The Cal Canal Field, situated in the San Joaquin Valley near Bakersfield, California, produces, a rich (280 bbl/MMSCF) gas condensate from an average depth of 11,500 feet. The upper Miocene Stevens Sand, the producing formation in the field, is a very tight, abnormally pressured gas condensate reservoir. The average reservoir parameters are 12 percent porosity, .01 to .1 md permeability and a connate water saturation of 59%. The dew point pressure of 5835 psi is 1508 psi below the initial reservoir pressure. The material balance method, corrected for abnormal pressure, indicates an original wet gas-in-place of 103.3 BSCF. Production performance history suggests that the ultimate recovery from the field will be approximately ±10% of the original wet GIP. Such a poor recovery could be attributed to retrograde fallout and increasin; water saturation in the vicinity of the wellbores.

This paper presents an analysis of the reservoir characteristics and a review of its performance to date. The purpose of the study was to investigate the feasibility of improving hydrocarbon recovery from the field.

Keywords:
cal canal field, production monitoring, wellbore, water saturation, reservoir, permeability, condensate reservoir, average reservoir pressure, reservoir pressure, stevens sand
Subjects:
Hydraulic Fracturing, Artificial Lift Systems, Well & Reservoir Surveillance and Monitoring, Reservoir Characterization, Fluid Characterization, Reservoir Fluid Dynamics, Improved and Enhanced Recovery, Reservoir Simulation, Formation Evaluation & Management, Reserves Evaluation
Copyright 1985, Society of Petroleum Engineers
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