CH4 70.79 18.40 C2 13.32 0.00 C3 7.11 0.00 iC4 1.60 0.00 nC4 2.60 0.00 iC5 0.40 0.00 nC5 0.40 0.00 nC6 0.08 0.00 Table B4. MP Resulting Streams - Process 1 (2S) for 10% CO2 in Raw Natural Gas Retentate 2 Permeate Temperature (ºC) 35 35 Pressure (bar) 49.5 4 Molar Flow (MMsm3/d) 4.67 0.95 % Molar N2 0.30 0.00 CO2 3.00 47.10 CH4 83.09 52.90 C2 6.01 0.00 C3 3.70 0.00 iC4 1.00 0.00 nC4 1.90 0.00 iC5 0.40 0.00 nC5 0.50 0.00 nC6 0.10 0.00 2S = 2-stages membrane permeation arrangement. B5. MP Resulting Streams - Process 1 (2S) for 30% CO2 in Raw Natural Gas Retentate 2 Permeate Temperature (ºC) 35 35 Pressure (bar) 49.5 4
iC4 1.20 0.00 nC4 2.10 0.00 iC5 0.40 0.00 nC5 0.40 0.00 nC6 0.09 0.00 Table B15. MP Resulting Streams – Process 2 (2S) for 50% CO2 in Raw Natural Gas Retentate 2 Permeate Temperature (ºC) 35 35 Pressure (bar) 49.5 4 Molar Flow (MMsm3/d) 2.41 3.00 % Molar N2 0.60 0.00 CO2 6.10 89.80 CH4 72.03 10.20 C2 11.10 0.00 C3 5.90 0.00 iC4 1.30 0.00 nC4 2.20 0.00 iC5 0.30 0.00 nC5 0.40 0.00 nC6 0.07 0.00 B16. MP Resulting Streams – Process 2 (3S) for 10% CO2 in Raw Natural Gas Retentate 3 Permeate Temperature (ºC) 35 35 Pressure (bar) 48 4 Molar Flow (MMsm3/d) 4.40 1.22 % Molar N2 0.30 0.00 CO2 1.80 41.70
Equipment D (m) H (m) Maximum Pressure (bar) Area (m2) Power (kW) V-2 2.6 10.4 20 V-1 2.3 9.1 44.5 V-3 1.6 6.3 15 E-4 12 403 E-1 45 1985 E-2 80 1024 E-5 36 280 E-6 100 135 E-3 52.5 367 H-1 51 72 H-2 49.5 66 K-4 8700 K-5 2647 K-6 2659 K-1 12866 K-2 5310 K-7 2233 K-8 2294 K-3 8540 Membrane 255753 E9. Equipment Dimensioning – Process 1 (3S) for 30% CO2 in Raw Natural Gas Equipment D (m) H (m) Maximum Pressure (bar) Area (m2) Power (kW) V-2 2.7 10.8 20 V-1 2.4 9.5 44.5 V-3 1.6 6.5 15 E-4 12 774
K-4 4112 K-5 3384 K-6 2660 K-1 12794 K-2 5114 K-3 8060 Membrane 92433 Absorber 1.8 19.8 51 Regenerator 2.3 19.8 4 Table E13. Equipment Dimensioning – Process 2 (1S) for 50% CO2 in Raw Natural Gas Equipment D (m) H (m) Maximum Pressure (bar) Area (m2) (kW) Separator 2.4 9.6 4.5 V-2 2.7 10.8 20 V-1 2.4 9.7 44.5 V-3 1.7 6.9 15 Lean/Rich Exchanger 4.5 514 E-3 12 585 E-4 36 380 E-5 100 430 E-100 51.5 677 E-1 45 2154 E-2 80 1280 E-3 52.5 244 Reboiler 4 451 Condenser 4 136 Booster Pump 464 K-2 4383 K-3 6369 K-4 6533
Regenerator 1.0 19.8 4 APPENDIX F. Economic Analysis Table F1. CAPEX Process Arrangement %CO2 in Raw NG Total CAPEX (M$) Skids in CAPEX %MP Skid in CAPEX %CA Skid in CAPEX 1 1S 10 264.4 80.4 19.6 0.0 1 1S 30 269.9 80.6 19.4 0.0 1 1S 50 202.6 85.6 14.4 0.0 1 2S 10 274.4 92.1 7.9 0.0 1 2S 30 266.1 81.3 18.7 0.0 1 2S 50 201.7 85.9 14.1 0.0 1 3S 10 285.7 89.3 10.7 0.0 1 3S 30 244.9 86.7 13.3 0.0 1 3S 50 197.7 87.3 12.7 0.0 2 1S 10 276.1 93.3 4.0 2.7 2 1S 30 221.0 89.3 4.9 5.8 2 1S 50 190.0 89.7 5.6 4.7 2 2S 10 274.4 92.1 7.9 0.0 2 2S 30 236.4 88.8 8.1 3.1 2 2S 50 193.4 88.8 8.3 2.9 2 3S 10 285.7 89.3 10.7 0.0 2 3S 30 241.9 87.5 11.0 1.5 2 3S 50 196.7 87.8 10.7 1.5 (a)Letter i indicates the Compression Skid number (1. 2 or 3) (Fig. 5). Table F2. OPEX Process Arrangement %CO2 in Raw Natural Gas Total OPEX (M$/year) in OPEX %MP Skid in OPEX %CA Skid in OPEX
2 3S 10 1775 57.4 42.6 0.0 2 3S 30 1799 60.4 36.3 3.3 2 3S 50 1703 66.8 30.4 2.8 (a)Letter i indicates the Compression Skid number (1. 2 or 3) (Fig. 5).