Abstract
To maximize a horizontal well production, we need to determine the optimum direction and horizontal well length that maximizes the gas field recovery for a certain constant flow rate called by plateau rate. This problem is conventionally solved by using a reservoir simulation model and trial and error procedure that consumes considerably a lot of time and efforts. This study uses a random search method, i.e., Genetic Algorithm (GA), to solve this optimization problem and it very much eases to find the best well location with less time and efforts consumed.Along the general technique in directing a horizontal well towards the least principal stress of rocks, this study considers the geomechanics effects that influence the gas production performance. And also, the drainage area of horizontal well will be considered in this study to obtain the optimum horizontal well direction and length. In order to do this, a new proposed objective function for the GA has been constructed based on basic reservoir properties (i.e., porosity, permeability and gas saturation) and geomechanics properties (i.e., Young’s modulus and Poisson’s ratio). The results of the proposed method are validated using a reservoir model and economics evaluation.It may be concluded that the applying GA, with the appropriate objective function, can give accurate and faster results compared with the trial and error method using reservoir simulator, technically and economically, and also the proposed method is able to reduce the amount of works considerably time.
Highlights
The determination of the optimum horizontal well direction and length has usually been conducted by using a conventional trial-and-error method, when placing coordinates at a geological or reservoir model and running with a simulator to obtain the gas recovery; this process requires experience, considerable time, and a relatively high cost
There are some consideration parameters in applying the horizontal well length: (1) Reservoir boundary: Reservoir production performance will be lower in the area near the reservoir boundary
The fluid sample was taken during Drill Stem Test (DST) that performed in the gas zone of X-1 exploration well, which it shows that the methane composition was 95.83%
Summary
The determination of the optimum horizontal well direction and length has usually been conducted by using a conventional trial-and-error method, when placing coordinates at a geological or reservoir model and running with a simulator to obtain the gas recovery; this process requires experience, considerable time, and a relatively high cost. The exhausted trial and error procedures have to be run to obtain the optimal production scenario in forecasting future reservoir performance. It spends quite a lot of time and cost of applying some case sensitivity of the development scenario with trial and error procedure. If the horizontal well section has reached the bad reservoir properties zone, it will reduce the gas production. If the bad zones penetrated by the horizontal section are the high mas.ccsenet.org
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