This paper presents a new methodology of coupled hydraulic fracturing, geomechanical and reservoir modeling, and an example of integrated analysis of a tight gas well. The new modeling technology and its advantages in field application are demonstrated on a case study of a designated “science well” in a tight gas Wyoming field. A detailed model of the well included its entire fracturing and production history, and was constrained by a large amount of field measurements. The model was successfully history matched to all of this data using a common reservoir description. This novel approach thus results in much higher level of confidence compared to using uncoupled models with different assumptions.
The history matching process provided insight in the mechanics of fracturing and flow in this field and the importance of geomechanical effects. Some of the most important findings are that the formation permeability is highly stress-sensitive and increases dramatically during frac injection, fracture length and conductivity are highly variable during flowbacks, and geomechanical effects on conductivity are still evident after several months of production. The calibrated model was then used to assess the gains in productivity possible from improved technology of fracturing, resulting in greater conductivity and length of fractures.
Author(s): SPE, SPE, A. (Tony) Settari, U. of Calgary and TAURUS Reservoir Solutions Ltd.; R.B. Sullivan, Anadarko Petroleum; R.J. Rother, Devon Energy; and T.K. Skinner, Marathon Oil
Paper Number: SPE 119394