GEOPHIRES-X Parameters

Input Parameters

Schema: geophires-request.json

Reservoir

Reservoir Parameters

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

Well Bores Parameters

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

Surface Plant Parameters

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

Economics Parameters

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

SUMMARY OF RESULTS Outputs

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

ECONOMIC PARAMETERS Outputs

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

EXTENDED ECONOMICS Outputs

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

CCUS ECONOMICS Outputs

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

S-DAC-GT ECONOMICS Outputs

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

ENGINEERING PARAMETERS Outputs

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

RESOURCE CHARACTERISTICS Outputs

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

RESERVOIR PARAMETERS Outputs

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

RESERVOIR SIMULATION RESULTS Outputs

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

CAPITAL COSTS Outputs

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

OPERATING AND MAINTENANCE COSTS Outputs

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

SURFACE EQUIPMENT SIMULATION RESULTS Outputs

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

Simulation Metadata Outputs

Name	Description	Preferred Units	Default Value Type
GEOPHIRES Version