Chevron Thailand and partners contracted CGGVeritas to reprocess forty of their key 3D seismic surveys in the Pattani Basin, Gulf of Thailand, with a combined area of more than 15,000 sq.km. The 40 surveys had been acquired over a period of 26 years (1979 to 2005) with variable acquisition parameters, geometries and azimuths, which resulted in variable amplitude and frequency content and variable fold or sampling density. The benefit of the reprocessing is enormous, but the technical challenges are just as great. In this paper we present some of the technical challenges and solutions in the data processing work. A) Detecting and correcting navigation errors in vintage data. Old surveys tend to have navigation errors. Some errors are not obvious until merging with adjacent surveys. We show how we detect the errors and correct them. B) Data regularization. The data of the 40 surveys were loaded into common grid and offset slots for imaging. A challenge is to bridge any acquisition gaps caused by existing platforms at the time of acquisition. Using advanced interpolation technology, we filled in gaps as wide as 350m. C) Offset-dependent matching of frequency bandwidth, amplitude, time and phase between surveys. We present a workflow that was tested and implemented successfully. D) Fault imaging. We show how fault imaging was improved by incorporating anisotropy in migration. Introduction The Gulf of Thailand Super Cube project in the Pattani Basin was initiated and financed by Chevron Thailand, and carried out by CGGVeritas over a period of 3 years. The project area is shown in Figure 1. The 40 3D seismic surveys cover approximately 15,000 sq. km. Prior to the current project, the data had been processed individually or in small groups for use in interpreting individual field areas. The primary objective of the reprocessing was to produce superior seismic imaging by making use of more advanced processing technology, and by making use of neighbouring surveys as migration aperture input. Specifically, the reprocessing aimed to accurately define the principal faults, and to broaden bandwith for high resolution definition of the reservoirs and near water bottom reflectors for the assessment of drilling hazards. The reprocessing also brought about other benefits, which include: regional consistency with DHI or AVO assessment; continuous regional interpretation and data management; fewer seismic volumes to manage; reducing the number of (redundant) faults and horizons in the database; and conveniently working in multiple field areas without the need to switch seismic workstation projects during an interpretation session. The 40 surveys were acquired over a time span of 26 years (1979 to 2005) with variable acquisition parameters, geometries and azimuths, which resulted in variable amplitude and frequency content and variable fold or sampling density. To merge them seamlessly requires great effort in spectral conditioning, time/phase matching, and AVO characteristics preservation. In addition, for some vintage surveys, essential information such as source signature, accurate navigation and well preserved trace data could be missing or incomplete. The essential information had to be cross-examined and reconstructed to facilitate the reprocessing.
acquisition, amplitude, conditioning, correction, estimation, grid, information, international petroleum technology conference, interpolation, matching, migration, navigation data, reprocessing, Reservoir Characterization, seismic survey, technical challenge, thailand super cube, time shift, Upstream Oil & Gas
Country:
- Asia > Vietnam > Gulf of Thailand (0.45)
- Asia > Thailand > Pattani > Pattani (0.45)
- Asia > Thailand > Gulf of Thailand (0.45)
- (3 more...)
Geophysics:
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (0.91)
Oilfield Places:
- Asia > Vietnam > Gulf of Thailand > Pattani Basin (0.99)
- Asia > Thailand > Gulf of Thailand > Pattani Basin (0.99)
- Asia > Myanmar > Gulf of Thailand > Pattani Basin (0.99)
- (2 more...)
SPE Disciplines: Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Evaluation of Factors in Horizontal Well Recovery in the Pattani Basin in the Gulf of Thailand
Harr, Michael Scott (Chevron Thailand E&P Ltd) | Chokasut, Siriporn (Chevron Thailand E&P Ltd) | Bhuripanyo, Chanapol (Chulalongkorn U.) | Viriyasittigun, Pattra (Chevron Thailand E&P) | Harun, Abd Rahman (Chevron Corp.)
Abstract The Gulf of Thailand (GoT) is south of Bangkok. The pay interval typically covers 3000 to 5000 vertical feet. It is composed of a series of stacked fluvial point bars sands that have limited areal extent. In addition, normal faulting breaks them up further. Because all 40 acre wells will be drilled at some point, the justification for drilling a horizontal well is based on incremental recovery over vertical wells. In 2010, a team was assembled to look at establishing a common method to evaluate horizontal wells. Production results from horizontal wells were compared to vertical wells. Concept models were used to evaluate different factors in horizontal well recovery. Where available, history matched simulation models were used to compare horizontal to vertical wells. In addition, the team looked at factors in horizontal well performance. The team collected information on all wells drilled. The team looked for relationships to EUR and recovery factor. Then, the team took a more in depth study of the best horizontals and the worst horizontals. The overall recovery factor averages 20% for horizontal wells and 12.5% for an equivalent vertical well. The average incremental is 7.5%. There are three sources for this difference. The first is improved areal sweep efficiency of a horizontal well. The second is lower abandonment pressure with deep gas lift valves than with a vertical well. In looking at the best and worst performing horizontal wells, the poorer wells were in small reservoirs, often drilled very close to contacts and some were drilled into depleted reservoirs. The best wells were drilled in large very continuous reservoirs and often had strong reservoir drive (either water drive or gas cap expansion). Description The Gulf of Thailand (GoT) is south of Bangkok. Figure 1 is a map of the Gulf of Thailand. The pay interval typically covers 3000 to5000 vertical feet. It is composed of a series of stacked fluvial point bars sands that have limited areal extent. In addition, normal faulting breaks them up further. The overall development strategy is to drill wells on equal spacing (40 acres) on the high side of the faults to encounter as many sands as possible. Figure 2 illustrates the stratagraphic and structural complexity. Chevron has drilled over 80 horizontal wells in the GoT with an average of about 5–10 every year. The targets are oil reservoirs that are at least 25 feet thick. By nature of the depositional and structural setting, these are relatively small reservoirs, usually with OOIP between 0.7 to 6.0 MMBO. The sands can have both a GOC and an OWC. Because all 40 acre wells will be drilled at some point, the justification for drilling a horizontal well is based on incremental recovery over vertical wells. Because the horizontal well design and execution plans are typically developed during the same drilling programs of vertical wells, a quick and reliable method of horizontal well evaluation is needed. In 2010, as part of the Reservoir Management Framework, a team was assembled to look at establishing a common method to evaluate horizontal wells. As part of this initiative, the team looked at factors in horizontal well performance. The study also included a comparison to vertical wells. The team used a multi faceted approach. Production results from horizontal wells were compared to vertical wells. Concept models were used to evaluate different factors in horizontal well recovery. Where available, history matched simulation models were used to compare horizontal to vertical wells.
abandonment pressure, Directional Drilling, drilling operation, Gulf, horizontal well, Horizontal Well Recovery, incremental recovery, international petroleum technology conference, Modeling & Simulation, Pattani Basin, Performer, poorest performer, recovery factor, reservoir, Thailand, Upstream Oil & Gas, vertical well, well planning
Country:
Oilfield Places:
- Asia > Vietnam > Gulf of Thailand > Pattani Basin (0.99)
- Asia > Thailand > Gulf of Thailand > Pattani Basin (0.99)
- Asia > Myanmar > Gulf of Thailand > Pattani Basin (0.99)
- (2 more...)
SPE Disciplines:
- Well Drilling > Well Planning (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Reservoir Description and Dynamics (1.00)
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