Modeling and Performance Assessment of Produced Water Injection Efficiency in Homogeneous and Heterogeneous Reservoir System as an Enhanced Oil Recovery Approach (Published)
Due to the increase in the demand of crude oil as precursor to energy base fuels production such as gasoline, as well as petrochemicals, the oil and gas production sector is challenged on optimizing their crude oil recovery measures as a means of meeting up the advancements in the oil and gas energy sector, hence calling interest of researchers and petroleum engineers to provide possible contributive ideas. On that bases, this work focuses on the performance assessment of produced water injection efficiency in homogeneous and heterogeneous reservoir system under enhanced oil recovery (EOR) as a cost, time and material conservative measure compared to the use of water as injection fluid. Reservoir and fluid properties data were obtained from IDU- Well10 (located in Orashi area of Niger Delta, Nigeria), and they were used to model the realistic reservoir using computer modeling group (CMG) computer-based software. Reservoir fluid model was created and after defining the fluid and rock properties, the model was initialized, well configuration was implemented by placing the producers along the length of the reservoir opposite to the injector well which conveys produced water at an injection pressure of 2040 psi and fluid temperature of 120oF (48.9oC). The studied reservoir model was recurrent to operates for 10 years using the CMG-GEM simulation engine collectively with CMG-WINPROP. Results shows that produced water has an RF value of 77.9% when used as injection fluid in a homogeneous reservoir, and it will generate 143094 bbl cumulative oil volume and 100445 ft3 cumulative gas (CG) volume. While when applied to a heterogeneous reservoir system it shows a 73.9% RF value with 108851 bbl cumulative oil volume and 49654.9 ft3 cumulative gas (CG) volume achieved, which are lesser when compare to those obtained from a homogeneous reservoir system. The result depicts that a convensional homogeneous reservoir is of higher higher recovery performance. It’s recommended that produced water should rather be used as injection during crude oil recovery instead of normal sea water as it proves to be of higher recovery efficiency (>73%), this will indeed save cost, and production time which are consummed when using normal sea water as injection fluid.
Keywords: Permeability, computer modeling group (CMG), crude oil recovery, oil recovery factor, volume of oil recovered, water-cut
Analytical Simulation for the Improvement of Oil Well Productivity Using Artificial Gas Lifting Techniques (Published)
A well simulation analysis was done using integrated production modeling (IPM) software (PROSPER) to determine the productivity of two wells. The simulation includes the well properties and a detailed description of the reservoir and vertical lift performance of the wells under investigation. The process was segmented into two phases. Phase -1 comprises of simulating a well using Pressure, Volume, Temperature (PVT) data, Inflow Performance Relationship (IPR) data, and surface production data. While phase-2 includes conducting Well analyses based on the different operating conditions prevalent in the field. Each constituent of the producing Well for the study was evaluated using a well-analytical approach. The bias in this procedure is to identify potential challenges in the production mechanisms causing flow restriction which adversely limit the well from achieving its maximum producing potential flow proportion. Three operational conditions were selected for the reservoir simulation, which include; varying the tubing size, varying gas injection rate, and reduction of the tubing head pressure. The simulation and analysis of the wells (22T and 19L) indicate Well Productivity as a function of Tubing-head pressure, while the reduction in the Tubing-head pressure causes an increase in production rates. However, the variation of the tubing sizes did not show a significant increase in Wells 22T and 19L. This is potentially due to the well’s high reservoir pressure, which required no artificial lift application at this instant but certainly in the future.At the conclusion of the analysis done on the two selected producers Wells under investigation, the results show that a gas artificial lift will certainly enhance well Productivity in the selected field.
Keywords: Productivity, Simulation, artificial gas lift, gas injection rate, oil and gas production, oml 42, water-cut