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Abstract

A multidisciplinary teamwork approach has been taken to plan the development and execution of a greenfield gas project offshore Peninsular Malaysia. Domestic demand for gas in Peninsular Malaysia remains strong mainly to fuel growing electricity demand. Timely execution of the T Gas Development project is critical to supplementing declining capacity from existing developed fields and ensuring the ability to meet gas supply obligations. The T field is a faulted, compressional anticline comprised of lower to middle Miocene sandstone reservoirs. The major reservoir in T consists of shallow, fluvio-deltaic to near-shore marine sediments containing a dry, non-associated gas. Discrete channel meanders and faulted segments within the field contribute to uncertainties in reservoir connectivity and compartmentalization. Incorporation of conventional seismic volumes with a derivative sand/shale indicator volume, and combined with an understanding of the environment of deposition and seismic stacking geometries, were used to better capture the range of predictive uncertainty in the lateral and vertical heterogeneities observed in the seismic data. Installation of down-hole pressure gauges in the production wells are expected to increase understanding of dynamic reservoir connectivity during production. Due to shallow reservoir burial depth, the development wells were designed with ERD (extended reach drilling) ratios of up to 2.9 in order to optimize well placement and reserves capture. Furthermore, installation of downhole sand control in these high-angle wells will be challenging, but is critical to ensure production sustainability and minimize future wellbore interventions. Alternate Path Technology (APT) screens will be utilized to ensure successful frac pack completions at high well angles. The T Field project utilizes the ‘Design One, Build Multiple’ concept via replication of proven design components to optimize cost and schedule. This paper describes key challenges for T Field development planning, including managing reservoir compartmentalization and connectivity uncertainties, optimizing well design, and the use of 7” tubing completions in high quality sands to maximize well deliverability and meet gas supply requirements with optimum well count for reserves capture. Early stakeholder-alignment and detailed execution planning have been pursued to meet aggressive project schedule reflecting the need to rig-up before monsoon season and to tie into a major gas compression hub during a limited shut-down window.

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/content/papers/10.3997/2214-4609-pdb.350.iptc16877
2013-03-26
2022-11-28
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