From 437259d102d97a21f030a5482e308ea0aefdc83d Mon Sep 17 00:00:00 2001 From: softwareengineerprogrammer <4056124+softwareengineerprogrammer@users.noreply.github.com> Date: Wed, 27 Nov 2024 10:13:20 -0800 Subject: [PATCH] Add examples 6 & 7 inputs & outputs + README entry. (Testing of examples 6 & 7 disabled until TOUGH executable can be made available in GitHub Actions - see https://github.com/NREL/GEOPHIRES-X/issues/318) --- README.rst | 14 ++- tests/examples/example6.out | 242 ++++++++++++++++++++++++++++++++++++ tests/examples/example6.txt | 68 ++++++++++ tests/examples/example7.out | 238 +++++++++++++++++++++++++++++++++++ tests/examples/example7.txt | 66 ++++++++++ tests/test_geophires_x.py | 2 + 6 files changed, 625 insertions(+), 5 deletions(-) create mode 100644 tests/examples/example6.out create mode 100644 tests/examples/example6.txt create mode 100644 tests/examples/example7.out create mode 100644 tests/examples/example7.txt diff --git a/README.rst b/README.rst index a9f01b56..9981139e 100644 --- a/README.rst +++ b/README.rst @@ -351,10 +351,14 @@ Example-specific web interface deeplinks are listed in the Link column. - `example5.txt `__ - `.out `__ - `link `__ - * - Example 6: TOUGH2 - - `example6.txt `__\* - - - - + * - Example 6: TOUGH2 (Multiple Gradients) + - `example6.txt `__ + - `.out `__ + - \* + * - Example 7: TOUGH2 (Single Gradient) + - `example7.txt `__ + - `.out `__ + - \* * - Example 8: Cornell Direct-Use Heat - `example8.txt `__ - `.out `__ @@ -452,7 +456,7 @@ Example-specific web interface deeplinks are listed in the Link column. - `.out `__ - `link `__ -*\*GEOPHIRES v2.0 input file* +*\*TOUGH2 is not currently supported in the web interface. Comment on `this tracking issue `__ to request web interface support for TOUGH2.* Videos ------ diff --git a/tests/examples/example6.out b/tests/examples/example6.out new file mode 100644 index 00000000..6b585d51 --- /dev/null +++ b/tests/examples/example6.out @@ -0,0 +1,242 @@ + ***************** + ***CASE REPORT*** + ***************** + +Simulation Metadata +---------------------- + GEOPHIRES Version: 3.5.2 + Simulation Date: 2024-11-27 + Simulation Time: 10:43 + Calculation Time: 7.187 sec + + ***SUMMARY OF RESULTS*** + + End-Use Option: Direct-Use Heat + Average Direct-Use Heat Production: 13.17 MW + Direct-Use heat breakeven price (LCOH): 5.64 USD/MMBTU + Number of production wells: 1 + Number of injection wells: 1 + Flowrate per production well: 50.0 kg/sec + Well depth (or total length, if not vertical): 3.0 kilometer + Segment 1 Geothermal gradient: 50 degC/km + Segment 1 Thickness: 1 kilometer + Segment 2 Geothermal gradient: 40 degC/km + + + ***ECONOMIC PARAMETERS*** + + Economic Model = Standard Levelized Cost + Interest Rate: 5.00 + Accrued financing during construction: 0.00 + Project lifetime: 30 yr + Capacity factor: 90.0 % + Project NPV: 5.09 MUSD + Project IRR: 8.37 % + Project VIR=PI=PIR: 1.23 + Project MOIC: 0.96 + Project Payback Period: 11.77 yr + + ***ENGINEERING PARAMETERS*** + + Number of Production Wells: 1 + Number of Injection Wells: 1 + Well depth (or total length, if not vertical): 3.0 kilometer + Water loss rate: 0.0 + Pump efficiency: 80.0 + Injection temperature: 70.0 degC + Production Wellbore heat transmission calculated with Ramey's model + Average production well temperature drop: 3.1 degC + Flowrate per production well: 50.0 kg/sec + Injection well casing ID: 8.000 in + Production well casing ID: 8.000 in + Number of times redrilling: 0 + + + ***RESOURCE CHARACTERISTICS*** + + Maximum reservoir temperature: 375.0 degC + Number of segments: 2 + Segment 1 Geothermal gradient: 50 degC/km + Segment 1 Thickness: 1 kilometer + Segment 2 Geothermal gradient: 40 degC/km + + + ***RESERVOIR PARAMETERS*** + + Reservoir Model = TOUGH2 Simulator Model + Bottom-hole temperature: 145.00 degC + Warning: the reservoir dimensions and thermo-physical properties + listed below are default values if not provided by the user. + They are only used for calculating remaining heat content. + Reservoir volume provided as input + Reservoir volume: 1000000000 m**3 + Reservoir impedance: 0.05 GPa.s/m**3 + Reservoir density: 2700.00 kg/m**3 + Reservoir thermal conductivity: 3.00 W/m/K + Reservoir heat capacity: 1050.00 J/kg/K + Reservoir porosity: 5.00 + Reservoir permeability: 6.00E-13 m**2 + Reservoir thickness: 250.00 meter + Reservoir width: 500.00 meter + Well separation: 900.00 meter + + + ***RESERVOIR SIMULATION RESULTS*** + + Maximum Production Temperature: 141.9 degC + Average Production Temperature: 140.4 degC + Minimum Production Temperature: 134.2 degC + Initial Production Temperature: 140.2 degC + Average Reservoir Heat Extraction: 14.63 MW + Production Wellbore Heat Transmission Model = Ramey Model + Average Production Well Temperature Drop: 3.1 degC + Total Average Pressure Drop: 1689.5 kPa + Average Injection Well Pressure Drop: 306.6 kPa + Average Reservoir Pressure Drop: 2580.0 kPa + Average Production Well Pressure Drop: 317.3 kPa + Average Buoyancy Pressure Drop: -1514.5 kPa + + + ***CAPITAL COSTS (M$)*** + + Drilling and completion costs: 10.97 MUSD + Drilling and completion costs per well: 5.49 MUSD + Stimulation costs: 0.00 MUSD + Surface power plant costs: 4.81 MUSD + Field gathering system costs: 1.17 MUSD + Total surface equipment costs: 5.98 MUSD + Exploration costs: 5.33 MUSD + Total capital costs: 22.28 MUSD + + + ***OPERATING AND MAINTENANCE COSTS (M$/yr)*** + + Wellfield maintenance costs: 0.22 MUSD/yr + Power plant maintenance costs: 0.35 MUSD/yr + Water costs: 0.00 MUSD/yr + Average Reservoir Pumping Cost: 0.06 MUSD/yr + Total operating and maintenance costs: 0.63 MUSD/yr + + + ***SURFACE EQUIPMENT SIMULATION RESULTS*** + + Maximum Net Heat Production: 13.45 MW + Average Net Heat Production: 13.17 MW + Minimum Net Heat Production: 12.00 MW + Initial Net Heat Production: 13.14 MW + Average Annual Heat Production: 102.97 GWh + Average Pumping Power: 0.11 MW + + ************************************************************ + * HEATING, COOLING AND/OR ELECTRICITY PRODUCTION PROFILE * + ************************************************************ + YEAR THERMAL GEOFLUID PUMP NET + DRAWDOWN TEMPERATURE POWER HEAT + (deg C) (MW) (MW) + 0 1.0000 140.22 0.1050 13.1358 + 1 1.0054 140.97 0.1047 13.2770 + 2 1.0075 141.27 0.1045 13.3321 + 3 1.0086 141.42 0.1045 13.3607 + 4 1.0093 141.52 0.1044 13.3797 + 5 1.0098 141.60 0.1044 13.3937 + 6 1.0102 141.66 0.1044 13.4046 + 7 1.0106 141.70 0.1044 13.4136 + 8 1.0109 141.74 0.1044 13.4212 + 9 1.0111 141.78 0.1043 13.4277 + 10 1.0113 141.81 0.1043 13.4335 + 11 1.0115 141.84 0.1043 13.4386 + 12 1.0117 141.86 0.1043 13.4431 + 13 1.0119 141.88 0.1043 13.4473 + 14 1.0113 141.81 0.1045 13.4332 + 15 1.0108 141.73 0.1046 13.4189 + 16 1.0106 141.70 0.1047 13.4128 + 17 1.0096 141.57 0.1049 13.3883 + 18 1.0080 141.35 0.1053 13.3468 + 19 1.0064 141.12 0.1057 13.3037 + 20 1.0044 140.84 0.1061 13.2521 + 21 1.0017 140.46 0.1068 13.1812 + 22 0.9987 140.04 0.1075 13.1024 + 23 0.9950 139.51 0.1083 13.0038 + 24 0.9905 138.89 0.1093 12.8868 + 25 0.9859 138.24 0.1104 12.7648 + 26 0.9806 137.50 0.1116 12.6267 + 27 0.9752 136.73 0.1128 12.4841 + 28 0.9690 135.88 0.1141 12.3235 + 29 0.9620 134.89 0.1157 12.1389 + + + ******************************************************************* + * ANNUAL HEATING, COOLING AND/OR ELECTRICITY PRODUCTION PROFILE * + ******************************************************************* + YEAR HEAT HEAT RESERVOIR PERCENTAGE OF + PROVIDED EXTRACTED HEAT CONTENT TOTAL HEAT MINED + (GWh/year) (GWh/year) (10^15 J) (%) + 1 104.1 115.6 212.21 0.20 + 2 104.9 116.6 211.79 0.39 + 3 105.2 116.9 211.37 0.59 + 4 105.4 117.1 210.95 0.79 + 5 105.5 117.3 210.52 0.99 + 6 105.6 117.4 210.10 1.19 + 7 105.7 117.5 209.68 1.39 + 8 105.8 117.5 209.26 1.58 + 9 105.8 117.6 208.83 1.78 + 10 105.9 117.7 208.41 1.98 + 11 105.9 117.7 207.99 2.18 + 12 106.0 117.7 207.56 2.38 + 13 106.0 117.8 207.14 2.58 + 14 105.9 117.7 206.71 2.78 + 15 105.9 117.6 206.29 2.98 + 16 105.8 117.5 205.87 3.18 + 17 105.7 117.4 205.44 3.38 + 18 105.4 117.1 205.02 3.58 + 19 105.1 116.8 204.60 3.77 + 20 104.7 116.3 204.18 3.97 + 21 104.2 115.8 203.77 4.17 + 22 103.6 115.1 203.35 4.36 + 23 102.9 114.4 202.94 4.55 + 24 102.1 113.4 202.53 4.75 + 25 101.1 112.4 202.13 4.94 + 26 100.1 111.2 201.73 5.13 + 27 99.0 110.0 201.33 5.31 + 28 97.8 108.7 200.94 5.50 + 29 96.4 107.1 200.55 5.68 + 30 71.4 79.3 200.27 5.81 + + + ******************************** + * REVENUE & CASHFLOW PROFILE * + ******************************** +Year Electricity | Heat | Cooling | Carbon | Project +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 0.00 0.00 | 0.00 -22.28 0.00 | 0.00 0.00 0.00 | 0.00 0.00 0.00 | 0.00 -22.28 -22.28 + 2 5.50 0.00 0.00 | 2.50 2.03 2.60 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.03 -20.24 + 3 5.50 0.00 0.00 | 2.50 2.05 5.23 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.05 -18.19 + 4 5.50 0.00 0.00 | 2.50 2.06 7.86 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.06 -16.13 + 5 5.50 0.00 0.00 | 2.50 2.07 10.49 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.07 -14.06 + 6 5.50 0.00 0.00 | 2.50 2.07 13.13 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.07 -11.99 + 7 5.50 0.00 0.00 | 2.50 2.07 15.77 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.07 -9.92 + 8 5.50 0.00 0.00 | 2.50 2.07 18.41 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.07 -7.84 + 9 5.50 0.00 0.00 | 2.50 2.08 21.06 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.08 -5.77 + 10 5.50 0.00 0.00 | 2.50 2.08 23.70 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.08 -3.69 + 11 5.50 0.00 0.00 | 2.50 2.08 26.35 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.08 -1.61 + 12 5.50 0.00 0.00 | 2.50 2.08 29.00 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.08 0.47 + 13 5.50 0.00 0.00 | 2.50 2.08 31.65 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.08 2.55 + 14 5.50 0.00 0.00 | 2.50 2.08 34.30 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.08 4.63 + 15 5.50 0.00 0.00 | 2.50 2.08 36.95 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.08 6.71 + 16 5.50 0.00 0.00 | 2.50 2.08 39.59 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.08 8.79 + 17 5.50 0.00 0.00 | 2.50 2.08 42.24 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.08 10.87 + 18 5.50 0.00 0.00 | 2.50 2.07 44.88 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.07 12.94 + 19 5.50 0.00 0.00 | 2.50 2.07 47.51 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.07 15.01 + 20 5.50 0.00 0.00 | 2.50 2.06 50.14 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.06 17.07 + 21 5.50 0.00 0.00 | 2.50 2.05 52.76 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.05 19.11 + 22 5.50 0.00 0.00 | 2.50 2.04 55.36 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.04 21.15 + 23 5.50 0.00 0.00 | 2.50 2.02 57.95 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.02 23.17 + 24 5.50 0.00 0.00 | 2.50 2.00 60.53 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 2.00 25.18 + 25 5.50 0.00 0.00 | 2.50 1.98 63.08 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 1.98 27.16 + 26 5.50 0.00 0.00 | 2.50 1.96 65.61 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 1.96 29.12 + 27 5.50 0.00 0.00 | 2.50 1.93 68.11 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 1.93 31.06 + 28 5.50 0.00 0.00 | 2.50 1.91 70.59 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 1.91 32.96 + 29 5.50 0.00 0.00 | 2.50 1.88 73.03 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 1.88 34.84 + 30 5.50 0.00 0.00 | 2.50 1.84 75.44 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.57 1.84 36.68 diff --git a/tests/examples/example6.txt b/tests/examples/example6.txt new file mode 100644 index 00000000..dfe84441 --- /dev/null +++ b/tests/examples/example6.txt @@ -0,0 +1,68 @@ +# Example 6: Geothermal Direct-Use Example Problem using TOUGH2 Doublet Model (Multiple Gradients) +# This example problem considers a hydrothermal reservoir simulated +# with the built-in TOUGH2 doublet model. End-use is direct-use heat. + +*** Subsurface technical parameters *** +**************************************** +Reservoir Model, 6, --- Use TOUGH2 simulator +TOUGH2 Model/File Name,Doublet, --- Use built-in Doublet TOUGH2 model +Reservoir Depth, 3, --- [km] +Number of Segments, 2, --- [-] Should be 1, 2, 3, or 4. +Gradient 1, 50, --- [deg.C/km] +Thickness 1, 1, --- [km] +Gradient 2, 40, --- [deg.C/km] +Maximum Temperature, 375, --- [deg.C] +Number of Production Wells, 1, --- [-] +Number of Injection Wells, 1, --- [-] +Production Well Diameter, 8, --- [inch] +Injection Well Diameter, 8, --- [inch] +Ramey Production Wellbore Model, 1, --- Should be 0 (disable) or 1 (enable) +Injection Wellbore Temperature Gain,0, --- [deg.C] +Production Flow Rate per Well, 50, --- [kg/s] + +--- Fracture geometry below required for reservoir models 1 and 2 +Reservoir Volume Option, 4, --- Should be 1, 2, 3, or 4. See manual for details. +Reservoir Volume, 1E9, --- [m3] (required for reservoir volume option 3 and 4 +Water Loss Fraction, 0, --- [-] (total geofluid lost)/(total geofluid produced) +Reservoir Impedance, 0.05, --- [GPa*s/m3] +Injection Temperature, 70, --- [deg.C] +Reservoir Heat Capacity, 1050, --- [J/kg/K] +Reservoir Density, 2700, --- [kg/m3] +Reservoir Thermal Conductivity, 3, --- [W/m/K] +Reservoir Porosity, 0.05, --- [-] +Reservoir Permeability, 6E-13, --- [m2] +Reservoir Thickness, 250, --- [m] +Reservoir Width, 500, --- [m] +Well Separation, 900, --- [m] + + + +*** Surface technical parameters *** +************************************ +End-Use Option, 2, --- [-] Direct-Use Heat +Circulation Pump Efficiency, 0.8, --- [-] +Utilization Factor, 0.9, --- [-] +End-Use Efficiency Factor, 0.9, --- [-] End-use efficiency for direct-use heat component +Surface Temperature, 15, --- [deg.C] +Ambient Temperature, 15, --- [deg.C] + +*** Economic/Financial Parameters *** +************************************* +Plant Lifetime, 30, --- [years] +Economic Model, 2, --- Should be 1 (FCR model), 2 (Standard LCOE/LCOH model), or 3 (Bicycle model). +Discount Rate, 0.05, --- [-] Required if Standard LCOE/LCOH model is selected. See manual for details. +Inflation Rate During Construction, 0, --- [-] +Well Drilling and Completion Capital Cost Adjustment Factor, 1, --- [-] Adjustment factor for built-in well drilling and completion capital cost correlation +Well Drilling Cost Correlation, 1, --- [-] Use built-in well drilling cost correlation #1 +Reservoir Stimulation Capital Cost Adjustment Factor, 0,--- [-] No reservoir stimulation +Surface Plant Capital Cost Adjustment Factor, 1, --- [-] Use built-in correlation as is +Field Gathering System Capital Cost Adjustment Factor, 1,--- [-] Use built-in correlation as is +Exploration Capital Cost Adjustment Factor, 1, --- [-] Use built-in correlation as is +Wellfield O&M Cost Adjustment Factor, 1, --- [-] Use built-in correlation as is +Surface Plant O&M Cost Adjustment Factor, 1, --- [-] Use built-in correlation as is +Water Cost Adjustment Factor, 1, --- [-] Use built-in correlation as is +Electricity Rate, 0.07, --- [$/kWh] Required to calculate pumping cost in direct-use or additional revenue stream in cogen option. + +*** Simulation Parameters *** +Print Output to Console, 1, --- [-] Should be 0 (don't print results to console) or 1 (print results to console) +Time steps per year, 4, --- [/year] diff --git a/tests/examples/example7.out b/tests/examples/example7.out new file mode 100644 index 00000000..4c5937f3 --- /dev/null +++ b/tests/examples/example7.out @@ -0,0 +1,238 @@ + ***************** + ***CASE REPORT*** + ***************** + +Simulation Metadata +---------------------- + GEOPHIRES Version: 3.5.2 + Simulation Date: 2024-11-26 + Simulation Time: 13:19 + Calculation Time: 12.170 sec + + ***SUMMARY OF RESULTS*** + + End-Use Option: Direct-Use Heat + Average Direct-Use Heat Production: 16.69 MW + Direct-Use heat breakeven price (LCOH): 4.97 USD/MMBTU + Number of production wells: 1 + Number of injection wells: 1 + Flowrate per production well: 50.0 kg/sec + Well depth (or total length, if not vertical): 3.0 kilometer + Geothermal gradient: 50 degC/km + + + ***ECONOMIC PARAMETERS*** + + Economic Model = Standard Levelized Cost + Interest Rate: 5.00 + Accrued financing during construction: 0.00 + Project lifetime: 30 yr + Capacity factor: 90.0 % + Project NPV: 10.94 MUSD + Project IRR: 10.44 % + Project VIR=PI=PIR: 1.46 + Project MOIC: 1.13 + Project Payback Period: 10.02 yr + + ***ENGINEERING PARAMETERS*** + + Number of Production Wells: 1 + Number of Injection Wells: 1 + Well depth (or total length, if not vertical): 3.0 kilometer + Water loss rate: 0.0 + Pump efficiency: 80.0 + Injection temperature: 70.0 degC + Production Wellbore heat transmission calculated with Ramey's model + Average production well temperature drop: 3.6 degC + Flowrate per production well: 50.0 kg/sec + Injection well casing ID: 8.000 in + Production well casing ID: 8.000 in + Number of times redrilling: 0 + + + ***RESOURCE CHARACTERISTICS*** + + Maximum reservoir temperature: 375.0 degC + Number of segments: 1 + Geothermal gradient: 50 degC/km + + + ***RESERVOIR PARAMETERS*** + + Reservoir Model = TOUGH2 Simulator Model + Bottom-hole temperature: 165.00 degC + Warning: the reservoir dimensions and thermo-physical properties + listed below are default values if not provided by the user. + They are only used for calculating remaining heat content. + Reservoir volume provided as input + Reservoir volume: 1000000000 m**3 + Reservoir impedance: 0.05 GPa.s/m**3 + Reservoir density: 2700.00 kg/m**3 + Reservoir thermal conductivity: 3.00 W/m/K + Reservoir heat capacity: 1050.00 J/kg/K + Reservoir porosity: 5.00 + Reservoir permeability: 6.00E-13 m**2 + Reservoir thickness: 250.00 meter + Reservoir width: 500.00 meter + Well separation: 900.00 meter + + + ***RESERVOIR SIMULATION RESULTS*** + + Maximum Production Temperature: 161.4 degC + Average Production Temperature: 159.0 degC + Minimum Production Temperature: 149.4 degC + Initial Production Temperature: 159.5 degC + Average Reservoir Heat Extraction: 18.55 MW + Production Wellbore Heat Transmission Model = Ramey Model + Average Production Well Temperature Drop: 3.6 degC + Total Average Pressure Drop: 1219.6 kPa + Average Injection Well Pressure Drop: 306.6 kPa + Average Reservoir Pressure Drop: 2597.4 kPa + Average Production Well Pressure Drop: 322.3 kPa + Average Buoyancy Pressure Drop: -2006.7 kPa + + + ***CAPITAL COSTS (M$)*** + + Drilling and completion costs: 10.97 MUSD + Drilling and completion costs per well: 5.49 MUSD + Stimulation costs: 0.00 MUSD + Surface power plant costs: 6.13 MUSD + Field gathering system costs: 1.14 MUSD + Total surface equipment costs: 7.27 MUSD + Exploration costs: 5.33 MUSD + Total capital costs: 23.57 MUSD + + + ***OPERATING AND MAINTENANCE COSTS (M$/yr)*** + + Wellfield maintenance costs: 0.25 MUSD/yr + Power plant maintenance costs: 0.49 MUSD/yr + Water costs: 0.00 MUSD/yr + Average Reservoir Pumping Cost: 0.04 MUSD/yr + Total operating and maintenance costs: 0.79 MUSD/yr + + + ***SURFACE EQUIPMENT SIMULATION RESULTS*** + + Maximum Net Heat Production: 17.14 MW + Average Net Heat Production: 16.69 MW + Minimum Net Heat Production: 14.89 MW + Initial Net Heat Production: 16.78 MW + Average Annual Heat Production: 130.56 GWh + Average Pumping Power: 0.08 MW + + ************************************************************ + * HEATING, COOLING AND/OR ELECTRICITY PRODUCTION PROFILE * + ************************************************************ + YEAR THERMAL GEOFLUID PUMP NET + DRAWDOWN TEMPERATURE POWER HEAT + (deg C) (MW) (MW) + 0 1.0000 159.49 0.0738 16.7804 + 1 1.0054 160.36 0.0734 16.9433 + 2 1.0076 160.70 0.0733 17.0069 + 3 1.0087 160.88 0.0732 17.0400 + 4 1.0094 161.00 0.0731 17.0618 + 5 1.0100 161.08 0.0731 17.0779 + 6 1.0104 161.15 0.0731 17.0906 + 7 1.0107 161.20 0.0730 17.1010 + 8 1.0110 161.25 0.0730 17.1097 + 9 1.0113 161.29 0.0730 17.1173 + 10 1.0115 161.33 0.0730 17.1239 + 11 1.0117 161.36 0.0730 17.1298 + 12 1.0119 161.39 0.0730 17.1350 + 13 1.0114 161.32 0.0731 17.1219 + 14 1.0114 161.32 0.0732 17.1218 + 15 1.0106 161.19 0.0734 17.0988 + 16 1.0097 161.04 0.0737 17.0705 + 17 1.0080 160.77 0.0742 17.0199 + 18 1.0061 160.47 0.0747 16.9637 + 19 1.0035 160.06 0.0755 16.8855 + 20 1.0001 159.51 0.0765 16.7835 + 21 0.9961 158.87 0.0776 16.6630 + 22 0.9920 158.22 0.0787 16.5419 + 23 0.9866 157.37 0.0802 16.3811 + 24 0.9812 156.49 0.0818 16.2173 + 25 0.9750 155.50 0.0835 16.0320 + 26 0.9680 154.39 0.0854 15.8239 + 27 0.9602 153.15 0.0875 15.5911 + 28 0.9523 151.89 0.0897 15.3545 + 29 0.9433 150.45 0.0921 15.0853 + + + ******************************************************************* + * ANNUAL HEATING, COOLING AND/OR ELECTRICITY PRODUCTION PROFILE * + ******************************************************************* + YEAR HEAT HEAT RESERVOIR PERCENTAGE OF + PROVIDED EXTRACTED HEAT CONTENT TOTAL HEAT MINED + (GWh/year) (GWh/year) (10^15 J) (%) + 1 132.9 147.7 268.79 0.20 + 2 133.9 148.7 268.26 0.40 + 3 134.2 149.1 267.72 0.60 + 4 134.4 149.4 267.18 0.80 + 5 134.6 149.5 266.65 1.00 + 6 134.7 149.7 266.11 1.20 + 7 134.8 149.8 265.57 1.40 + 8 134.9 149.8 265.03 1.60 + 9 134.9 149.9 264.49 1.80 + 10 135.0 150.0 263.95 2.00 + 11 135.0 150.0 263.41 2.20 + 12 135.1 150.1 262.87 2.40 + 13 135.1 150.1 262.33 2.60 + 14 135.0 150.0 261.79 2.80 + 15 134.9 149.9 261.25 3.00 + 16 134.7 149.7 260.71 3.20 + 17 134.4 149.3 260.17 3.40 + 18 134.0 148.9 259.64 3.60 + 19 133.4 148.3 259.10 3.80 + 20 132.7 147.5 258.57 3.99 + 21 131.9 146.5 258.04 4.19 + 22 130.9 145.5 257.52 4.38 + 23 129.8 144.2 257.00 4.58 + 24 128.5 142.8 256.49 4.77 + 25 127.1 141.3 255.98 4.96 + 26 125.6 139.6 255.48 5.14 + 27 123.9 137.6 254.98 5.33 + 28 122.0 135.6 254.49 5.51 + 29 120.0 133.3 254.01 5.69 + 30 88.6 98.5 253.66 5.82 + + + ******************************** + * REVENUE & CASHFLOW PROFILE * + ******************************** +Year Electricity | Heat | Cooling | Carbon | Project +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 0.00 0.00 | 0.00 -23.57 0.00 | 0.00 0.00 0.00 | 0.00 0.00 0.00 | 0.00 -23.57 -23.57 + 2 5.50 0.00 0.00 | 2.50 2.58 3.32 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.58 -20.99 + 3 5.50 0.00 0.00 | 2.50 2.60 6.67 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.60 -18.39 + 4 5.50 0.00 0.00 | 2.50 2.61 10.02 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.61 -15.78 + 5 5.50 0.00 0.00 | 2.50 2.62 13.39 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.62 -13.17 + 6 5.50 0.00 0.00 | 2.50 2.62 16.75 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.62 -10.55 + 7 5.50 0.00 0.00 | 2.50 2.62 20.12 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.62 -7.93 + 8 5.50 0.00 0.00 | 2.50 2.62 23.49 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.62 -5.30 + 9 5.50 0.00 0.00 | 2.50 2.63 26.86 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.63 -2.67 + 10 5.50 0.00 0.00 | 2.50 2.63 30.23 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.63 -0.05 + 11 5.50 0.00 0.00 | 2.50 2.63 33.61 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.63 2.58 + 12 5.50 0.00 0.00 | 2.50 2.63 36.98 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.63 5.21 + 13 5.50 0.00 0.00 | 2.50 2.63 40.36 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.63 7.85 + 14 5.50 0.00 0.00 | 2.50 2.63 43.74 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.63 10.48 + 15 5.50 0.00 0.00 | 2.50 2.63 47.11 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.63 13.11 + 16 5.50 0.00 0.00 | 2.50 2.63 50.48 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.63 15.73 + 17 5.50 0.00 0.00 | 2.50 2.62 53.85 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.62 18.36 + 18 5.50 0.00 0.00 | 2.50 2.61 57.21 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.61 20.97 + 19 5.50 0.00 0.00 | 2.50 2.60 60.56 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.60 23.58 + 20 5.50 0.00 0.00 | 2.50 2.59 63.90 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.59 26.17 + 21 5.50 0.00 0.00 | 2.50 2.57 67.21 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.57 28.74 + 22 5.50 0.00 0.00 | 2.50 2.55 70.51 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.55 31.29 + 23 5.50 0.00 0.00 | 2.50 2.53 73.78 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.53 33.82 + 24 5.50 0.00 0.00 | 2.50 2.50 77.03 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.50 36.32 + 25 5.50 0.00 0.00 | 2.50 2.47 80.24 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.47 38.79 + 26 5.50 0.00 0.00 | 2.50 2.43 83.42 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.43 41.22 + 27 5.50 0.00 0.00 | 2.50 2.39 86.56 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.39 43.62 + 28 5.50 0.00 0.00 | 2.50 2.35 89.66 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.35 45.97 + 29 5.50 0.00 0.00 | 2.50 2.30 92.71 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.30 48.27 + 30 5.50 0.00 0.00 | 2.50 2.25 95.71 | 2.50 0.00 0.00 | 0.00 0.00 0.00 | 0.75 2.25 50.53 diff --git a/tests/examples/example7.txt b/tests/examples/example7.txt new file mode 100644 index 00000000..5626ef9e --- /dev/null +++ b/tests/examples/example7.txt @@ -0,0 +1,66 @@ +# Example 7: Geothermal Direct-Use Example Problem using TOUGH2 Doublet Model (Single Gradient) +# This example problem considers a hydrothermal reservoir simulated +# with the built-in TOUGH2 doublet model. End-use is direct-use heat. + +*** Subsurface technical parameters *** +**************************************** +Reservoir Model, 6, --- Use TOUGH2 simulator +TOUGH2 Model/File Name,Doublet, --- Use built-in Doublet TOUGH2 model +Reservoir Depth, 3, --- [km] +Number of Segments, 1, --- [-] Should be 1, 2, 3, or 4. +Gradient 1, 50, --- [deg.C/km] +Maximum Temperature, 375, --- [deg.C] +Number of Production Wells, 1, --- [-] +Number of Injection Wells, 1, --- [-] +Production Well Diameter, 8, --- [inch] +Injection Well Diameter, 8, --- [inch] +Ramey Production Wellbore Model, 1, --- Should be 0 (disable) or 1 (enable) +Injection Wellbore Temperature Gain,0, --- [deg.C] +Production Flow Rate per Well, 50, --- [kg/s] + +--- Fracture geometry below required for reservoir models 1 and 2 +Reservoir Volume Option, 4, --- Should be 1, 2, 3, or 4. See manual for details. +Reservoir Volume, 1E9, --- [m3] (required for reservoir volume option 3 and 4 +Water Loss Fraction, 0, --- [-] (total geofluid lost)/(total geofluid produced) +Reservoir Impedance, 0.05, --- [GPa*s/m3] +Injection Temperature, 70, --- [deg.C] +Reservoir Heat Capacity, 1050, --- [J/kg/K] +Reservoir Density, 2700, --- [kg/m3] +Reservoir Thermal Conductivity, 3, --- [W/m/K] +Reservoir Porosity, 0.05, --- [-] +Reservoir Permeability, 6E-13, --- [m2] +Reservoir Thickness, 250, --- [m] +Reservoir Width, 500, --- [m] +Well Separation, 900, --- [m] + + + +*** Surface technical parameters *** +************************************ +End-Use Option, 2, --- [-] Direct-Use Heat +Circulation Pump Efficiency, 0.8, --- [-] +Utilization Factor, 0.9, --- [-] +End-Use Efficiency Factor, 0.9, --- [-] End-use efficiency for direct-use heat component +Surface Temperature, 15, --- [deg.C] +Ambient Temperature, 15, --- [deg.C] + +*** Economic/Financial Parameters *** +************************************* +Plant Lifetime, 30, --- [years] +Economic Model, 2, --- Should be 1 (FCR model), 2 (Standard LCOE/LCOH model), or 3 (Bicycle model). +Discount Rate, 0.05, --- [-] Required if Standard LCOE/LCOH model is selected. See manual for details. +Inflation Rate During Construction, 0, --- [-] +Well Drilling and Completion Capital Cost Adjustment Factor, 1, --- [-] Adjustment factor for built-in well drilling and completion capital cost correlation +Well Drilling Cost Correlation, 1, --- [-] Use built-in well drilling cost correlation #1 +Reservoir Stimulation Capital Cost Adjustment Factor, 0,--- [-] No reservoir stimulation +Surface Plant Capital Cost Adjustment Factor, 1, --- [-] Use built-in correlation as is +Field Gathering System Capital Cost Adjustment Factor, 1,--- [-] Use built-in correlation as is +Exploration Capital Cost Adjustment Factor, 1, --- [-] Use built-in correlation as is +Wellfield O&M Cost Adjustment Factor, 1, --- [-] Use built-in correlation as is +Surface Plant O&M Cost Adjustment Factor, 1, --- [-] Use built-in correlation as is +Water Cost Adjustment Factor, 1, --- [-] Use built-in correlation as is +Electricity Rate, 0.07, --- [$/kWh] Required to calculate pumping cost in direct-use or additional revenue stream in cogen option. + +*** Simulation Parameters *** +Print Output to Console, 1, --- [-] Should be 0 (don't print results to console) or 1 (print results to console) +Time steps per year, 4, --- [/year] diff --git a/tests/test_geophires_x.py b/tests/test_geophires_x.py index 49689ae9..dd886b7d 100644 --- a/tests/test_geophires_x.py +++ b/tests/test_geophires_x.py @@ -161,6 +161,8 @@ def get_output_file_for_example(example_file: str): lambda example_file_path: example_file_path.startswith( ('example', 'Beckers_et_al', 'SUTRA', 'Wanju', 'Fervo', 'S-DAC-GT') ) + # TOUGH not enabled for testing - see https://github.com/NREL/GEOPHIRES-X/issues/318 + and not example_file_path.startswith(('example6.txt', 'example7.txt')) and '.out' not in example_file_path, self._list_test_files_dir(test_files_dir='examples'), )