GEOPHIRES-X Parameters

Input Parameters

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 gradients	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: Specify number of fractures and fracture separation, 2: Specify reservoir volume and fracture separation, 3: Specify reservoir volume and number of fractures, 4: Specify reservoir volume only (sufficient for reservoir models 3, 4, 5 and 6)	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

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	1.000001
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	1	0	100
Multilaterals Cased		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.		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
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
Construction Years	Number of years spent in construction (assumes whole years, no fractions)	None	integer	1	1	14
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)	None	integer	2	1	4
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		number	1.0	0	10
Injection Well Drilling and Completion Capital Cost Adjustment Factor	Injection 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. 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
Fraction of Investment in Bonds	Fraction of geothermal project financing through bonds (see docs)		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			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; 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	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		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	7.000000000000001	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
Do CCUS Calculations	Set to true if you want the CCUS economics calculations to be made	None	boolean	False
Ending CCUS Credit Value		USD/lb	number	0.0	0	1000
CCUS Escalation Start Year	Number of years after start of project before start of CCUS incentives	yr	integer	0	0	100
CCUS Escalation Rate Per Year	additional value per year of price after escalation starts	USD/mt	number	0.0	0.0	100.0
Starting CCUS Credit Value		USD/mt	number	0.0	0	1000
AddOn Nickname		None	array	[]	0.0	1000.0
AddOn CAPEX		MUSD	array	[]	0.0	1000.0
AddOn OPEX		MUSD/yr	array	[]	0.0	1000.0
AddOn Electricity Gained		kW/yr	array	[]	0.0	1000.0
AddOn Heat Gained		kW/yr	array	[]	0.0	1000.0
AddOn Profit Gained		MUSD/yr	array	[]	0.0	1000.0

Output Parameters

Output Parameters

Name	Preferred Units	Default Value Type
Calculated Fracture Separation	meter
Calculated Number of Fractures	1
Calculated Fracture Width	meter
Calculated Fracture Height	meter
Calculated Fracture Area	m**2
Calculated Reservoir Volume	m**3	number
cpwater	None	number
rhowater	None	number
averagegradient	None	number
Bottom-hole temperature	degC
Initial Reservoir Heat Content	MW
Time Vector	1
Reservoir Temperature History	degC
Cylindrical Reservoir Surface Area	m**2
NonLinear Time vs Temperature	1
SUTRA Annual Heat Stored	GWh
SUTRA Annual Heat Supplied	GWh
SUTRA Annual Round-Trip Heat Efficiency	%
SUTRA Target Heat Profile	kWh
SUTRA Simulated Heat Profile	kWh
SUTRA Storage Well Flow Rate Profile	kg/sec
SUTRA Balance Well Flow Rate Profile	kg/sec
SUTRA Storage Well Temperature Profile	degC
SUTRA Balance Well Temperature Profile	degC
Calculated Reservoir Pressure	kPa
Average Reservoir Pressure	kPa
Calculated Injection Reservoir Pressure	kPa
redrill	1
PumpingPowerProd	MW
PumpingPowerInj	MW
pumpdepth	meter
impedancemodelallowed	1
productionwellpumping	1
impedancemodelused	1
Production Well Temperature Drop	degC
Total Pressure Drop	kPa
Injection Well Pressure Drop	kPa
Reservoir Pressure Drop	kPa
Production Well Pump Pressure Drop	kPa
Bouyancy Pressure Drop	kPa
Produced Temperature	degC
Pumping Power	MW
Production wellhead pressure	kPa
Nonvertical Pressure Drop	kPa
Total length of all drilling	kilometer
Total length of vertical drilling	meter
Total length from lateral junction to base of vertical drilling	meter
Total length of lateral drilling	meter
PumpingPower	kW
Injection Temperature	degC
Production Well Flow Rate Profile	kg/sec
usebuiltinoutletplantcorrelation	1
TenteringPP	degC
annual heat production	GW/yr
annual electricity production	kW/yr
Total Electricity Generation	kWh
Net Electricity Production	MW
Net Electricity Generation	kWh
First Law Efficiency	%
Heat Extracted	MW
Heat Produced in MW	MW
Heat Produced in kWh	kW
Geofluid Availability	MW/(kg/s)
Remaining Reservoir Heat Content	MW
Heat Produced	MW
pumping power needed	kWh
Electricity Produced in the First Year	kWh
Average Net Daily Electricity Production	kW
Heat Produced in the First Year	kWh
Average Net Daily Heat Production	kW
Average Production Pressure	bar
Average Production Temperature	degC
Time Step used in SUTRA	hr
Heat Injected	MW
Auxiliary Heat Produced	MW
Total Heat Produced	MW
Annual Heat Injected	GWh/year
Annual Heat Produced	GWh/year
Annual Auxiliary Heat Produced	GWh/year
Annual Total Heat Produced	GWh/year
Annual Pumping Electricity Required	kWh/yr
Maximum Peaking Boiler Natural Gas Demand	MW
Heat Pump Electricity Consumed	MW
Annual Heat Pump Electricity Consumption	kWh/yr
Electricity Sale Price Model	cents/kWh
Heat Sale Price Model	cents/kWh
Cooling Sale Price Model	cents/kWh
Carbon Price Model	USD/tonne
LCOC	USD/MMBTU
LCOE	cents/kWh
LCOH	USD/MMBTU
O&M Surface Plant costs	MUSD/yr
Exploration cost	MUSD
Wellfield cost	MUSD
O&M Wellfield cost	MUSD/yr
Surface Plant cost	MUSD
Field gathering system cost	MUSD
Transmission pipeline costs	MUSD
O&M Make-up Water costs	MUSD/yr
Total Capital Cost	MUSD
Total O&M Cost	MUSD/yr
Average Annual Heat Pump Electricity Cost	MUSD/yr
Peaking boiler cost	MUSD
District Heating System Cost	MUSD
District Heating System Population Density	Population per square km
Annual Peaking Fuel Cost	MUSD/yr
Annual District Heating O&M Cost	MUSD/yr
Average Annual Peaking Fuel Cost	MUSD/yr
Annual Revenue from Electricity Production	MUSD/yr
Cumulative Revenue from Electricity Production	MUSD
Annual Revenue from Heat Production	MUSD/yr
Cumulative Revenue from Heat Production	MUSD
Annual Revenue from Cooling Production	MUSD/yr
Cumulative Revenue from Cooling Production	MUSD
Annual Revenue from Carbon Pricing	MUSD/yr
Cumulative Revenue from Carbon Pricing	MUSD
Annual Saved Carbon Production	pound
Total Saved Carbon Production	pound
Interest Rate	%
Annual Revenue from Project	MUSD/yr
Cumulative Revenue from Project	MUSD
Project Net Present Value	MUSD
Project Internal Rate of Return	%
Project Value Investment Ratio
Project Multiple of Invested Capital
Project Payback Period	yr
Investment Tax Credit Value	MUSD
Cost of One Production Well	MUSD
Cost of One Injection Well	MUSD
Cost of the entire (multi-) lateral section of a well	MUSD
Cost of the entire section of a well from bottom of vertical to junction with laterals	MUSD
Estimated Jobs Created	1
Annual Pumping Costs	KUSD/yr
Annual Project Cash Flow	MUSD/yr
Cumulative Project Cash Flow	MUSD
CCUS Incentive Model	USD/lb
Annual Revenue Generated from CCUS	MUSD/yr
Annual Cash Flow	MUSD/yr
Cumulative Cash Flow	MUSD
CCUS Electricity Sale Price Model	cents/kWh
CCUS Heat Sale Price Model	cents/kWh
AddOn CAPEX Total	MUSD
AddOn OPEX Total Per Year	MUSD/yr
AddOn Electricity Gained Total Per Year	kW/yr
AddOn Heat Gained Total Per Year	kW/yr
AddOn Profit Gained Total Per Year	MUSD/yr
AddOn Payback Period	yr
Adjusted CAPEX	MUSD
Adjusted OPEX	MUSD
Annual AddOn Cash Flow	MUSD/yr
Cumulative AddOn Cash Flow	MUSD
Annual Revenue Generated from Electricity Sales	MUSD/yr
Annual Revenue Generated from Heat Sales	MUSD/yr
Annual Revenue Generated from AddOns	MUSD/yr