Economic Optimization of a Development Program for a Low-Permeability Reservoir
- R.N. Hodgson (Continental Oil Co.) | G.C. Clark (Continental Oil Co.) | M.D. Rowe
- Document ID
- Society of Petroleum Engineers
- Journal of Petroleum Technology
- Publication Date
- March 1961
- Document Type
- Journal Paper
- 231 - 235
- 1961. Original copyright American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. Copyright has expired.
- 3.2.3 Hydraulic Fracturing Design, Implementation and Optimisation, 5.2 Reservoir Fluid Dynamics, 5.7.5 Economic Evaluations, 4.1.5 Processing Equipment, 4.1.2 Separation and Treating, 2.4.3 Sand/Solids Control, 5.6.4 Drillstem/Well Testing, 2 Well Completion, 4.1.9 Tanks and storage systems, 1.6 Drilling Operations, 5.2.1 Phase Behavior and PVT Measurements
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To evaluate the development of the Sacatosa field, Maverick County, Tex., which is a marginal reserve field, a complete computer study was made. The computer phase of the work was performed to determine, first, if the field could be economically developed and, if so, to determine the best completion methods and well-spacing patterns to use.
To answer these questions, a numerical solution of the two-phase flow equations developed originally by Muskat, the Howard-Fast equation for fracture extension, and an economic computer simulation model for analysis of the various economic factors involved in a fieldwide development program were utilized.
Prior to any of the computer work, it was necessary to conduct an extensive field-testing program to gather sufficient data for the various computer phases. This testing involved primarily the determination of initial reservoir pressure, producing bottom-hole pressure and obtaining representative fluid samples. Considerable emphasis was also placed on obtaining accurate producing GOR's; and, as a result, special metering separators were installed on three test wells. Field data also were obtained which indicated the fracture techniques used yield horizontal, single-plane fractures.
Additional data (Table 1) also were available on the reservoir properties, plus the early producing rates from a series of test wells drilled to aid evaluation of the field.
Three wells were drilled in 1957 to initially evaluate the field. One of these wells was unfractured and never attained production greater than 8 B/D, and this only after stimulation with 150 quarts of nitroglycerin. The other two wells were fractured - one with a 66,690-gal, single-plane treatment and the second with a dual-plane treatment, one of 17,640 gal and the other of 51,000 gal of lease crude with 1 lb of 20-40 mesh sand/gal. At the time of the computer study, these wells were the only ones available to provide any indication of production trends for an extended period. As a result, these wells were tested to provide producing bottom-hole pressures so that a check point would be available in solving the flow equations, that is, producing bottom-hole pressure after about 10,000 bbl of stock-tank oil production at an average rate of 18 B/D.
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