# 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