Multilateral Horizontal Well Increases Liquids Recovery in the Gulf of Thailand
- M.J. Horn (Total Exploration And Production Thailand) | D.P. Plathey (Total Exploration And Production Thailand) | O. Ibrahim (Total Exploration And Production Thailand)
- Document ID
- Society of Petroleum Engineers
- SPE Drilling & Completion
- Publication Date
- June 1998
- Document Type
- Journal Paper
- 78 - 87
- 1998. Society of Petroleum Engineers
- 1.11.2 Drilling Fluid Selection and Formulation (Chemistry, Properties), 3 Production and Well Operations, 1.10 Drilling Equipment, 2.4.3 Sand/Solids Control, 1.6 Drilling Operations, 5.6.4 Drillstem/Well Testing, 1.5 Drill Bits, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 5.2 Reservoir Fluid Dynamics, 2 Well Completion, 1.6.2 Technical Limit Drilling, 5.1.1 Exploration, Development, Structural Geology, 5.5 Reservoir Simulation, 3.2.2 Downhole intervention and remediation (including wireline and coiled tubing), 1.12.1 Measurement While Drilling, 5.5.8 History Matching, 4.1.5 Processing Equipment, 1.14 Casing and Cementing, 5.1.2 Faults and Fracture Characterisation, 4.1.2 Separation and Treating, 1.11 Drilling Fluids and Materials, 1.6.6 Directional Drilling, 5.1.5 Geologic Modeling, 5.2.1 Phase Behavior and PVT Measurements, 4.5 Offshore Facilities and Subsea Systems, 2.2.2 Perforating
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This paper describes the objectives, the completion and the first results of the dual-horizontal well BK-4-M drilled in May 1996 in the Bongkot field. The main objective of BK-4-M was to maximize the recovery from a shallow and thin oil rim by delaying the water breakthrough by two years and maintaining a flow rate of 4000 bbl/d. The final recovery will be increased by three times in comparison to a conventional deviated well. BK-4-M completion was a challenge in terms of planning, technically and economically. Well BK-4-M was successfully put on stream in July 1996 with a potential flow rate of 4000 bbl/d. The duration of operations was 21 days' including completion. Each of the two horizontal branches has a length of about 1 000m and is located in the upper third of the 10m-thick oil rim. BK-4-M cost was 1.70 times higher than a conventional single drain deviated well, and is expected to triple recovery, using only one platform slot. It is the first dual-horizontal well ever completed in South-East Asia.
Bongkot Field. The field is situated offshore in the Gulf of Thailand 600 kilometres (km) south of Bangkok and 180 km off the coast of Songkhla province (Fig. 1). Following discovery of the field in 1973, it was delineated by drilling 23 wells.
In 1990 the concession development rights were transferred to a Joint Venture Group comprising of PTT Exploration and Production Public Company Ltd. (40%), Total Exploration and Production Thailand (Operator, 30%), British Gas Thailand Ltd. (20%) and Statoil Thailand Ltd. (10%).
Since the start of the development phase of the field 114 wells have been drilled, of which two thirds have been development wells and one third delineation wells. The development wells are drilled from 12 slot wellhead platforms, using a self erecting tender barge. A rig package is installed on the platforms for the duration of drilling and completion operations. Further well interventions are performed without the rig.
The production from the remote platforms is transported to a central processing platform for treatment. Gas is piped to shore and liquids stored on a floating storage and offshore-loading facility. Liquid export is via shuttle tanker.
By mid 1996 gas production from the field was 350 million standard cubic feet per day (MMscf/d), with 8,000 barrels per day (bbl/d) of condensate.
Geological Context. As currently delineated, the field extends over an area of 450 square km, with a length of 70 km and a width of 5 km to 12 km. Proven reserves were certified at 3 trillion standard cubic feet in 1994. Water depth over the field varies between 75 and 80 metres (m).
The hydrocarbon reserves are found in multi-faulted sandstone reservoirs of the Oligocene and Miocene Age, deposited in fluvio-deltaic and coastal environments. These reservoirs are found over a large range of true vertical depth (TVD) from 1000 to 3000m below mean sea level (msl). All reservoirs developed to date have had a hydrostatic pressure regime.
The majority of the hydrocarbon bearing reservoirs contain gas and associated condensate. However, in certain reservoirs, significant oil rims have been identified as underlying the gas column. Oil columns up to 15m thick have been identified. Channels which will contain oil rims are difficult to predict and drilling and logging is the only method to prove the presence of liquid hydrocarbon.
The largest oil accumulation identified to date is in a structure known as the 10-90 A (Fig. 2). This structure was the candidate reservoir for the horizontal well BK-4-M.
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