likelihood of the scale formation and the respective chemical methods to mitigate the scale formation. [20...
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likelihood of the scale formation and the respective chemical methods to mitigate the scale formation. [20 marks] 3. Based on the reservoir description and the given data, establish the sand failure design criteria for the producing formation. [15 marks] Table 2: Injection seawater and formation water composition Sea water (ppm) lon Sodium (Na) Potassium (K) Calcium (Ca) Magnesium (Mg) Strontium (Sr) Barium (Ba) Iron (Fe) Bicarbonate (HCO) 124 Sulphate (SO²) 3600 Chlorine (CI) Salinity ppm 14000 630 420 1450 11 0 23000 43235 Properties Formation permeability, K Formation thickness, h Tensile strength, T oil viscosity, Formation Volume Factor of oil, Bo Skin factor, s External boundary radius, re Wellbore radius, rw Average reservoir pressure, Pavg Wellbore pressure, Pw value 300 100 150 2.2 1.1 7 Formation water (ppm) 1489 0.5 1850 1230 123059 10206 40909 1710 1011 1496 9 Table 3: Near wellbore and the producing formation properties Unit mD 6 0 261370 439776 ft psi cP SCF/STB ft ft psi psi Sea level CO₂ N₂ H₂S C₁ -Wells C₂ C3 ¡C4 nC4 ¡C5 nC5 Reservoir Producing reservoir oil properties Component Composition (Mol%) C6 C7+ Figure 1: Representative diagram showing the hydrocarbon flow path from the reservoir to the offshore platform. Total API Table 1: The properties of the reservoir including the producing reservoir oil, producing gas, temperature of transportation and ocean floor 3.32 1.09 0.66 28.18 13.6 Sea floor 9.2 0.95 4.3 1.38 2.6 4.32 30.4 100 (mol%) 36.1 Reservoir pressure: 5200 psia Reservoir depth: 9000 ft Flowline / Riser H₂S: 7.5 ppm Bubble point pressure: 3100 psia Platform Producing gas properties component methane, Ethane Propane i-butane n-butane pentane INST CAST 92.67 5.29 1.38 0.182 0.338 0.14 composition (mol%) Flowing hydrocarbon stream temperature in the transportation pipeline: 50 °F Pipeline inlet pressure: 8.27 MPa Pipeline inlet temperature: 84.2 °F Pipeline outlet pressure: 6.2 MPa Pipeline outlet temperature: 45.4 °F The ocean floor temperature: 39 °F Hammerschmidt constant for MEG: 4000 Hammerschmidt Constant for methanol: 2335 A North Sea "subsea offshore reservoir A" is currently producing at the 7000 bpd of oil, 40000 SCF/STB Gas-Oil-Ratio (GOR) and the 15000 BPD of water and processed at the offshore facility via the ten (10) miles subsea transportation pipeline (refer to the following figure 1). The reservoir pressure declined below the bubble point pressure after 10 years of production since the time it was put on production in early 1990s. Waterflooding operations was undertaken for the reservoir pressure maintenance through the seawater injection (predominant of sulphate ions) into reservoir. Moreover, the static and dynamic analysis of the hydrocarbon flow through the transportation line indicated that the flowing hydrocarbon stream undergoes the pressure and temperature changes (higher to lower) during its travel from the source (reservoir) to the sink (surface facilities). Tasks: You are required to accomplish the following tasks using above description and the provided data in Table 1, 2 and 3. Wherever needed, you should justify your answers supported by the associated neatly labelled diagrams. It is an essential part of this design assignment that the students themselves should identify the appropriate data (from the given description and tables) needed for your design solution. likelihood of the scale formation and the respective chemical methods to mitigate the scale formation. [20 marks] 3. Based on the reservoir description and the given data, establish the sand failure design criteria for the producing formation. [15 marks] Table 2: Injection seawater and formation water composition Sea water (ppm) lon Sodium (Na) Potassium (K) Calcium (Ca) Magnesium (Mg) Strontium (Sr) Barium (Ba) Iron (Fe) Bicarbonate (HCO) 124 Sulphate (SO²) 3600 Chlorine (CI) Salinity ppm 14000 630 420 1450 11 0 23000 43235 Properties Formation permeability, K Formation thickness, h Tensile strength, T oil viscosity, Formation Volume Factor of oil, Bo Skin factor, s External boundary radius, re Wellbore radius, rw Average reservoir pressure, Pavg Wellbore pressure, Pw value 300 100 150 2.2 1.1 7 Formation water (ppm) 1489 0.5 1850 1230 123059 10206 40909 1710 1011 1496 9 Table 3: Near wellbore and the producing formation properties Unit mD 6 0 261370 439776 ft psi cP SCF/STB ft ft psi psi Sea level CO₂ N₂ H₂S C₁ -Wells C₂ C3 ¡C4 nC4 ¡C5 nC5 Reservoir Producing reservoir oil properties Component Composition (Mol%) C6 C7+ Figure 1: Representative diagram showing the hydrocarbon flow path from the reservoir to the offshore platform. Total API Table 1: The properties of the reservoir including the producing reservoir oil, producing gas, temperature of transportation and ocean floor 3.32 1.09 0.66 28.18 13.6 Sea floor 9.2 0.95 4.3 1.38 2.6 4.32 30.4 100 (mol%) 36.1 Reservoir pressure: 5200 psia Reservoir depth: 9000 ft Flowline / Riser H₂S: 7.5 ppm Bubble point pressure: 3100 psia Platform Producing gas properties component methane, Ethane Propane i-butane n-butane pentane INST CAST 92.67 5.29 1.38 0.182 0.338 0.14 composition (mol%) Flowing hydrocarbon stream temperature in the transportation pipeline: 50 °F Pipeline inlet pressure: 8.27 MPa Pipeline inlet temperature: 84.2 °F Pipeline outlet pressure: 6.2 MPa Pipeline outlet temperature: 45.4 °F The ocean floor temperature: 39 °F Hammerschmidt constant for MEG: 4000 Hammerschmidt Constant for methanol: 2335 A North Sea "subsea offshore reservoir A" is currently producing at the 7000 bpd of oil, 40000 SCF/STB Gas-Oil-Ratio (GOR) and the 15000 BPD of water and processed at the offshore facility via the ten (10) miles subsea transportation pipeline (refer to the following figure 1). The reservoir pressure declined below the bubble point pressure after 10 years of production since the time it was put on production in early 1990s. Waterflooding operations was undertaken for the reservoir pressure maintenance through the seawater injection (predominant of sulphate ions) into reservoir. Moreover, the static and dynamic analysis of the hydrocarbon flow through the transportation line indicated that the flowing hydrocarbon stream undergoes the pressure and temperature changes (higher to lower) during its travel from the source (reservoir) to the sink (surface facilities). Tasks: You are required to accomplish the following tasks using above description and the provided data in Table 1, 2 and 3. Wherever needed, you should justify your answers supported by the associated neatly labelled diagrams. It is an essential part of this design assignment that the students themselves should identify the appropriate data (from the given description and tables) needed for your design solution.
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Hydrology and Floodplain Analysis
ISBN: 978-0132567961
5th edition
Authors: Philip B. Bedient, Wayne C. Huber, Baxter E. Vieux
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