Fracturing of high-temperature, naturally fissured, gas-condensate reservoirs : Cikes, M; Economides, M J SPE Prod EngngV7, N2, May 1992, P226–232

Abstract

Eleven hydraulic fracture treatments were performed in deep (3300 to 3800 m [10,830 to 12,470 ft]), extremely high-temperature (180 to 195°C [356 to 383°F]), naturally fissured, gas-condensate reservoirs. Formation permeabilities at the fractured-well locations range from 0.003 to 0.2 md, while the initial formation pressure gradient is about 0.13 bar/m[0.57 psi/ft]. The producing fluid is high-gravity gas (0.83 to 1.15 to air) and contains up to 22% CO 2 and up to 4% H 2 S. Job sizes have ranged from 300 to 2000 m 3 [80,000 to 528,400 gal] of fluid and 50 to 600 Mg [100,130 to 1,321,590 lbm] of high-strength proppant. This paper emphasizes the general approach to well completion and stimulation treatment design, treatment execution, and evaluation. Interesting items include the engineering of the fracturing fluids to sustain their viscosity at the extreme temperatures and to reduce leakoff in these highly fissured formations