GEOPHIRES-X Parameters¶
Input Parameters¶
Reservoir¶
¶ 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¶
¶ 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¶
¶ 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¶
¶ 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
100
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
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)
%
number
6.25
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¶
¶ 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
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