Identifier

etd-04072016-165145

Degree

Doctor of Philosophy (PhD)

Department

Petroleum Engineering

Document Type

Dissertation

Abstract

Unlike the Continuous Gas Injection (CGI) and Water-Alternative Gas (WAG), the Gas Assisted Gravity Drainage (GAGD) process takes advantage of the natural segregation of reservoir fluids to provide gravity-stable oil displacement. The gas is injected through existing vertical wells to formulate a gas cap to allow oil and water drain down to the horizontal producer (s). Therefore, the GAGD process was implemented through immiscible and miscible injection modes to improve oil recovery in a sector of the main pay/upper sandstone member in the South Rumaila oil field, located in Iraq. A high-resolution geostatistical reservoir characterization model was constructed to model the lithofacies and petrophysical properties in order to provide the most realistic geological environment for the GAGD process evaluation. After upscaling the geostatistical model, a compositional reservoir simulation was built to evaluate the GAGD process and test its effectiveness to improve oil recovery. Next, sensitivity analysis was performed to determine the most influential reservoir parameters that impact the GAGD process. With no effect of reservoir porosity, it was also investigated that reservoir permeability and anisotropy ratio have the most impact on the reservoir flow response through the GAGD process. Then, several GAGD optimization and uncertainty assessment approaches were conducted to determine the optimal future reservoir scenario of the largest improvement in oil recovery. These optimal cases include operational decision parameters, injection pressure, and cycling injection. It was concluded that the cycling GAGD process has better performance to improve oil recovery than the continuous injection mode. In addition, all the successive approaches of the optimization and uncertainty assessments led to in- crease oil production by more than 500 million barrels over the base-case GAGD process of default operational decision parameters. Finally, both heterogeneity and anisotropy effects have been identified by showing a significant impact on the reservoir flow responses. Specifically, the effect of permeability anisotropy is higher than reservoir heterogeneity be cause the main concept of the GAGD process considers vertical fluid movements towards the horizontal producers. Consequently, the overall reservoir characterization, compositional simulation, and optimization of the immiscible GAGD process have shown its effectiveness to improve oil recovery in a real field-scale evaluation.

Date

2016

Document Availability at the Time of Submission

Release the entire work immediately for access worldwide.

Committee Chair

Rao, Dandina

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