Although the Angsi field is considered to be “lean”, with a maximum liquid dropout of 1.5%, this paper documents substantial productivity impairment as condensate yield increases. The fracture conductivity was improved by substituting 16/30 CARBOPROP® instead of 20/40 HSP. Laboratory testing suggested a 40% increase in effective conductivity at the projected stress level of 7500 psi. In addition to reducing total proppant cost, a four-fold increase in production was obtained with improved fracture conductivity.
Angsi Field, the first tight gas development in Malaysia is being developed for start-up in 2002 to meet gas supply commitments.
Productivity from hydraulically fractured wells and recovery from tight sands are major factors in Angsi development planning. An accurate assessment of the physics of fluid flow dynamics within this type of porous media is critical to project success.
A full-field model was constructed using an in-house reservoir simulation package. The objectives of this study were to assess the uncertainties surrounding the productivity of hydraulically fractured wells, expected gas recovery factors and other factors which could impede productivity and recoveries.
This paper discusses the reservoir simulation results and the optimum case that was used as the basis for the field development planning and describes briefly the pre-drill hydraulic fracture simulation design.
Author(s): Sri Ganesh Gopalakrishnan, SPE and Razli Shawari, Petronas Carigali Sdn Bhd and Kamal Kassim, SPE, SPE, Mohd Naguib Ab Majid, SPE and M Nazri M Nor, Esso Production Malaysia Inc.
Paper Number: SPE 54335