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<span style="color:black;mso-themecolor:
text1">Application of Reservoir Simulation Techniques Using an Actual Case Study of a Mature Oil Field<o:p></o:p></span></h1>
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normal"><span style="font-size:11.0pt"><o:p> </o:p></span></b></p>
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<b style="mso-bidi-font-weight:
normal"><span style="font-size:11.0pt">Sundar Ramasamy Masters’ Thesis Dissertation<o:p></o:p></span></b></p>
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normal"><span style="font-size:11.0pt"><o:p> </o:p></span></b></p>
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<b style="mso-bidi-font-weight:
normal"><span style="font-size:11.0pt">Defense Date:</span></b><span style="font-size:11.0pt"> Thursday, August 2<sup>nd</sup> 2018
<b style="mso-bidi-font-weight:normal">Time: </b>3:00 pm <b style="mso-bidi-font-weight:
normal">
Location: </b>Room 124, ERP Building 9<o:p></o:p></span></p>
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<b style="mso-bidi-font-weight:
normal"><span style="font-size:11.0pt">Committee Members:</span></b><span style="font-size:11.0pt"> Dr. Ganesh Thakur, Dr. Ahmad Sakhaee-Pour and Dr. Sriram Balasubramanian<o:p></o:p></span></p>
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<span style="font-size:11.0pt"><o:p> </o:p></span></p>
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mso-hansi-font-family:Calibri;mso-hansi-theme-font:minor-latin;color:black"><span style="mso-tab-count:1">
</span></span><span style="font-size:12.0pt;
line-height:200%;font-family:"Times New Roman",serif">The aim of this study is to apply reservoir simulation techniques, namely streamline simulation and black oil simulation to an actual oil field undergoing primary
recovery. These techniques were used to propose a future development strategy for an oil field.
</span><span style="font-size:12.0pt;mso-bidi-font-size:11.0pt;line-height:
200%;font-family:"Times New Roman",serif">The field under study in this thesis is in operation since 1993 and is currently under primary recovery under a strong water drive. The two
types of simulations compared in this study are black oil and streamline simulation models. The simulators used are ECLIPSE E100 and Frontsim for black oil simulation and streamline simulation, respectively. FrontSim, by default, is an IMPES (Implicit Pressure
and Explicit Saturation) type simulator which solves pressure equations implicitly and the saturation equations explicitly. In streamline simulation, pressure throughout the reservoir is calculated and this is then used to generate a series of streamlines
representing the fluid flow in the reservoir. The fluid saturations are then calculated along theses streamlines. This de-coupling of the pressure and saturation equations helps reduce the computational time of streamline simulators when compared to black
oil simulators. The drastic reduction in computation time supports the use of streamline simulators in intensive workflows such as history matching, uncertainty studies and waterflood optimization, which require multiple model runs in a considerably short
time. The static model of the oil field was provided by the operating company of this field.</span><span style="font-size:12.0pt;line-height:200%;font-family:"Times New Roman",serif"> Field data such as production, completion, core flood and PVT report required
to initialize and history match the reservoir model were also provided</span><span style="font-size:12.0pt;mso-bidi-font-size:11.0pt;line-height:200%;font-family:
"Times New Roman",serif">. The entire simulation study was carried out using streamline and black
oil simulation methods, drawing comparisons between them during history match. </span>
<span style="font-size:12.0pt;line-height:200%;
font-family:"Times New Roman",serif">Prediction scenarios were run using black oil simulation method as it was observed to produce a better history match compared to streamline simulation method.
</span><span style="font-size:12.0pt;
mso-bidi-font-size:11.0pt;line-height:200%;font-family:"Times New Roman",serif"><span style="mso-spacerun:yes"> </span></span><span style="font-size:12.0pt;
line-height:200%;font-family:"Times New Roman",serif">Prediction
cases include a blind test, base case prediction and proposal and performance evaluation of two horizontal infill wells. It was observed that the reservoir under study has a strong aquifer support and does not require water-flooding in the near future. Hence,
infill drilling will contribute to majority of the field development. Three infill locations have been proposed and evaluated for future performance. Two of the three proposed horizontal infill wells were predicted to produce around 3 MMSTB of oil each in
a span of 20 years. The third well was a poor producer and was predicted to produce less than 1 MMSTB of oil in 20 years. This well was not suggested to be drilled as it is of a lower priority compared to the other two wells. Based on the location of these
wells, new infill well locations can be determined in the future.<b style="mso-bidi-font-weight:
normal"><span style="color:#1F497D;mso-themecolor:text2"><o:p></o:p></span></b></span></p>
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