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Synchronize Project Red example with workshop version NREL#273
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softwareengineerprogrammer committed Nov 21, 2024
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162 changes: 81 additions & 81 deletions tests/examples/Fervo_Norbeck_Latimer_2023.out
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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***
Expand All @@ -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

Expand All @@ -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
Expand All @@ -70,82 +70,82 @@ 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


***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 *
************************************************************
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


*******************************************************************
Expand All @@ -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


********************************
Expand All @@ -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
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