diff --git a/tests/examples/Fervo_Norbeck_Latimer_2023.out b/tests/examples/Fervo_Norbeck_Latimer_2023.out index 92f1d358..2fb56c8a 100644 --- a/tests/examples/Fervo_Norbeck_Latimer_2023.out +++ b/tests/examples/Fervo_Norbeck_Latimer_2023.out @@ -4,21 +4,21 @@ Simulation Metadata ---------------------- - GEOPHIRES Version: 3.6.3 - Simulation Date: 2024-11-18 - Simulation Time: 16:48 - Calculation Time: 1.672 sec + GEOPHIRES Version: 3.6.6 + Simulation Date: 2024-11-21 + Simulation Time: 10:38 + Calculation Time: 0.439 sec ***SUMMARY OF RESULTS*** End-Use Option: Electricity - Average Net Electricity Production: 2.08 MW - Electricity breakeven price: 27.85 cents/kWh + Average Net Electricity Production: 2.26 MW + Electricity breakeven price: 26.95 cents/kWh Number of production wells: 1 Number of injection wells: 1 Flowrate per production well: 41.0 kg/sec Well depth (or total length, if not vertical): 2.3 kilometer - Geothermal gradient: 76.74 degC/km + Geothermal gradient: 74 degC/km ***ECONOMIC PARAMETERS*** @@ -27,10 +27,10 @@ Simulation Metadata Accrued financing during construction: 5.00 Project lifetime: 10 yr Capacity factor: 90.0 % - Project NPV: -13.14 MUSD - Project IRR: -5.39 % - Project VIR=PI=PIR: 0.51 - Project MOIC: -0.21 + Project NPV: -13.17 MUSD + Project IRR: -4.65 % + Project VIR=PI=PIR: 0.53 + Project MOIC: -0.19 Project Payback Period: N/A Estimated Jobs Created: 6 @@ -43,25 +43,25 @@ Simulation Metadata Pump efficiency: 80.0 % Injection temperature: 41.0 degC Production Wellbore heat transmission calculated with Ramey's model - Average production well temperature drop: 4.1 degC + Average production well temperature drop: 3.8 degC Flowrate per production well: 41.0 kg/sec Injection well casing ID: 7.000 in Production well casing ID: 7.000 in Number of times redrilling: 0 - Power plant type: Subcritical ORC + Power plant type: Supercritical ORC ***RESOURCE CHARACTERISTICS*** Maximum reservoir temperature: 400.0 degC Number of segments: 1 - Geothermal gradient: 76.74 degC/km + Geothermal gradient: 74 degC/km ***RESERVOIR PARAMETERS*** Reservoir Model = Multiple Parallel Fractures Model - Bottom-hole temperature: 188.11 degC + Bottom-hole temperature: 179.42 degC Fracture model = Rectangular Well separation: fracture height: 160.00 meter Fracture width: 160.00 meter @@ -70,7 +70,7 @@ Simulation Metadata Number of fractures: 100.00 Fracture separation: 10.00 meter Reservoir volume: 25344000 m**3 - Reservoir impedance: 0.33 GPa.s/m**3 + Reservoir impedance: 0.30 GPa.s/m**3 Reservoir density: 2800.00 kg/m**3 Reservoir thermal conductivity: 2.70 W/m/K Reservoir heat capacity: 1000.00 J/kg/K @@ -78,57 +78,57 @@ Simulation Metadata ***RESERVOIR SIMULATION RESULTS*** - Maximum Production Temperature: 184.1 degC - Average Production Temperature: 182.4 degC - Minimum Production Temperature: 169.6 degC - Initial Production Temperature: 181.8 degC - Average Reservoir Heat Extraction: 24.20 MW + Maximum Production Temperature: 175.7 degC + Average Production Temperature: 174.1 degC + Minimum Production Temperature: 162.2 degC + Initial Production Temperature: 173.5 degC + Average Reservoir Heat Extraction: 22.74 MW Production Wellbore Heat Transmission Model = Ramey Model - Average Production Well Temperature Drop: 4.1 degC - Total Average Pressure Drop: 12325.6 kPa - Average Injection Well Pressure Drop: 392.5 kPa - Average Reservoir Pressure Drop: 14029.4 kPa - Average Production Well Pressure Drop: 350.0 kPa - Average Buoyancy Pressure Drop: -2446.4 kPa + Average Production Well Temperature Drop: 3.8 degC + Total Average Pressure Drop: 11221.8 kPa + Average Injection Well Pressure Drop: 387.1 kPa + Average Reservoir Pressure Drop: 12713.2 kPa + Average Production Well Pressure Drop: 342.1 kPa + Average Buoyancy Pressure Drop: -2220.6 kPa ***CAPITAL COSTS (M$)*** - Drilling and completion costs: 10.21 MUSD - Drilling and completion costs per vertical production well: 3.06 MUSD - Drilling and completion costs per vertical injection well: 3.06 MUSD + Drilling and completion costs: 10.13 MUSD + Drilling and completion costs per vertical production well: 3.02 MUSD + Drilling and completion costs per vertical injection well: 3.02 MUSD Drilling and completion costs per non-vertical sections: 3.61 MUSD Stimulation costs: 1.51 MUSD - Surface power plant costs: 9.85 MUSD - Field gathering system costs: 1.55 MUSD - Total surface equipment costs: 11.40 MUSD - Exploration costs: 3.65 MUSD - Total capital costs: 26.77 MUSD + Surface power plant costs: 11.34 MUSD + Field gathering system costs: 1.52 MUSD + Total surface equipment costs: 12.85 MUSD + Exploration costs: 3.62 MUSD + Total capital costs: 28.12 MUSD ***OPERATING AND MAINTENANCE COSTS (M$/yr)*** - Wellfield maintenance costs: 0.20 MUSD/yr - Power plant maintenance costs: 0.41 MUSD/yr + Wellfield maintenance costs: 0.21 MUSD/yr + Power plant maintenance costs: 0.45 MUSD/yr Water costs: 0.11 MUSD/yr - Total operating and maintenance costs: 0.72 MUSD/yr + Total operating and maintenance costs: 0.76 MUSD/yr ***SURFACE EQUIPMENT SIMULATION RESULTS*** - Initial geofluid availability: 0.16 MW/(kg/s) - Maximum Total Electricity Generation: 2.85 MW - Average Total Electricity Generation: 2.77 MW - Minimum Total Electricity Generation: 2.22 MW - Initial Total Electricity Generation: 2.74 MW - Maximum Net Electricity Generation: 2.16 MW - Average Net Electricity Generation: 2.08 MW - Minimum Net Electricity Generation: 1.50 MW - Initial Net Electricity Generation: 2.05 MW - Average Annual Total Electricity Generation: 21.67 GWh - Average Annual Net Electricity Generation: 16.26 GWh - Initial pumping power/net installed power: 33.79 % - Average Pumping Power: 0.69 MW + Initial geofluid availability: 0.15 MW/(kg/s) + Maximum Total Electricity Generation: 2.97 MW + Average Total Electricity Generation: 2.90 MW + Minimum Total Electricity Generation: 2.38 MW + Initial Total Electricity Generation: 2.87 MW + Maximum Net Electricity Generation: 2.34 MW + Average Net Electricity Generation: 2.26 MW + Minimum Net Electricity Generation: 1.74 MW + Initial Net Electricity Generation: 2.24 MW + Average Annual Total Electricity Generation: 22.63 GWh + Average Annual Net Electricity Generation: 17.70 GWh + Initial pumping power/net installed power: 28.16 % + Average Pumping Power: 0.63 MW ************************************************************ * HEATING, COOLING AND/OR ELECTRICITY PRODUCTION PROFILE * @@ -136,16 +136,16 @@ Simulation Metadata YEAR THERMAL GEOFLUID PUMP NET FIRST LAW DRAWDOWN TEMPERATURE POWER POWER EFFICIENCY (degC) (MW) (MW) (%) - 1 1.0000 181.78 0.6927 2.0502 8.5097 - 2 1.0090 183.41 0.6921 2.1272 8.7283 - 3 1.0108 183.75 0.6920 2.1434 8.7738 - 4 1.0118 183.93 0.6920 2.1518 8.7974 - 5 1.0124 184.04 0.6919 2.1574 8.8131 - 6 1.0129 184.12 0.6919 2.1612 8.8239 - 7 1.0129 184.13 0.6920 2.1612 8.8237 - 8 1.0108 183.75 0.6925 2.1430 8.7720 - 9 1.0019 182.13 0.6948 2.0640 8.5464 - 10 0.9771 177.63 0.7009 1.8532 7.9258 + 1 1.0000 173.47 0.6305 2.2385 9.8871 + 2 1.0088 175.01 0.6300 2.3076 10.0758 + 3 1.0107 175.32 0.6299 2.3220 10.1147 + 4 1.0116 175.49 0.6298 2.3295 10.1349 + 5 1.0123 175.60 0.6298 2.3345 10.1483 + 6 1.0127 175.67 0.6298 2.3379 10.1576 + 7 1.0127 175.68 0.6298 2.3380 10.1576 + 8 1.0107 175.34 0.6303 2.3221 10.1142 + 9 1.0021 173.83 0.6323 2.2525 9.9225 + 10 0.9780 169.65 0.6377 2.0628 9.3820 ******************************************************************* @@ -154,16 +154,16 @@ Simulation Metadata YEAR ELECTRICITY HEAT RESERVOIR PERCENTAGE OF PROVIDED EXTRACTED HEAT CONTENT TOTAL HEAT MINED (GWh/year) (GWh/year) (10^15 J) (%) - 1 16.6 191.4 9.75 6.60 - 2 16.8 192.4 9.06 13.23 - 3 16.9 192.7 8.36 19.88 - 4 17.0 192.9 7.67 26.53 - 5 17.0 193.1 6.97 33.19 - 6 17.0 193.1 6.28 39.85 - 7 17.0 192.9 5.58 46.50 - 8 16.6 191.7 4.89 53.12 - 9 15.6 187.8 4.22 59.59 - 10 12.0 161.5 3.64 65.16 + 1 18.0 179.8 9.18 6.59 + 2 18.3 180.8 8.52 13.22 + 3 18.3 181.1 7.87 19.85 + 4 18.4 181.3 7.22 26.50 + 5 18.4 181.4 6.57 33.15 + 6 18.4 181.5 5.91 39.80 + 7 18.4 181.3 5.26 46.44 + 8 18.1 180.2 4.61 53.05 + 9 17.1 176.6 3.98 59.52 + 10 13.6 151.9 3.43 65.09 ******************************** @@ -173,13 +173,13 @@ Year Electricity | Heat | Since Price Ann. Rev. Cumm. Rev. | Price Ann. Rev. Cumm. Rev. | Price Ann. Rev. Cumm. Rev. | Price Ann. Rev. Cumm. Rev. | OPEX Net Rev. Net Cashflow Start (cents/kWh)(MUSD/yr) (MUSD) |(cents/kWh) (MUSD/yr) (MUSD) |(cents/kWh) (MUSD/yr) (MUSD) |(USD/tonne) (MUSD/yr) (MUSD) |(MUSD/yr) (MUSD/yr) (MUSD) ________________________________________________________________________________________________________________________________________________________________________________________ - 1 0.00 -26.77 0.00 | 0.00 0.00 0.00 | 0.00 0.00 0.00 | 0.00 0.00 0.00 | 0.00 -26.77 -26.77 - 2 15.00 1.77 2.48 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.72 1.77 -25.00 - 3 15.00 1.81 5.01 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.72 1.81 -23.20 - 4 15.41 1.89 7.62 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.72 1.89 -21.30 - 5 15.81 1.97 10.30 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.72 1.97 -19.34 - 6 16.22 2.04 13.07 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.72 2.04 -17.29 - 7 16.62 2.11 15.90 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.72 2.11 -15.18 - 8 17.03 2.17 18.79 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.72 2.17 -13.01 - 9 17.43 2.18 21.69 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.72 2.18 -10.82 - 10 17.84 2.06 24.47 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.72 2.06 -8.77 + 1 0.00 -28.12 0.00 | 0.00 0.00 0.00 | 0.00 0.00 0.00 | 0.00 0.00 0.00 | 0.00 -28.12 -28.12 + 2 15.00 1.94 2.70 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.76 1.94 -26.18 + 3 15.00 1.97 5.44 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.76 1.97 -24.21 + 4 15.41 2.06 8.26 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.76 2.06 -22.15 + 5 15.81 2.14 11.17 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.76 2.14 -20.00 + 6 16.22 2.22 14.16 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.76 2.22 -17.78 + 7 16.62 2.30 17.22 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.76 2.30 -15.48 + 8 17.03 2.37 20.35 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.76 2.37 -13.12 + 9 17.43 2.39 23.51 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.76 2.39 -10.73 + 10 17.84 2.29 26.56 | 2.50 0.00 0.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.76 2.29 -8.44 diff --git a/tests/examples/Fervo_Norbeck_Latimer_2023.txt b/tests/examples/Fervo_Norbeck_Latimer_2023.txt index ec5eb1bf..486950ad 100644 --- a/tests/examples/Fervo_Norbeck_Latimer_2023.txt +++ b/tests/examples/Fervo_Norbeck_Latimer_2023.txt @@ -13,58 +13,58 @@ Reservoir Model, 1 Reservoir Volume Option, 1, -Reservoir Density, 2800, per the paper phyllite + quartzite + diorite + granodiorite, -Reservoir Depth, 7700 feet, per the paper -Reservoir Heat Capacity, 1000 +Reservoir Density, 2800, -- per the paper phyllite + quartzite + diorite + granodiorite +Reservoir Depth, 7600 feet, -- per the paper +Reservoir Heat Capacity, 1000, -- [J/kg/K] Reservoir Thermal Conductivity, 2.7 -Number of Fractures, 100, per the paper -Fracture Shape, 4, per the paper -Fracture Height, 160, per the paper -Fracture Width, 160, per the paper (distance between wellbores assumes a dipole flow field) +Number of Fractures, 100, -- per the paper +Fracture Shape, 4, -- per the paper +Fracture Height, 160, -- per the paper +Fracture Width, 160, -- per the paper (distance between wellbores assumes a dipole flow field) Fracture Separation, 10 meter Number of Segments, 1 -Gradient 1, 76.74, per the paper -Plant Outlet Pressure, 1500 psi, per the paper +Gradient 1, 74, -- per the paper +Plant Outlet Pressure, 1500 psi, -- per the paper Number of Injection Wells, 1 Number of Production Wells, 1 Well Geometry Configuration, 4 Has Nonvertical Section, True Multilaterals Cased, True -Number of Multilateral Sections, 2, Two parallel horizontal sections -Nonvertical Length per Multilateral Section, 3250 feet, per the paper -Well Drilling Cost Correlation, 10, per the drill cost paper - works out to $400/ft -Horizontal Well Drilling Cost Correlation, 10, per the drill cost paper - works out to $400/ft -Production Flow Rate per Well, 41.02, =650 gpm per the paper - per the paper the maximum flow rate was 63 L/s but the range was 550-750 gpm -Production Well Diameter, 7, per the paper -Injection Well Diameter, 7, per the paper -Well Separation, 365 feet, per the paper -Injection Temperature, 38 degC, per the paper 75 to 125 degF -Injection Wellbore Temperature Gain, 3 -Reservoir Impedance, 0.33, per paper, matching pumping power report 500-1000 kW -Ramey Production Wellbore Model, True +Number of Multilateral Sections, 2, -- Two parallel horizontal sections +Total Nonvertical Length, 3250 feet, -- per the paper +Well Drilling Cost Correlation, 10, -- per the drill cost paper - works out to $400/ft +Horizontal Well Drilling Cost Correlation, 10, -- per the drill cost paper - works out to $400/ft +Production Flow Rate per Well, 41, -- =650 gpm per the paper - per the paper the maximum flow rate was 63 L/s but the range was 550-750 gpm +Production Well Diameter, 7, -- per the paper +Injection Well Diameter, 7, -- per the paper +Well Separation, 365 feet, -- per the paper +Injection Temperature, 38 degC, -- per the paper 75 to 125 degF +Injection Wellbore Temperature Gain, 3, -- [degC] +Reservoir Impedance, 0.30, -- per paper, matching pumping power report 500-1000 kW +Ramey Production Wellbore Model, 1 Utilization Factor, .9 Water Loss Fraction, 0.1 -Maximum Drawdown, 1, no redrilling considered -Ambient Temperature, 8 degC, per the paper. Published ambient is 10.27 degC -Surface Temperature, 8 degC, per the paper. Published ambient is 10.27 degC -End-Use Option, 1, electricity as the main product +Maximum Drawdown, 1, -- no redrilling considered +Ambient Temperature, 8 degC, -- per the paper. Published ambient is 10.27 degC +Surface Temperature, 8 degC, -- per the paper. Published ambient is 10.27 degC +End-Use Option, 1, -- electricity as the main product Plant Lifetime, 10 -Power Plant Type, 1, subcritical binary cycle +Power Plant Type, 2, -- supercritical binary cycle End-Use Efficiency Factor, .9 -Circulation Pump Efficiency, 0.80, per the paper -Economic Model, 3, BICYCLE Levelized Cost Model +Circulation Pump Efficiency, 0.80, -- per the paper +Economic Model, 3, -- BICYCLE Levelized Cost Model Starting Electricity Sale Price, 0.15 -Ending Electricity Sale Price, 1.00, essentially no limit as the rate can rise continuously with inflation -Electricity Escalation Rate Per Year, 0.004053223, End up being about 2% inflation +Ending Electricity Sale Price, 1.00, -- essentially no limit as the rate can rise continuously with inflation +Electricity Escalation Rate Per Year, 0.004053223, -- End up being about 2% inflation Electricity Escalation Start Year, 1 -Fraction of Investment in Bonds, .5, Required for BICYCLE model -Combined Income Tax Rate, .3, Required for BICYCLE model -Gross Revenue Tax Rate, 0, Required for BICYCLE model -Inflated Bond Interest Rate, .05, Required for BICYCLE model -Inflated Equity Interest Rate, .08, Required for BICYCLE model -Inflation Rate, .02, Required for BICYCLE model -Investment Tax Credit Rate, 0, Required for BICYCLE model -Inflation Rate During Construction, 0.05, -Property Tax Rate, 0, Required for BICYCLE model +Fraction of Investment in Bonds, .5, -- Required for BICYCLE model +Combined Income Tax Rate, .3, -- Required for BICYCLE model +Gross Revenue Tax Rate, 0, -- Required for BICYCLE model +Inflated Bond Interest Rate, .05, -- Required for BICYCLE model +Inflated Equity Interest Rate, .08, -- Required for BICYCLE model +Inflation Rate, .02, -- Required for BICYCLE model +Investment Tax Credit Rate, 0, -- Required for BICYCLE model +Inflation Rate During Construction, 0.05 +Property Tax Rate, 0, -- Required for BICYCLE model Print Output to Console, 1 Time steps per year, 10