The key to the success of a tight-gas field development program in a fluvial environment is to understand the reservoir's deliverability and what the optimum fracture half-length is as a function of geological setting and stress state. The application and appropriate modification of basin best practices and the application of technology for reservoir characterization can shorten the learning curve of an operator in the development of a basin.
Numerous completion strategies (Limited Entry, high rate limited entry, and various Pin-point Stimulation Techniques) were implemented with an appropriate data collection strategy to evaluate and compare well performance. Micro seismic data, tracer logs, and pump-in data were used to calibrate and constrain appropriate fracture evaluation models (P3D and 3D). Rate-transient production analysis techniques, together with statistical data techniques were incorporated to evaluate stimulation techniques (proppant & fluid volumes) and to validate the differences/ similarities observed between micro-seismic and fracture-propagation model predicted lengths.
This paper demonstrates how reservoir characterization and completion understanding via the use of calibrated fracture propagation models and production analysis tools have enabled the evaluation of the technology used and the acceleration of the learning curve to achieve significant impact on gas production rates and downhole flowing pressures.