Large Frac jobs may unlock tight reservoirs. Pt. 2

Journal Article · Tue May 04 00:00:00 EDT 1971 · Oil Gas J.; (United States)

OSTI ID:5518406

Holditch, S A; Morse, R A

This second part of a 2-part article deals with results of the numerical model study. For each method of stimulation, the early pressure-distribution changes were very rapid. The magnitude of these changes was a function of the surface area of the fracture or cavity that was exposed to the formation. The flow rates during this portion of the production history for each well were changing rapidly. After the formation flanking, the fracture or cavity had been depleted to essentially the well-bore pressure. The pressure distribution in the reservoir began changing much more slowly and uniformly. The flow rate monitored during this later portion of the production history for each well is referred to as stabilized flow rate. The system was not a steady state; but the flow rates, being controlled by the constant well-bore pressure and the reservoir pressure beyond the fracture or cavity, declined at rates corresponding to the reservoir-pressure decline. for the 3 reservoir situations modeled, the flow rates of the 5 stimulated wells are plotted. Tabular data show (1) comparison of average flow rate; and (2) a summary of the economics. To examine the effect of the stimulation method, the performance of each stimulated well was compared to the performance of an unstimulated well. (16 refs.)

• Research Organization: Texas A and M Univ.
• OSTI ID: 5518406
• Journal Information: Oil Gas J.; (United States), Vol. 69:14
• Country of Publication: United States
• Language: English

Related Subjects

02 PETROLEUM
HYDRAULIC FRACTURING
PERFORMANCE
OIL WELLS
FLOW RATE
FLUID FLOW
GEOLOGIC STRUCTURES
MATHEMATICAL MODELS
PERMEABILITY
PHYSICAL PROPERTIES
PRESSURE DEPENDENCE
RESERVOIR PRESSURE
STABILIZATION
SURFACE AREA
UNSTEADY FLOW
WELL COMPLETION
WELL PRESSURE
COMMINUTION
FRACTURING
SURFACE PROPERTIES
WELLS
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