Reservoir Characterisation of the Mid Miocene Reservoirs of the North Malay Basin, Joint Malaysian Thailand Development Area (MTJDA)
- Steve Carney | Duncan Charles Barr (Sedigon Consultants LLC) | Shinta Ni Chai (Hess Oil & Gas) | Libny A. Leal (Hess Corp.) | Mohd Farif Abu Bakar (Hess Oil & Gas)
- Document ID
- Society of Petroleum Engineers
- SPE Asia Pacific Oil and Gas Conference and Exhibition, 20-22 October, Perth, Australia
- Publication Date
- Document Type
- Conference Paper
- 2008. Society of Petroleum Engineers
- 2.2.2 Perforating, 1.12.2 Logging While Drilling, 2.4.3 Sand/Solids Control, 5.6.4 Drillstem/Well Testing, 5.1.5 Geologic Modeling, 5.1 Reservoir Characterisation, 1.6.9 Coring, Fishing, 5.3.4 Integration of geomechanics in models, 4.1.5 Processing Equipment, 5.1.3 Sedimentology, 7.2.2 Risk Management Systems, 3.3.1 Production Logging, 5.6.1 Open hole/cased hole log analysis, 1.14 Casing and Cementing, 5.1.4 Petrology, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 1.2.3 Rock properties, 5.1.7 Seismic Processing and Interpretation, 5.5.11 Formation Testing (e.g., Wireline, LWD), 5.6.2 Core Analysis, 5.5.2 Core Analysis, 5.5 Reservoir Simulation, 5.1.1 Exploration, Development, Structural Geology, 4.3.4 Scale, 5.7.2 Recovery Factors
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The Cakerawala, Bulan, Bumi and Suriya gas fields in the MTJDA, northern Malay Basin form a major new development hub for the region, with an estimated total GIIP of 9 Tcf. These large assets are very early in their field life with only 300 Bcf of production from Cakerawala field so far. There has however already been significant (USD 1-2 billion) development investment. There is significant subsurface uncertainty due to geological complexities and a detailed, integrated data gathering and interpretation effort was necessary to better understand the asset. The impact of the study is a deeper understanding of the fields' potential and an insight into how to optimally develop these complex resources. This study covers many aspects of the reservoir characterisation process with examples from the North Malay Basin and has application in other complex fields.
The subsurface geology comprises a thick interval (more than 7,000 ft) of stacked, clastic, fine grained, often clay-rich reservoirs, deposited in an upper delta plain to shallow marine environment. Significant challenges exist in developing these fields due to the large development area, thick zones of interest, large number of reservoirs and challenging depositional setting. There are also petrophysical issues to overcome, including fine scale reservoir heterogeneity, complex mineralogy and the presence of low-resistivity low-contrast (LRLC) pay.
An improved understanding of the factors controlling reservoir quality was achieved by adopting a holistic and multidisciplinary approach. This included the integration of stratigraphic, depositional and lithofacies information along with mineralogical and pore system data.
Key lessons learnt include the importance of acquiring good subsurface rock data and the construction of robust databases. The novel application of Lorenz plots and Winland R35 analysis calibrated to test data provided key rock quality and heterogeneity information for inclusion in geo-engineering models. The definition of LRLC reservoirs proved to be an important milestone which led to the development of a water saturation cut-off for gas-productive reservoirs. These findings are now being incorporated into our forward development strategies in Block A-18 and other assets. Success was achieved on a highly complex problem due to the application of an integrated, multi-disciplinary work flow.
The study area is located in Block A-18 within the Malaysia-Thailand Joint Development Area (MTJDA), in the northern Malay Basin. Miocene sediments were studied in four fields, Cakerawala, Bulan, Bumi and Suriya (Fig. 1). Structurally the fields form part of the Central Inversion Zone (CIZ), which is characterised by north-south trending horst and graben features. The Miocene hydrocarbon system within the study area is well documented (Madon et al., 1999; Madon et al., 2006) and consists of a thick interval (more than 7,000 ft) of interbedded sands and shales with abundant source-rich shales and coals. Not all the source rocks within the study areas are mature enough to have generated hydrocarbons, therefore some reservoirs rely on vertical migration via faults from deeper, more mature source rocks. Reservoir quality is typically moderate to
excellent for gas. The Miocene sediments have been grouped into genetic sequences (0 to XV) based on flooding surfaces, sequence boundaries and regional markers.
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