Pressure = 2100 psia, Temperature = 200, Solution Gas = 500 scf/stb OFVF above bubble point = 1.16 3000psia and 200 oF. (find the flowingīottom hole pressure, flowing wellhead temperature and production rate for a given wellhead Use the measured data to calibrate the PVT model and re-run Exercise 1. The following measured PVT data is available to calibrate and improve the fluid model. From the Setup | Black Oil menu to enter the stock tank oil properties and the bubble point GOR, then the stock tank GOR is used (takes precendence)with the calibration GOR ignored.ġ. GOR is specified).Ĭonversely, if the stock tank GOR is less than the calibration sat. pressure will intersect this calibration point, but the bubble point is no longer that with which the calibrationsat. GOR, you are effectively increasing the bubble point. By specifying a higher stock tank GOR than acalibration sat. Note: The bubble point calibration for sat GOR is used to normalize (calibrate) the Soln GOR correlation. Gas compressibility (Z) 2,000 psia and 210 ☏ Live oil viscosity 0.29 cP 2,000 psia and 210 ☏ OFVF (below bubble point pressure) 1.38 2,000 psia and 210 ☏ĭead oil viscosities 0.31 cP 200 ☏ and 0.92 cP 60 ☏
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OFVF (above bubble point pressure) 1.49 4,269 psia and 210 ☏ The following table contains data from a laboratory analysis of our fluid: These physical properties are subsequently used to determine the phases present, theįlow regime, the pressure losses in single and multiphase flow regions, and the heat transferred to or The fluid physical properties to estimated over the range of pressures and temperatures encounteredīy the fluid. No analysis work can be carried out until a blackoil fluid model has been developed. A verticalĮxcersise 2: Develop a Calibrated Blackoil Model This is done by pointing and clicking on the verticalĬompletion button at the top of the screen and then pointing and clicking in the work area. Through field life because the oil and water have similar mobilities in this reservoir structure.ġ. The PI will not be affected by changes to the watercut Pressure is to be maintained by water injection.
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The PI will not be affected by changes to the reservoir pressure because the reservoir This applies throughout field life and the productivity index is not expected toĬhange. The engineering data available is given at the end of this case study.ġ) Select File| New| Well Performance AnalysisĮxcercise1: Insert Completion and Develop a Well Inflow Performance ModelĪ straight line productivity index (PI) method is considered adequate in this case because the fluidįlows into the completion at a pressure considerably above the bubble point and no gas comes out of Method of predicting the fluid physical properties so that the pressure losses and heat transferģ) Select a suitable tubing size for the production string.Ĥ) Review the feasibility of using gas lift as an alternative to water injection. Relationship between the reservoir pressure, the flowing bottom hole pressure and flowrateĢ) Develop a blackoil fluid model to match the laboratory data. The engineer is asked to perform the following tasks:ġ) Develop a well inflow performance model applicable throughout field life. The reservoir pressure will be maintained by water injection and the preference is toĪvoid the use of artificial lift methods. Reservoir simulations have been performed to predict the change in watercut Fluid properties at stock tank and laboratory conditions Inserted and flow characteristics measured. A vertical well has been drilled, a test string Single Branch Tutorial 4 – Black Oil Calibration and Performance ForecastingĪn oil reservoir has been discovered in the North Sea. Worked Answers: Case Study 1 – Oil Well Design 175 Worked Answers: Case Study 2 – Well Performance Analysis – Nodal Analysis 194 (4)
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145 FPT Tutorial 3: Look Up Tables 157 FPT Tutorial 4: Daily Contract Quotas (DCQ) 163 Network Tutorial 1: Looped Gathering Network 100 Network Tutorial 2: Gas Transmission Network 108 Network Tutorial 3: Water Injection System 112įPT Tutorial 1: Compositional Tank & Look Up Tables 117 FPT Tutorial 2: Black Oil Tank.
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Single Branch Tutorial 1 - Single Phase Pipeline 6 Single Branch Tutorial 2 – Multiphase Pipeline 26 Single Branch Tutorial 3 - Oil Well Performance 33 Single Branch Tutorial 4 – Black Oil Calibration and Performance Forecasting 46Ĭase Study 1 - Oil Well/ Black Oil Fluid 65 Case Study 2 - Well Performance Modelling - Nodal Analysis 73 Case Study 3 - Gas well Performance using a Compositional Fluid Model 77 Case Study 4 – ESP Selection / Design 86 Case Study 5 – Pipeline and Facilities (Compositional Fluid model) 89 Case Study 6 – Gas Lift Design, New Mandrel spacing: 95 Case Study 7 – Gas Lift Design, Current Mandrel spacing: 98