GEOPHIRES-X Parameters ========== .. contents:: Input Parameters ################ Schema: `geophires-request.json `__ Reservoir --------- .. list-table:: Reservoir Parameters :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type - Default Value - Min - Max * - Reservoir Model - 0: Simple cylindrical; 1: Multiple Parallel Fractures; 2: 1-D Linear Heat Sweep; 3: Single Fracture m/A Thermal Drawdown; 4: Annual Percentage Thermal Drawdown; 5: User-Provided Temperature Profile; 6: TOUGH2 Simulator; 7: SUTRA; 8: SBT - None - integer - 4 - 0 - 8 * - Reservoir Depth - Depth of the reservoir - kilometer - number - 3.0 - 0.1 - 15 * - Maximum Temperature - Maximum allowable reservoir temperature (e.g. due to drill bit or logging tools constraints). GEOPHIRES will cap the drilling depth to stay below this maximum temperature. - degC - number - 400.0 - 50 - 600 * - Number of Segments - Number of rock segments from surface to reservoir depth with specific geothermal gradient - None - integer - 1 - 1 - 4 * - Gradients - Geothermal gradient(s) - degC/km - array - [0.05, 0.0, 0.0, 0.0] - 0.0 - 500.0 * - Gradient 1 - Geothermal gradient 1 in rock segment 1 - degC/km - number - 50 - 0.0 - 500.0 * - Gradient 2 - Geothermal gradient 2 in rock segment 2 - degC/km - number - 0.0 - 0.0 - 500.0 * - Gradient 3 - Geothermal gradient 3 in rock segment 3 - degC/km - number - 0.0 - 0.0 - 500.0 * - Gradient 4 - Geothermal gradient 4 in rock segment 4 - degC/km - number - 0.0 - 0.0 - 500.0 * - Thicknesses - Thicknesses of rock segments - kilometer - array - [100000.0, 0.01, 0.01, 0.01, 0.01] - 0.01 - 100.0 * - Thickness 1 - Thickness of rock segment 1 - kilometer - number - 2.0 - 0.01 - 100.0 * - Thickness 2 - Thickness of rock segment 2 - kilometer - number - 0.01 - 0.01 - 100.0 * - Thickness 3 - Thickness of rock segment 3 - kilometer - number - 0.01 - 0.01 - 100.0 * - Thickness 4 - Thickness of rock segment 4 - kilometer - number - 0.01 - 0.01 - 100.0 * - Reservoir Volume Option - Specifies how the reservoir volume, and fracture distribution (for reservoir models 1 and 2) are calculated. The reservoir volume is used by GEOPHIRES to estimate the stored heat in place. The fracture distribution is needed as input for the EGS fracture-based reservoir models 1 and 2. 1: FRAC_NUM_SEP: Specify number of fractures and fracture separation; 2: RES_VOL_FRAC_SEP: Specify reservoir volume and fracture separation; 3: RES_VOL_FRAC_NUM: Specify reservoir volume and number of fractures; 4: RES_VOL_ONLY: Specify reservoir volume only - None - integer - 3 - 1 - 4 * - Fracture Shape - Specifies the shape of the (identical) fractures in a fracture-based reservoir: 1: Circular fracture with known area; 2: Circular fracture with known diameter; 3: Square; 4: Rectangular - None - integer - 1 - 1 - 4 * - Fracture Area - Effective heat transfer area per fracture - m**2 - number - 250000.0 - 1 - 100000000.0 * - Fracture Height - Diameter (if fracture shape = 2) or height (if fracture shape = 3 or 4) of each fracture - meter - number - 500.0 - 1 - 10000 * - Fracture Width - Width of each fracture - meter - number - 500.0 - 1 - 10000 * - Number of Fractures - Number of identical parallel fractures in EGS fracture-based reservoir model. - None - integer - 10 - 1 - 149 * - Fracture Separation - Separation of identical parallel fractures with uniform spatial distribution in EGS fracture-based reservoir - meter - number - 50.0 - 1 - 10000.0 * - Reservoir Volume - Geothermal reservoir volume - m**3 - number - 125000000.0 - 10 - 1000000000000.0 * - Water Loss Fraction - Fraction of water lost in the reservoir defined as (total geofluid lost)/(total geofluid produced). - % - number - 0.0 - 0.0 - 0.99 * - Reservoir Heat Capacity - Constant and uniform reservoir rock heat capacity - J/kg/K - number - 1000.0 - 100 - 10000 * - Reservoir Density - Constant and uniform reservoir rock density - kg/m**3 - number - 2700.0 - 100 - 10000 * - Reservoir Thermal Conductivity - Constant and uniform reservoir rock thermal conductivity - W/m/K - number - 3.0 - 0.01 - 100 * - Reservoir Permeability - Constant and uniform reservoir permeability - m**2 - number - 1e-13 - 1e-20 - 1e-05 * - Reservoir Porosity - Constant and uniform reservoir porosity - - number - 0.04 - 0.001 - 0.99 * - Surface Temperature - Surface temperature used for calculating bottom-hole temperature (with geothermal gradient and reservoir depth) - degC - number - 15.0 - -50 - 50 * - Drawdown Parameter - specify the thermal drawdown for reservoir model 3 and 4 - 1/year - number - 0.005 - 0 - 0.2 * - Cylindrical Reservoir Input Depth - Depth of the inflow end of a cylindrical reservoir - kilometer - number - 3.0 - 0.1 - 15 * - Cylindrical Reservoir Output Depth - Depth of the outflow end of a cylindrical reservoir - kilometer - number - 3.0 - 0.1 - 15 * - Cylindrical Reservoir Length - Length of cylindrical reservoir - kilometer - number - 4.0 - 0.1 - 10.0 * - Cylindrical Reservoir Radius of Effect - The radius of effect - the distance into the rock from the center of the cylinder that will be perturbed by at least 1 C - meter - number - 30.0 - 0 - 1000.0 * - Cylindrical Reservoir Radius of Effect Factor - The radius of effect reduction factor - to account for the fact that we cannot extract 100% of the heat in the cylinder. - - number - 1.0 - 0.0 - 10.0 * - Drilled length - Depth of the inflow end of a cyclindrical reservoir - kilometer - number - 0.0 - 0.0 - 150 * - Flowrate Model - Must be 1 or 2. '1' means the user provides a constant mass flow rate. '1' means the user provides an excel file with a mass flow rate profile. - None - integer - - 1 - 2 * - Flowrate File - Excel file with a mass flow rate profile - None - string - - - * - Injection Temperature Model - Must be 1 or 2. '1' means the user provides a constant injection temperature. '1' means the user provides an excel file with an injection temperature profile. - None - integer - - 1 - 2 * - Injection Temperature File - Excel file with an injection temperature profile - None - string - - - * - SBT Accuracy Desired - Must be 1, 2, 3, 4 or 5 with 1 lowest accuracy and 5 highest accuracy. Lowest accuracy runs fastest. Accuracy level impacts number of discretizations for numerical integration and decision tree thresholds in SBT algorithm. - None - integer - 1 - 1 - 5 * - SBT Percent Implicit Euler Scheme - Should be between 0 and 1. Most stable is setting it to 1 which results in a fully implicit Euler scheme when calculating the fluid temperature at each time step. With a value of 0, the convective term is modelled using explicit Euler. A value of 0.5 would model the convective term 50% explicit and 50% implicit, which may be slightly more accurate than fully implicit. - - number - 1.0 - 0.0 - 1.0 * - SBT Initial Timestep Count - The number of timesteps in the first ~3 hours of model - None - integer - 5 - 1 - 150 * - SBT Final Timestep Count - The number of timesteps after the first ~3 hours of model - None - number - 70 - 5 - 1000 * - SBT Initial to Final Timestep Transition - The time in secs at which the time arrays switches from closely spaced linear to logarithmic - sec - number - 9900 - 1 - 40000000 * - SBT Generate Wireframe Graphics - Switch to control the generation of a wireframe drawing of a SBT wells configuration - None - boolean - False - - * - SUTRA Annual Heat File Name - SUTRA file with heat stored, heat supplied and efficiency for each year - None - string - None - - * - SUTRA Heat Budget File Name - SUTRA file with target heat and simulated heat for each SUTRA time step over lifetime - None - string - None - - * - SUTRA Balance and Storage Well Output File Name - SUTRA file with well flow rate and temperature for each SUTRA time step over lifetime - None - string - None - - * - TOUGH2 Executable Path - - None - string - xt2_eos1.exe - - * - TOUGH2 Model/File Name - File name of reservoir output in case reservoir model 5 is selected - None - string - None - - * - Reservoir Thickness - Reservoir thickness for built-in TOUGH2 doublet reservoir model - meter - number - 0.0 - 10 - 10000 * - Reservoir Width - Reservoir width for built-in TOUGH2 doublet reservoir model - meter - number - 0.0 - 10 - 10000 Well Bores ---------- .. list-table:: Well Bores Parameters :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type - Default Value - Min - Max * - Number of Production Wells - Number of (identical) production wells - None - integer - 1 - 1 - 200 * - Number of Injection Wells - Number of (identical) injection wells - None - integer - 1 - 0 - 200 * - Production Well Diameter - Inner diameter of production wellbore (assumed constant along the wellbore) to calculate frictional pressure drop and wellbore heat transmission with Rameys model - in - number - 8.0 - 1.0 - 30.0 * - Injection Well Diameter - Inner diameter of production wellbore (assumed constant along the wellbore) to calculate frictional pressure drop and wellbore heat transmission with Rameys model - in - number - 8.0 - 1.0 - 30.0 * - Ramey Production Wellbore Model - Select whether to use Rameys model to estimate the geofluid temperature drop in the production wells - None - boolean - True - - * - Production Wellbore Temperature Drop - Specify constant production well geofluid temperature drop in case Rameys model is disabled. - degC - number - 5.0 - -5.0 - 50.0 * - Injection Wellbore Temperature Gain - Specify constant injection well geofluid temperature gain. - degC - number - 0.0 - -5.0 - 50.0 * - Production Flow Rate per Well - Geofluid flow rate per production well. - kg/sec - number - 50.0 - 1.0 - 500.0 * - Reservoir Impedance - Reservoir resistance to flow per well-pair. For EGS-type reservoirs when the injection well is in hydraulic communication with the production well, this parameter specifies the overall pressure drop in the reservoir between injection well and production well (see docs) - GPa.s/m**3 - number - 1000.0 - 0.0001 - 10000.0 * - Well Separation - Well separation for built-in TOUGH2 doublet reservoir model - meter - number - 1000.0 - 10.0 - 10000.0 * - Injection Temperature - Constant geofluid injection temperature at injection wellhead. - degC - number - 70.0 - 0.0 - 200.0 * - Reservoir Hydrostatic Pressure - Reservoir hydrostatic far-field pressure. Default value is calculated with built-in modified Xie-Bloomfield-Shook equation (DOE, 2016). - kPa - number - 29430 - 100.0 - 100000.0 * - Production Wellhead Pressure - Constant production wellhead pressure; Required if specifying productivity index - kPa - number - 446.02 - 0.0 - 10000.0 * - Injectivity Index - Injectivity index defined as ratio of injection well flow rate over injection well outflow pressure drop (flowing bottom hole pressure - hydrostatic reservoir pressure). - kg/sec/bar - number - 10.0 - 0.01 - 10000.0 * - Productivity Index - Productivity index defined as ratio of production well flow rate over production well inflow pressure drop (see docs) - kg/sec/bar - number - 10.0 - 0.01 - 10000.0 * - Maximum Drawdown - Maximum allowable thermal drawdown before redrilling of all wells into new reservoir (most applicable to EGS-type reservoirs with heat farming strategies). E.g. a value of 0.2 means that all wells are redrilled after the production temperature (at the wellhead) has dropped by 20% of its initial temperature - - number - 1.0 - 0.0 - 1.0 * - Is AGS - Set to true if the model is for an Advanced Geothermal System (AGS) - None - boolean - False - - * - Overpressure Percentage - enter the amount of pressure over the hydrostatic pressure in the reservoir (100%=hydrostatic) - % - number - 100.0 - -1.8e+30 - 1.8e+30 * - Overpressure Depletion Rate - enter the amount of pressure over the hydrostatic pressure in the reservoir (100%=hydrostatic) - %/yr - number - 0.0 - -1.8e+30 - 1.8e+30 * - Injection Reservoir Temperature - enter the temperature of the injection reservoir (100 C) - degC - number - 100.0 - -1.8e+30 - 1.8e+30 * - Injection Reservoir Depth - enter the depth of the injection reservoir (1000 m) - meter - number - 1000.0 - -1.8e+30 - 1.8e+30 * - Injection Reservoir Initial Pressure - enter the depth of the injection reservoir initial pressure (use lithostatic pressure) - kPa - number - 0.0 - -1.8e+30 - 1.8e+30 * - Injection Reservoir Inflation Rate - enter the rate at which the pressure increases per year in the injection reservoir (1000 kPa/yr) - kPa/yr - number - 1000.0 - -1.8e+30 - 1.8e+30 * - Closed-loop Configuration - 1: utube; 2: coaxial; 3: vertical; 4: L; 5: EavorLoop - None - integer - 3 - 1 - 5 * - Well Geometry Configuration - 1: utube; 2: coaxial; 3: vertical; 4: L; 5: EavorLoop - None - integer - 3 - 1 - 5 * - Water Thermal Conductivity - Water Thermal Conductivity - W/m/K - number - 0.6 - 0.0 - 100.0 * - Heat Transfer Fluid - 1: water; 2: sCO2 - None - integer - 1 - 1 - 2 * - Nonvertical Length per Multilateral Section - - meter - number - 1000.0 - 50.0 - 20000.0 * - Nonvertical Wellbore Diameter - Non-vertical Wellbore Diameter - meter - number - 0.156 - 0.01 - 100.0 * - Number of Multilateral Sections - Number of Nonvertical Wellbore Sections - None - integer - 0 - 0 - 100 * - Multilaterals Cased - If set to True, casing & cementing are assumed to comprise 50% of drilling costs (doubling cost compared to uncased). - None - boolean - False - - * - Closed Loop Calculation Start Year - Closed Loop Calculation Start Year - yr - number - 0.01 - 0.01 - 100.0 * - Vertical Section Length - length/depth to the bottom of the vertical wellbores - meter - number - 2000.0 - 0.01 - 10000.0 * - Vertical Wellbore Spacing - Horizontal distance between vertical wellbores - meter - number - 100.0 - 0.01 - 10000.0 * - Lateral Spacing - Horizontal distance between laterals - meter - number - 100.0 - 0.01 - 10000.0 * - Lateral Inclination Angle - Inclination of the lateral section, where 0 degrees would mean vertical while 90 degrees is pure horizontal - degrees - number - 20.0 - 0.0 - 89.999999 * - Discretization Length - distance between sample point along length of model - meter - number - 250.0 - 0.01 - 10000.0 * - Junction Depth - vertical depth where the different laterals branch out (where the multilateral section starts, second deepest depth of model) - meter - number - 4000.0 - 1000 - 15000.0 * - Lateral Endpoint Depth - vertical depth where the lateral section ends (tip of the multilateral section, deepest depth of model) - meter - number - 7000.0 - 1000 - 15000.0 Surface Plant ------------- .. list-table:: Surface Plant Parameters :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type - Default Value - Min - Max * - End-Use Option - Select the end-use application of the geofluid heat: 1: Electricity; 2: Direct-Use Heat; 31: Cogeneration Topping Cycle, Heat sales considered as extra income; 32: Cogeneration Topping Cycle, Electricity sales considered as extra income; 41: Cogeneration Bottoming Cycle, Heat sales considered as extra income; 42: Cogeneration Bottoming Cycle, Electricity sales considered as extra income; 51: Cogeneration Parallel Cycle, Heat sales considered as extra income; 52: Cogeneration Parallel Cycle, Electricity sales considered as extra income - None - integer - 1 - 1 - 52 * - Power Plant Type - Specify the type of physical plant. 1: Subcritical ORC; 2: Supercritical ORC; 3: Single-Flash; 4: Double-Flash; 5: Absorption Chiller; 6: Heat Pump; 7: District Heating; 8: Reservoir Thermal Energy Storage; 9: Industrial - None - integer - 1 - 1 - 9 * - Circulation Pump Efficiency - Specify the overall efficiency of the injection and production well pumps - % - number - 0.75 - 0.1 - 1.0 * - Utilization Factor - Ratio of the time the plant is running in normal production in a 1-year time period. Synonymous with capacity factor. - - number - 0.9 - 0.1 - 1.0 * - End-Use Efficiency Factor - Constant thermal efficiency of the direct-use application - - number - 0.9 - 0.1 - 1.0 * - CHP Fraction - Fraction of produced geofluid flow rate going to direct-use heat application in CHP parallel cycle - - number - 0.5 - 0.0001 - 0.9999 * - CHP Bottoming Entering Temperature - Power plant entering geofluid temperature used in CHP bottoming cycle - degC - number - 150.0 - 0 - 400 * - Ambient Temperature - Ambient (or dead-state) temperature used for calculating power plant utilization efficiency - degC - number - 15.0 - -50 - 50 * - Plant Lifetime - System lifetime - yr - integer - 30 - 1 - 100 * - Surface Piping Length - - kilometer - number - 0.0 - 0 - 100 * - Plant Outlet Pressure - Constant plant outlet pressure equal to injection well pump(s) suction pressure - kPa - number - 100.0 - 0.01 - 15000.0 * - Electricity Rate - Price of electricity to calculate pumping costs in direct-use heat only mode or revenue from electricity sales in CHP mode. - USD/kWh - number - 0.07 - 0.0 - 1.0 * - Heat Rate - Price of heat to calculate revenue from heat sales in CHP mode. - USD/kWh - number - 0.02 - 0.0 - 1.0 * - Construction Years - Number of years spent in construction (assumes whole years, no fractions). Capital costs are spread evenly over constructions years e.g. if total capital costs are $500M and there are 2 construction years, then $250M will be spent in both the first and second construction years. - None - integer - 1 - 1 - 14 * - Working Fluid Heat Capacity - Heat capacity of the working fluid - J/kg/K - number - 4200.0 - 0.0 - 10000.0 * - Working Fluid Density - Density of the working fluid - kg/m**3 - number - 1000.0 - 0.0 - 10000.0 * - Working Fluid Thermal Conductivity - Thermal conductivity of the working fluid - W/m/K - number - 0.68 - 0.0 - 10.0 * - Working Fluid Dynamic Viscosity - Dynamic viscosity of the working fluid - PaSec - number - 0.0006 - 0.0 - 1 * - Dead-state Pressure - - Pa - number - 100000.0 - 80000.0 - 110000.0 * - Isentropic Efficiency for CO2 Turbine - - - number - 0.9 - 0.8 - 1.0 * - Generator Conversion Efficiency - - - number - 0.98 - 0.8 - 1.0 * - Isentropic Efficiency for CO2 Compressor - - - number - 0.9 - 0.8 - 1.0 * - CO2 Temperature Decline with Cooling - - degC - number - 12.0 - 0.0 - 15.0 * - CO2 Turbine Outlet Pressure - - bar - number - 81.0 - 75.0 - 200.0 Economics --------- .. list-table:: Economics Parameters :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type - Default Value - Min - Max * - Economic Model - Specify the economic model to calculate the levelized cost of energy. 1: Fixed Charge Rate (FCR); 2: Standard Levelized Cost; 3: BICYCLE; 4: Simple (CLGS); 5: SAM Single Owner PPA - None - integer - 2 - 1 - 5 * - Reservoir Stimulation Capital Cost - Total reservoir stimulation capital cost - MUSD - number - -1.0 - 0 - 1000 * - Reservoir Stimulation Capital Cost Adjustment Factor - Multiplier for built-in reservoir stimulation capital cost correlation - - number - 1.0 - 0 - 10 * - Exploration Capital Cost - Total exploration capital cost - MUSD - number - -1.0 - 0 - 100 * - Exploration Capital Cost Adjustment Factor - Multiplier for built-in exploration capital cost correlation - - number - 1.0 - 0 - 10 * - Well Drilling and Completion Capital Cost - Well Drilling and Completion Capital Cost - MUSD - number - -1.0 - 0 - 200 * - Injection Well Drilling and Completion Capital Cost - Injection Well Drilling and Completion Capital Cost - MUSD - number - -1.0 - 0 - 200 * - Well Drilling and Completion Capital Cost Adjustment Factor - Well Drilling and Completion Capital Cost Adjustment Factor. Applies to production wells; also applies to injection wells unless a value is provided for Injection Well Drilling and Completion Capital Cost Adjustment Factor. - - number - 1.0 - 0 - 10 * - Injection Well Drilling and Completion Capital Cost Adjustment Factor - Injection Well Drilling and Completion Capital Cost Adjustment Factor. If not provided, this value will be set automatically to the same value as Well Drilling and Completion Capital Cost Adjustment Factor. - - number - 1.0 - 0 - 10 * - Wellfield O&M Cost - Total annual wellfield O&M cost - MUSD/yr - number - -1.0 - 0 - 100 * - Wellfield O&M Cost Adjustment Factor - Multiplier for built-in wellfield O&M cost correlation - - number - 1.0 - 0 - 10 * - Surface Plant Capital Cost - Total surface plant capital cost - MUSD - number - -1.0 - 0 - 1000 * - Surface Plant Capital Cost Adjustment Factor - Multiplier for built-in surface plant capital cost correlation - - number - 1.0 - 0 - 10 * - Field Gathering System Capital Cost - Total field gathering system capital cost - MUSD - number - -1.0 - 0 - 100 * - Field Gathering System Capital Cost Adjustment Factor - Multiplier for built-in field gathering system capital cost correlation - - number - 1.0 - 0 - 10 * - Surface Plant O&M Cost - Total annual surface plant O&M cost - MUSD/yr - number - -1.0 - 0 - 100 * - Surface Plant O&M Cost Adjustment Factor - Multiplier for built-in surface plant O&M cost correlation - - number - 1.0 - 0 - 10 * - Water Cost - Total annual make-up water cost - MUSD/yr - number - -1.0 - 0 - 100 * - Water Cost Adjustment Factor - Multiplier for built-in make-up water cost correlation - - number - 1.0 - 0 - 10 * - Total Capital Cost - Total initial capital cost. - MUSD - number - -1.0 - 0 - 1000 * - Total O&M Cost - Total initial O&M cost. - MUSD/yr - number - -1.0 - 0 - 100 * - Time steps per year - Number of internal simulation time steps per year - None - integer - 4 - 1 - 100 * - Fixed Charge Rate - Fixed charge rate (FCR) used in the Fixed Charge Rate Model - - number - 0.1 - 0.0 - 1.0 * - Discount Rate - Discount rate used in the Standard Levelized Cost Model and SAM Economic Models. Discount Rate is synonymous with Fixed Internal Rate. If one is provided, the other's value will be automatically set to the same value. - - number - 0.07 - 0.0 - 1.0 * - Discount Initial Year Cashflow - Whether to discount cashflow in the initial project year when calculating NPV (Net Present Value). The default value of False conforms to NREL's standard convention for NPV calculation (Short W et al, 1995. https://www.nrel.gov/docs/legosti/old/5173.pdf). A value of True will, by contrast, cause NPV calculation to follow the convention used by Excel, Google Sheets, and other common spreadsheet software. Although NREL's NPV convention may typically be considered more technically correct, Excel-style NPV calculation might be preferred for familiarity or compatibility with existing business processes. See https://github.com/NREL/GEOPHIRES-X/discussions/344 for further details. - None - boolean - False - - * - Fraction of Investment in Bonds - Fraction of geothermal project financing through bonds (debt). - - number - 0.5 - 0.0 - 1.0 * - Inflated Bond Interest Rate - Inflated bond interest rate (see docs) - - number - 0.05 - 0.0 - 1.0 * - Inflated Equity Interest Rate - Inflated equity interest rate (see docs) - - number - 0.1 - 0.0 - 1.0 * - Inflation Rate - Inflation rate - - number - 0.02 - 0.0 - 1.0 * - Combined Income Tax Rate - Combined income tax rate (see docs) - - number - 0.02 - 0.0 - 1.0 * - Gross Revenue Tax Rate - Gross revenue tax rate (see docs) - - number - 0.02 - 0.0 - 1.0 * - Investment Tax Credit Rate - Investment tax credit rate (see docs) - - number - 0.0 - 0.0 - 1.0 * - Property Tax Rate - Property tax rate (see docs) - - number - 0.0 - 0.0 - 1.0 * - Inflation Rate During Construction - For SAM Economic Models, this value is treated as an indirect EPC capital cost percentage. - % - number - 0.0 - 0.0 - 1.0 * - Well Drilling Cost Correlation - Select the built-in well drilling and completion cost correlation: 1: vertical small diameter, baseline; 2: deviated small diameter, baseline; 3: vertical large diameter, baseline; 4: deviated large diameter, baseline; 5: Simple (per-meter cost); 6: vertical small diameter, intermediate1; 7: vertical small diameter, intermediate2; 8: deviated small diameter, intermediate1; 9: deviated small diameter, intermediate2; 10: vertical large diameter, intermediate1; 11: vertical large diameter, intermediate2; 12: deviated large diameter, intermediate1; 13: deviated large diameter, intermediate2; 14: vertical open-hole, small diameter, ideal; 15: deviated liner, small diameter, ideal; 16: vertical open-hole, large diameter, ideal; 17: deviated liner, large diameter, ideal. Baseline correlations (1-4) are from NREL's 2025 cost curve update. Intermediate and ideal correlations (6-17) are from GeoVision. - None - integer - 10 - 1 - 17 * - Do AddOn Calculations - Set to true if you want the add-on economics calculations to be made - None - boolean - False - - * - Do Carbon Price Calculations - Set to true if you want the Carbon Credit economics calculations to be made - None - boolean - False - - * - Do S-DAC-GT Calculations - Set to true if you want the S-DAC-GT economics calculations to be made - None - boolean - False - - * - All-in Vertical Drilling Costs - Set user specified all-in cost per meter of vertical drilling, including drilling, casing, cement, insulated insert - USD/m - number - 1000.0 - 0.0 - 10000.0 * - All-in Nonvertical Drilling Costs - Set user specified all-in cost per meter of non-vertical drilling, including drilling, casing, cement, insulated insert - USD/m - number - 1300.0 - 0.0 - 15000.0 * - Absorption Chiller Capital Cost - Absorption chiller capital cost - MUSD - number - 5 - 0 - 100 * - Absorption Chiller O&M Cost - Absorption chiller O&M cost - MUSD/yr - number - 1 - 0 - 100 * - Heat Pump Capital Cost - Heat pump capital cost - MUSD - number - 5 - 0 - 100 * - Peaking Fuel Cost Rate - Price of peaking fuel for peaking boilers - USD/kWh - number - 0.034 - 0.0 - 1.0 * - Peaking Boiler Efficiency - Peaking boiler efficiency - - number - 0.85 - 0 - 1 * - District Heating Piping Cost Rate - District heating piping cost rate ($/m) - USD/m - number - 1200 - 0 - 10000 * - Total District Heating Network Cost - Total district heating network cost ($M) - MUSD - number - 10 - 0 - 1000 * - District Heating O&M Cost - Total annual district heating O&M cost ($M/year) - MUSD/yr - number - 1 - 0 - 100 * - District Heating Network Piping Length - District heating network piping length (km) - kilometer - number - 10.0 - 0 - 1000 * - District Heating Road Length - District heating road length (km) - kilometer - number - 10.0 - 0 - 1000 * - District Heating Land Area - District heating land area (km2) - km**2 - number - 10.0 - 0 - 1000 * - District Heating Population - Specify the population in the district heating network - None - number - 200 - 0 - 1000000 * - Starting Heat Sale Price - - USD/kWh - number - 0.025 - 0 - 100 * - Ending Heat Sale Price - - USD/kWh - number - 0.025 - 0 - 100 * - Heat Escalation Start Year - Number of years after start of project before start of escalation - yr - integer - 5 - 0 - 100 * - Heat Escalation Rate Per Year - additional cost per year of price after escalation starts - USD/kWh - number - 0.0 - 0.0 - 100.0 * - Starting Electricity Sale Price - - USD/kWh - number - 0.055 - 0 - 100 * - Ending Electricity Sale Price - The maximum price to which the electricity sale price can escalate. For example, if Starting Electricity Sale Price = 0.10 USD/kWh and Electricity Escalation Rate = 0.01 USD/kWh/yr: Electricity Price will reach 0.15 USD/kWh after 4 years of escalation. The price will then remain at 0.15 USD/kWh for the remaining years of the project lifetime. If the Ending Electricity Sale Price is not reached by escalation during the project lifetime, then the value will have no effect beyond allowing escalation to occur every year. - USD/kWh - number - 0.055 - 0 - 100 * - Electricity Escalation Start Year - Number of years after start of project before start of escalation - yr - integer - 5 - 0 - 100 * - Electricity Escalation Rate Per Year - additional cost per year of price after escalation starts - USD/kWh - number - 0.0 - 0.0 - 100.0 * - Starting Cooling Sale Price - - USD/kWh - number - 0.025 - 0 - 100 * - Ending Cooling Sale Price - - USD/kWh - number - 0.025 - 0 - 100 * - Cooling Escalation Start Year - Number of years after start of project before start of escalation - yr - integer - 5 - 0 - 100 * - Cooling Escalation Rate Per Year - additional cost per year of price after escalation starts - USD/kWh - number - 0.0 - 0.0 - 100.0 * - Starting Carbon Credit Value - - USD/lb - number - 0.0 - 0 - 1000 * - Ending Carbon Credit Value - - USD/lb - number - 0.0 - 0 - 1000 * - Carbon Escalation Start Year - Number of years after start of project before start of Carbon incentives - yr - integer - 0 - 0 - 100 * - Carbon Escalation Rate Per Year - additional value per year of price after escalation starts - USD/lb - number - 0.0 - 0.0 - 100.0 * - Current Grid CO2 production - CO2 intensity of the grid (how much CO2 is produced per kWh of electricity produced (0.93916924 lbs/kWh for Texas ERCOT)) - lbs/kWh - number - 0.93916924 - 0 - 50000 * - CO2 produced by Natural Gas - CO2 intensity of burning natural gas (how much CO2 is produced per kWh of heat produced (0.070324961 lbs/kWh; https://www.epa.gov/energy/greenhouse-gases-equivalencies-calculator-calculations-and-references)) - lbs/kWh - number - 0.070324961 - 0 - 50000 * - Annual License Fees Etc - - MUSD - number - 0.0 - -1000.0 - 1000.0 * - One-time Flat License Fees Etc - - MUSD - number - 0.0 - -1000.0 - 1000.0 * - Other Incentives - - MUSD - number - 0.0 - -1000.0 - 1000.0 * - Tax Relief Per Year - Fixed percent reduction in annual tax rate - % - number - 0.0 - 0.0 - 100.0 * - One-time Grants Etc - - MUSD - number - 0.0 - -1000.0 - 1000.0 * - Fixed Internal Rate - Fixed Internal Rate (used in NPV calculation). Fixed Internal Rate is synonymous with Discount Rate. If one is provided, the other's value will be automatically set to the same value. - % - number - 7.0 - 0.0 - 100.0 * - CHP Electrical Plant Cost Allocation Ratio - CHP Electrical Plant Cost Allocation Ratio (cost electrical plant/total CAPEX) - - number - -1.0 - 0.0 - 1.0 * - Production Tax Credit Electricity - Production tax credit for electricity in $/kWh - USD/kWh - number - 0.04 - 0.0 - 10.0 * - Production Tax Credit Heat - Production tax credit for heat in $/MMBTU - USD/MMBTU - number - 0.0 - 0.0 - 100.0 * - Production Tax Credit Cooling - Production tax credit for cooling in $/MMBTU - USD/MMBTU - number - 0.0 - 0.0 - 100.0 * - Production Tax Credit Duration - Production tax credit for duration in years - yr - integer - 10 - 0 - 99 * - Production Tax Credit Inflation Adjusted - Production tax credit inflation adjusted - None - boolean - False - - * - Estimated Jobs Created per MW of Electricity Produced - Estimated jobs created per MW of electricity produced, per https://geothermal.org/resources/geothermal-basics - None - number - 2.13 - -1.8e+30 - 1.8e+30 * - Operation & Maintenance Cost of Surface Plant - - - number - 0.015 - 0.0 - 0.2 * - Capital Cost for Surface Plant for Direct-use System - - USD/kW - number - 100.0 - 0.0 - 10000.0 * - Capital Cost for Power Plant for Electricity Generation - - USD/kW - number - 3000.0 - 0.0 - 10000.0 * - AddOn Nickname - If using multiple add-ons: either (1) specify this value as an array or (2) use multiple parameters suffixed with a number e.g. 'AddOn Nickname 1', 'AddOn Nickname 2', etc. - None - array - [] - 0.0 - 1000.0 * - AddOn CAPEX - If using multiple add-ons: either (1) specify this value as an array or (2) use multiple parameters suffixed with a number e.g. 'AddOn CAPEX 1', 'AddOn CAPEX 2', etc. - MUSD - array - [] - 0.0 - 1000.0 * - AddOn OPEX - Annual operating cost. If using multiple add-ons: either (1) specify this value as an array or (2) use multiple parameters suffixed with a number e.g. 'AddOn OPEX 1', 'AddOn OPEX 2', etc. - MUSD/yr - array - [] - 0.0 - 1000.0 * - AddOn Electricity Gained - Annual electricity gained. If using multiple add-ons: either (1) specify this value as an array or (2) use multiple parameters suffixed with a number e.g. 'AddOn Electricity Gained 1', 'AddOn Electricity Gained 2', etc. - kW/yr - array - [] - 0.0 - 1000.0 * - AddOn Heat Gained - Annual heat gained. If using multiple add-ons: either (1) specify this value as an array or (2) use multiple parameters suffixed with a number e.g. 'AddOn Heat Gained 1', 'AddOn Heat Gained 2', etc. - kW/yr - array - [] - 0.0 - 1000.0 * - AddOn Profit Gained - Annual profit gained. If using multiple add-ons: either (1) specify this value as an array or (2) use multiple parameters suffixed with a number e.g. 'AddOn Profit Gained 1', 'AddOn Profit Gained 2', etc. - MUSD/yr - array - [] - 0.0 - 1000.0 Outputs ################# Schema: `geophires-result.json `__ SUMMARY OF RESULTS ------------------ .. list-table:: SUMMARY OF RESULTS Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - End-Use Option - - - * - End-Use - - - * - Surface Application - - - * - Average Net Electricity Production - - - * - Electricity breakeven price - LCOE. For SAM economic models, this is the nominal LCOE value (as opposed to real). - cents/kWh - number * - Total CAPEX - - - * - Average Direct-Use Heat Production - - - * - Direct-Use heat breakeven price - - - * - Direct-Use heat breakeven price (LCOH) - LCOH - USD/MMBTU - number * - Direct-Use Cooling Breakeven Price (LCOC) - LCOC - USD/MMBTU - number * - Annual District Heating Demand - - - * - Average Cooling Production - - - * - Average Annual Geothermal Heat Production - - - * - Average Annual Peaking Fuel Heat Production - - - * - Direct-Use Cooling Breakeven Price - - - * - Number of production wells - - - * - Number of injection wells - - - * - Flowrate per production well - - - * - Well depth - - - * - Well depth (or total length, if not vertical) - - - * - Geothermal gradient - - - * - Segment 1 Geothermal gradient - - - * - Segment 1 Thickness - - - * - Segment 2 Geothermal gradient - - - * - Segment 2 Thickness - - - * - Segment 3 Geothermal gradient - - - * - Segment 3 Thickness - - - * - Segment 4 Geothermal gradient - - - * - LCOE - LCOE. For SAM economic models, this is the nominal LCOE value (as opposed to real). - cents/kWh - number * - LCOH - LCOH - USD/MMBTU - number * - Lifetime Average Well Flow Rate - - - * - Total Avoided Carbon Emissions - Total Saved Carbon Production - pound - number ECONOMIC PARAMETERS ------------------- .. list-table:: ECONOMIC PARAMETERS Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - Economic Model - - - * - Interest Rate - - % - number * - Real Discount Rate - - % - number * - Nominal Discount Rate - Nominal Discount Rate is displayed for SAM Economic Models. It is calculated per https://samrepo.nrelcloud.org/help/fin_single_owner.html?q=nominal+discount+rate: Nominal Discount Rate = [ ( 1 + Real Discount Rate ÷ 100 ) × ( 1 + Inflation Rate ÷ 100 ) - 1 ] × 100. - % - number * - WACC - Weighted Average Cost of Capital displayed for SAM Economic Models. It is calculated per https://samrepo.nrelcloud.org/help/fin_commercial.html?q=wacc: WACC = [ Nominal Discount Rate ÷ 100 × (1 - Debt Percent ÷ 100) + Debt Percent ÷ 100 × Loan Rate ÷ 100 × (1 - Effective Tax Rate ÷ 100 ) ] × 100; Effective Tax Rate = [ Federal Tax Rate ÷ 100 × ( 1 - State Tax Rate ÷ 100 ) + State Tax Rate ÷ 100 ] × 100; - % - number * - Accrued financing during construction - - - * - Project lifetime - - - * - Capacity factor - - - * - Project NPV - Project Net Present Value. NPV is calculated with cashflows lumped at the end of periods. See: Short W et al, 1995. "A Manual for the Economic Evaluation of Energy Efficiency and Renewable Energy Technologies.", p. 41. https://www.nrel.gov/docs/legosti/old/5173.pdf - MUSD - number * - Project IRR - Project Internal Rate of Return - % - number * - After-tax IRR - The After-tax IRR (internal rate of return) is the nominal discount rate that corresponds to a net present value (NPV) of zero for PPA SAM Economic models. See https://samrepo.nrelcloud.org/help/mtf_irr.html. If SAM calculates After-tax IRR as NaN, numpy-financial.irr (https://numpy.org/numpy-financial/latest/irr.html) is used to calculate the value from SAM's total after-tax returns. - % - number * - Project VIR=PI=PIR - Project Value Investment Ratio - - number * - Project MOIC - Project Multiple of Invested Capital. For SAM Economic Models, this is calculated as the sum of Total pre-tax returns (total value received) divided by Issuance of equity (total capital invested). - - number * - Fixed Charge Rate (FCR) - - - * - Project Payback Period - The time at which cumulative cash flow reaches zero. For projects that never pay back, the calculated value will be "N/A". For SAM Economic Models, total after-tax returns are used to calculate cumulative cash flow. - yr - number * - CHP: Percent cost allocation for electrical plant - - - * - Estimated Jobs Created - - None - number EXTENDED ECONOMICS ------------------ .. list-table:: EXTENDED ECONOMICS Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - Adjusted Project LCOE (after incentives, grants, AddOns,etc) - - - * - Adjusted Project LCOH (after incentives, grants, AddOns,etc) - - - * - Adjusted Project CAPEX (after incentives, grants, AddOns, etc) - - - * - Adjusted Project OPEX (after incentives, grants, AddOns, etc) - - - * - Project NPV (including AddOns) - - - * - Project IRR (including AddOns) - - - * - Project VIR=PI=PIR (including AddOns) - - - * - Project MOIC (including AddOns) - - - * - Project Payback Period (including AddOns) - - - * - Total Add-on CAPEX - - - * - Total Add-on OPEX - - - * - Total Add-on Net Elec - - - * - Total Add-on Net Heat - - - * - Total Add-on Profit - - - * - AddOns Payback Period - - - CCUS ECONOMICS -------------- .. list-table:: CCUS ECONOMICS Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - Total Avoided Carbon Production - - - * - Project NPV (including carbon credit) - - - * - Project IRR (including carbon credit) - - - * - Project VIR=IR=PIR (including carbon credit) - - - * - Project MOIC (including carbon credit) - - - * - Project Payback Period (including carbon credit) - - - S-DAC-GT ECONOMICS ------------------ .. list-table:: S-DAC-GT ECONOMICS Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - LCOD using grid-based electricity only - - - * - LCOD using natural gas only - - - * - LCOD using geothermal energy only - - - * - CO2 Intensity using grid-based electricity only - - - * - CO2 Intensity using natural gas only - - - * - CO2 Intensity using geothermal energy only - - - * - Geothermal LCOH - - - * - Geothermal Ratio (electricity vs heat) - - - * - Percent Energy Devoted To Process - - - * - Total Cost of Capture - - - ENGINEERING PARAMETERS ---------------------- .. list-table:: ENGINEERING PARAMETERS Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - Number of Production Wells - - - * - Number of Injection Wells - - - * - Well depth - - - * - Well depth (or total length, if not vertical) - - - * - Water loss rate - - - * - Pump efficiency - - - * - Injection temperature - - - * - Injection Temperature - - degC - array * - Average production well temperature drop - - - * - Flowrate per production well - - - * - Injection well casing ID - - - * - Production well casing ID - - - * - Number of times redrilling - - - * - Power plant type - - - * - Fluid - - - * - Design - - - * - Flow rate - - - * - Lateral Length - - - * - Vertical Depth - - - * - Wellbore Diameter - - - * - Lifetime Average Well Flow Rate - - - RESOURCE CHARACTERISTICS ------------------------ .. list-table:: RESOURCE CHARACTERISTICS Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - Maximum reservoir temperature - - - * - Number of segments - - - * - Geothermal gradient - - - * - Segment 1 Geothermal gradient - - - * - Segment 1 Thickness - - - * - Segment 2 Geothermal gradient - - - * - Segment 2 Thickness - - - * - Segment 3 Geothermal gradient - - - * - Segment 3 Thickness - - - * - Segment 4 Geothermal gradient - - - RESERVOIR PARAMETERS -------------------- .. list-table:: RESERVOIR PARAMETERS Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - Reservoir Model - - - * - Fracture model - - - * - Bottom-hole temperature - - degC - number * - Well separation: fracture diameter - - - * - Well separation: fracture height - - - * - Fracture width - Calculated Fracture Width - meter - number * - Fracture area - Calculated Fracture Area. Effective heat transfer area per fracture - m**2 - number * - Number of fractures - Calculated Number of Fractures. Displayed rounded up to the nearest whole number. - None - number * - Fracture separation - Calculated Fracture Separation - meter - number * - Reservoir volume calculation note - - - * - Reservoir volume - - - * - Reservoir impedance - - - * - Reservoir hydrostatic pressure - - - * - Average reservoir pressure - Average Reservoir Pressure - kPa - number * - Plant outlet pressure - - - * - Production wellhead pressure - - kPa - number * - Productivity Index - - - * - Injectivity Index - - - * - Reservoir density - - - * - Reservoir thermal conductivity - - - * - Reservoir heat capacity - - - * - Reservoir porosity - - - * - Thermal Conductivity - - - RESERVOIR SIMULATION RESULTS ---------------------------- .. list-table:: RESERVOIR SIMULATION RESULTS Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - Maximum Production Temperature - - - * - Average Production Temperature - - degC - number * - Minimum Production Temperature - - - * - Initial Production Temperature - - - * - Average Reservoir Heat Extraction - - - * - Production Wellbore Heat Transmission Model - - - * - Wellbore Heat Transmission Model - - - * - Average Production Well Temperature Drop - - - * - Total Average Pressure Drop - - - * - Average Injection Well Pressure Drop - - - * - Average Production Pressure - - bar - number * - Average Reservoir Pressure Drop - - - * - Average Production Well Pressure Drop - - - * - Average Buoyancy Pressure Drop - - - * - Average Injection Well Pump Pressure Drop - - - * - Average Production Well Pump Pressure Drop - - - * - Average Heat Production - - - * - First Year Heat Production - - - * - Average Net Electricity Production - - - * - First Year Electricity Production - - - * - Maximum Storage Well Temperature - - - * - Average Storage Well Temperature - - - * - Minimum Storage Well Temperature - - - * - Maximum Balance Well Temperature - - - * - Average Balance Well Temperature - - - * - Minimum Balance Well Temperature - - - * - Maximum Annual Heat Stored - - - * - Average Annual Heat Stored - - - * - Minimum Annual Heat Stored - - - * - Maximum Annual Heat Supplied - - - * - Average Annual Heat Supplied - - - * - Minimum Annual Heat Supplied - - - * - Average Round-Trip Efficiency - - - CAPITAL COSTS ------------- .. list-table:: CAPITAL COSTS Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - Drilling and completion costs - Wellfield cost. Includes total drilling and completion cost of all injection and production wells and laterals, plus 5% indirect costs. - MUSD - number * - Drilling and completion costs per well - - - * - Drilling and completion costs per production well - - - * - Drilling and completion costs per injection well - - - * - Drilling and completion costs per vertical production well - - - * - Drilling and completion costs per vertical injection well - - - * - Drilling and completion costs per non-vertical section - - MUSD - number * - Drilling and completion costs (for redrilling) - - - * - Drilling and completion costs per redrilled well - - - * - Stimulation costs - Default correlation: $1.25M per injection well plus 15% contingency plus 12% indirect costs. Provide Reservoir Stimulation Capital Cost Adjustment Factor to multiply the default correlation. Provide Reservoir Stimulation Capital Cost to override the default correlation and set your own cost. - MUSD - number * - Stimulation costs (for redrilling) - - - * - Surface power plant costs - - - * - of which Absorption Chiller Cost - - - * - of which Heat Pump Cost - - - * - of which Peaking Boiler Cost - - - * - Transmission pipeline cost - Transmission pipeline costs - MUSD - number * - District Heating System Cost - - MUSD - number * - Field gathering system costs - Field gathering system cost - MUSD - number * - Total surface equipment costs - - - * - Exploration costs - Exploration cost. Default correlation: 60% of the cost of one production well plus 15% contingency plus 12% indirect costs. Provide Exploration Capital Cost Adjustment Factor to multiply the default correlation. Provide Exploration Capital Cost to override the default correlation and set your own cost. - MUSD - number * - Investment Tax Credit - Investment Tax Credit Value - MUSD - number * - Total capital costs - Total Capital Cost - MUSD - number * - Annualized capital costs - - - * - Total CAPEX - - - * - Drilling Cost - - - * - Drilling and Completion Costs - - - * - Drilling and Completion Costs per Well - - - * - Auxiliary Heater Cost - - - * - Pump Cost - - - * - Total Capital Costs - - - OPERATING AND MAINTENANCE COSTS ------------------------------- .. list-table:: OPERATING AND MAINTENANCE COSTS Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - Wellfield maintenance costs - O&M Wellfield cost - MUSD/yr - number * - Power plant maintenance costs - O&M Surface Plant costs - MUSD/yr - number * - Water costs - O&M Make-up Water costs - MUSD/yr - number * - Average Reservoir Pumping Cost - - - * - Absorption Chiller O&M Cost - - - * - Average Heat Pump Electricity Cost - - - * - Annual District Heating O&M Cost - - MUSD/yr - number * - Average Annual Peaking Fuel Cost - - MUSD/yr - number * - Average annual pumping costs - - - * - Total operating and maintenance costs - Total O&M Cost - MUSD/yr - number * - OPEX - - - * - Average annual auxiliary fuel cost - - - * - Average annual pumping cost - - - * - Total average annual O&M costs - - - SURFACE EQUIPMENT SIMULATION RESULTS ------------------------------------ .. list-table:: SURFACE EQUIPMENT SIMULATION RESULTS Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - Initial geofluid availability - - - * - Maximum Total Electricity Generation - - - * - Average Total Electricity Generation - - - * - Minimum Total Electricity Generation - - - * - Initial Total Electricity Generation - - - * - Maximum Net Electricity Generation - - - * - Average Net Electricity Generation - - - * - Minimum Net Electricity Generation - - - * - Initial Net Electricity Generation - - - * - Average Annual Total Electricity Generation - - - * - Average Annual Net Electricity Generation - - - * - Maximum Net Heat Production - - - * - Average Net Heat Production - - - * - Minimum Net Heat Production - - - * - Initial Net Heat Production - - - * - Average Annual Heat Production - - - * - Average Pumping Power - - - * - Average Annual Heat Pump Electricity Use - - - * - Maximum Cooling Production - - - * - Average Cooling Production - - - * - Minimum Cooling Production - - - * - Initial Cooling Production - - - * - Average Annual Cooling Production - - - * - Annual District Heating Demand - - - * - Maximum Daily District Heating Demand - - - * - Average Daily District Heating Demand - - - * - Minimum Daily District Heating Demand - - - * - Maximum Geothermal Heating Production - - - * - Average Geothermal Heating Production - - - * - Minimum Geothermal Heating Production - - - * - Maximum Peaking Boiler Heat Production - - - * - Average Peaking Boiler Heat Production - - - * - Minimum Peaking Boiler Heat Production - - - * - Initial pumping power/net installed power - - - * - Heat to Power Conversion Efficiency - First law efficiency average over project lifetime - % - object * - Surface Plant Cost - - - * - Average RTES Heating Production - - - * - Average Auxiliary Heating Production - - - * - Average Annual RTES Heating Production - - - * - Average Annual Auxiliary Heating Production - - - * - Average Annual Total Heating Production - - - * - Average Annual Electricity Use for Pumping - - - Simulation Metadata ------------------- .. list-table:: Simulation Metadata Outputs :header-rows: 1 * - Name - Description - Preferred Units - Default Value Type * - GEOPHIRES Version - - -