REopt Inputs
Inputs to run_reopt can be provided in one of four formats:
- a file path (string) to a JSON file,
- a
Dict, - using the
Scenariostruct, or - using the
REoptInputsstruct
Any one of these types can be passed to the run_reopt method as shown in Examples.
The first option is perhaps the most straightforward. For example, the minimum requirements for a JSON scenario file would look like:
{
"Site": {
"longitude": -118.1164613,
"latitude": 34.5794343
},
"ElectricLoad": {
"doe_reference_name": "MidriseApartment",
"annual_kwh": 1000000.0
},
"ElectricTariff": {
"urdb_label": "5ed6c1a15457a3367add15ae"
}
}The order of the keys does not matter. Note that this scenario does not include any energy generation technologies and therefore the results can be used as a baseline for comparison to scenarios that result in cost-optimal generation technologies (alternatively, a user could include a BAUScenario as shown in Examples).
To add PV to the analysis simply add a PV key with an empty dictionary (to use default values):
{
"Site": {
"longitude": -118.1164613,
"latitude": 34.5794343
},
"ElectricLoad": {
"doe_reference_name": "MidriseApartment",
"annual_kwh": 1000000.0
},
"ElectricTariff": {
"urdb_label": "5ed6c1a15457a3367add15ae"
},
"PV": {}
}This scenario will consider the option to purchase a solar PV system to reduce energy costs, and if solar PV can reduce the energy costs then REopt will provide the optimal PV capacity (assuming perfect foresight!). See PV for all available input keys and default values for PV. To override a default value, simply specify a value for a given key. For example, the site under consideration might have some existing PV capacity to account for, which can be done by setting the existing_kw key to the appropriate value.
Scenario
The Scenario struct captures all of the possible user input keys (see REopt Inputs for potential input formats). A Scenario struct will be automatically created if a Dict or file path are supplied to the run_reopt method. Alternatively, a user can create a Scenario struct and supply this to run_reopt.
REopt.Scenario — TypeScenario(d::Dict; flex_hvac_from_json=false)A Scenario struct can contain the following keys:
- Site (required)
- Financial (optional)
- ElectricTariff (required when
off_grid_flag=false) - ElectricLoad (required)
- PV (optional, can be Array)
- Wind (optional)
- ElectricStorage (optional)
- ElectricUtility (optional)
- Generator (optional)
- DomesticHotWaterLoad (optional)
- SpaceHeatingLoad (optional)
- ExistingBoiler (optional)
- Boiler (optional)
- CHP (optional)
- FlexibleHVAC (optional)
- ExistingChiller (optional)
- AbsorptionChiller (optional)
- GHP (optional, can be Array)
- SteamTurbine (optional)
All values of d are expected to be Dicts except for PV and GHP, which can be either a Dict or Dict[] (for multiple PV arrays or GHP options).
Set flex_hvac_from_json=true if FlexibleHVAC values were loaded in from JSON (necessary to handle conversion of Vector of Vectors from JSON to a Matrix in Julia).
Scenario(fp::String)Consruct Scenario from filepath fp to JSON with keys aligned with the Scenario(d::Dict) method.
BAUScenario
The Business-as-usual (BAU) inputs are automatically created based on the BAUScenario struct when a user supplies two JuMP.Models to run_reopt() (as shown in Examples). The outputs of the BAU scenario are used to calculate comparative results such as the Financial net present value (npv).
REopt.BAUInputs — FunctionBAUInputs(p::REoptInputs)TheBAUInputs (REoptInputs for the Business As Usual scenario) are created based on the BAUScenario, which is in turn created based on the optimized-case Scenario.
The following assumptions are made for the BAU Inputs:
PVandGeneratormin_kwandmax_kwset to theexisting_kwvaluesExistingBoilerandExistingChiller# TODO- All other generation and storage tech sizes set to zero
- Capital costs are assumed to be zero for existing
PVandGenerator - O&M costs and all other tech inputs are assumed to be the same for existing
PVandGeneratoras those specified for the optimized case - Outage assumptions for deterministic vs stochastic # TODO
Settings
REopt.Settings — TypeCaptures high-level inputs affecting the optimization.
Settings is an optional REopt input with the following keys and default values:
time_steps_per_hour::Int = 1 # corresponds to the time steps per hour for user-provided time series (e.g., `ElectricLoad.loads_kw` and `DomesticHotWaterLoad.fuel_loads_mmbtu_per_hour`)
add_soc_incentive::Bool = true # when true, an incentive is added to the model's objective function to keep the ElectricStorage SOC high
off_grid_flag::Bool = false # true if modeling an off-grid system, not connected to bulk power system
include_climate_in_objective::Bool = false # true if climate costs of emissions should be included in the model's objective function
include_health_in_objective::Bool = false # true if health costs of emissions should be included in the model's objective functionSite
REopt.Site — TypeInputs related to the physical location:
Site is a required REopt input with the following keys and default values:
latitude::Real,
longitude::Real,
land_acres::Union{Real, Nothing} = nothing,
roof_squarefeet::Union{Real, Nothing} = nothing,
min_resil_time_steps::Int=0,
mg_tech_sizes_equal_grid_sizes::Bool = true,
node::Int = 1,
CO2_emissions_reduction_min_fraction::Union{Float64, Nothing} = nothing,
CO2_emissions_reduction_max_fraction::Union{Float64, Nothing} = nothing,
bau_emissions_lb_CO2_per_year::Union{Float64, Nothing} = nothing,
bau_grid_emissions_lb_CO2_per_year::Union{Float64, Nothing} = nothing,
renewable_electricity_min_fraction::Real = 0.0,
renewable_electricity_max_fraction::Union{Float64, Nothing} = nothing,
include_exported_elec_emissions_in_total::Bool = true,
include_exported_renewable_electricity_in_total::Bool = true,ElectricLoad
REopt.ElectricLoad — TypeElectricLoad is a required REopt input with the following keys and default values:
loads_kw::Array{<:Real,1} = Real[],
path_to_csv::String = "", # for csv containing loads_kw
year::Int = 2020, # used in ElectricTariff to align rate schedule with weekdays/weekends
doe_reference_name::String = "",
blended_doe_reference_names::Array{String, 1} = String[],
blended_doe_reference_percents::Array{<:Real,1} = Real[],
city::String = "",
annual_kwh::Union{Real, Nothing} = nothing,
monthly_totals_kwh::Array{<:Real,1} = Real[],
critical_loads_kw::Union{Nothing, Array{Real,1}} = nothing,
loads_kw_is_net::Bool = true,
critical_loads_kw_is_net::Bool = false,
critical_load_fraction::Real = off_grid_flag ? 1.0 : 0.5, # if off grid must be 1.0, else 0.5
operating_reserve_required_fraction::Real = off_grid_flag ? 0.1 : 0.0, # if off grid, 10%, else must be 0%. Applied to each time_step as a % of electric load.
min_load_met_annual_fraction::Real = off_grid_flag ? 0.99999 : 1.0 # if off grid, 99.999%, else must be 100%. Applied to each time_step as a % of electric load.Must provide either loads_kw or path_to_csv or [doe_reference_name and city] or doe_reference_name or [blended_doe_reference_names and blended_doe_reference_percents].
When only doe_reference_name is provided the Site.latitude and Site.longitude are used to look up the ASHRAE climate zone, which determines the appropriate DoE Commercial Reference Building profile.
When using the [doe_reference_name and city] option, choose city from one of the cities used to represent the ASHRAE climate zones:
- Albuquerque
- Atlanta
- Baltimore
- Boulder
- Chicago
- Duluth
- Fairbanks
- Helena
- Houston
- LosAngeles
- Miami
- Minneapolis
- Phoenix
- SanFrancisco
- Seattle
and doe_reference_name from:
- FastFoodRest
- FullServiceRest
- Hospital
- LargeHotel
- LargeOffice
- MediumOffice
- MidriseApartment
- Outpatient
- PrimarySchool
- RetailStore
- SecondarySchool
- SmallHotel
- SmallOffice
- StripMall
- Supermarket
- Warehouse
- FlatLoad # constant load year-round
- FlatLoad245 # constant load all hours of the weekdays
- FlatLoad167 # two 8-hour shifts for all days of the year; 6-10 a.m.
- FlatLoad165 # two 8-hour shifts for the weekdays; 6-10 a.m.
- FlatLoad87 # one 8-hour shift for all days of the year; 9 a.m.-5 p.m.
- FlatLoad85 # one 8-hour shift for the weekdays; 9 a.m.-5 p.m.
Each city and doe_reference_name combination has a default annual_kwh, or you can provide your own annual_kwh or monthly_totals_kwh and the reference profile will be scaled appropriately.
ElectricTariff
REopt.ElectricTariff — MethodElectricTariff is a required REopt input for on-grid scenarios only (it cannot be supplied when Settings.off_grid_flag is true) with the following keys and default values:
urdb_label::String="",
urdb_response::Dict=Dict(),
urdb_utility_name::String="",
urdb_rate_name::String="",
year::Int=2020,
NEM::Bool=false,
wholesale_rate::T1=nothing,
export_rate_beyond_net_metering_limit::T2=nothing,
monthly_energy_rates::Array=[],
monthly_demand_rates::Array=[],
blended_annual_energy_rate::S=nothing,
blended_annual_demand_rate::R=nothing,
add_monthly_rates_to_urdb_rate::Bool=false,
tou_energy_rates_per_kwh::Array=[],
add_tou_energy_rates_to_urdb_rate::Bool=false,
remove_tiers::Bool=false,
demand_lookback_months::AbstractArray{Int64, 1}=Int64[],
demand_lookback_percent::Real=0.0,
demand_lookback_range::Int=0,
coincident_peak_load_active_time_steps::Vector{Vector{Int64}}=[Int64[]],
coincident_peak_load_charge_per_kw::AbstractVector{<:Real}=Real[]
) where {
T1 <: Union{Nothing, Real, Array{<:Real}},
T2 <: Union{Nothing, Real, Array{<:Real}},
S <: Union{Nothing, Real},
R <: Union{Nothing, Real}
}The NEM boolean is determined by the ElectricUtility.net_metering_limit_kw. There is no need to pass in a NEM value.
Financial
REopt.Financial — TypeFinancial is an optional REopt input with the following keys and default values:
om_cost_escalation_rate_fraction::Real = 0.025,
elec_cost_escalation_rate_fraction::Real = 0.019,
existing_boiler_fuel_cost_escalation_rate_fraction::Float64 = 0.034,
boiler_fuel_cost_escalation_rate_fraction::Real = 0.034,
chp_fuel_cost_escalation_rate_fraction::Real = 0.034,
generator_fuel_cost_escalation_rate_fraction::Real = 0.027,
offtaker_tax_rate_fraction::Real = 0.26,
offtaker_discount_rate_fraction::Real = 0.0564,
third_party_ownership::Bool = false,
owner_tax_rate_fraction::Real = 0.26,
owner_discount_rate_fraction::Real = 0.0564,
analysis_years::Int = 25,
value_of_lost_load_per_kwh::Union{Array{R,1}, R} where R<:Real = 1.00,
microgrid_upgrade_cost_fraction::Real = off_grid_flag ? 0.0 : 0.3, # not applicable when off_grid_flag is true
macrs_five_year::Array{Float64,1} = [0.2, 0.32, 0.192, 0.1152, 0.1152, 0.0576], # IRS pub 946
macrs_seven_year::Array{Float64,1} = [0.1429, 0.2449, 0.1749, 0.1249, 0.0893, 0.0892, 0.0893, 0.0446],
offgrid_other_capital_costs::Real = 0.0, # only applicable when off_grid_flag is true. Straight-line depreciation is applied to this capex cost, reducing taxable income.
offgrid_other_annual_costs::Real = 0.0 # only applicable when off_grid_flag is true. Considered tax deductible for owner. Costs are per year.
# Emissions cost inputs
CO2_cost_per_tonne::Real = 51.0,
CO2_cost_escalation_rate_fraction::Real = 0.042173,
NOx_grid_cost_per_tonne::Union{Nothing,Real} = nothing,
SO2_grid_cost_per_tonne::Union{Nothing,Real} = nothing,
PM25_grid_cost_per_tonne::Union{Nothing,Real} = nothing,
NOx_onsite_fuelburn_cost_per_tonne::Union{Nothing,Real} = nothing,
SO2_onsite_fuelburn_cost_per_tonne::Union{Nothing,Real} = nothing,
PM25_onsite_fuelburn_cost_per_tonne::Union{Nothing,Real} = nothing,
NOx_cost_escalation_rate_fraction::Union{Nothing,Real} = nothing,
SO2_cost_escalation_rate_fraction::Union{Nothing,Real} = nothing,
PM25_cost_escalation_rate_fraction::Union{Nothing,Real} = nothing,
# fields from other models needed for validation
latitude::Real, # Passed from Site
longitude::Real, # Passed from Site
include_health_in_objective::Bool = false # Passed from SettingsWhen third_party_ownership is false the offtaker's discount and tax percentages are used throughout the model:
if !third_party_ownership
owner_tax_rate_fraction = offtaker_tax_rate_fraction
owner_discount_rate_fraction = offtaker_discount_rate_fraction
endElectricUtility
REopt.ElectricUtility — TypeElectricUtility is an optional REopt input with the following keys and default values:
net_metering_limit_kw::Real = 0,
interconnection_limit_kw::Real = 1.0e9,
outage_start_time_step::Int=0, # for modeling a single outage, with critical load spliced into the baseline load ...
outage_end_time_step::Int=0, # ... utiltity production_factor = 0 during the outage
allow_simultaneous_export_import::Bool = true, # if true the site has two meters (in effect)
# next 5 variables below used for minimax the expected outage cost,
# with max taken over outage start time, expectation taken over outage duration
outage_start_time_steps::Array{Int,1}=Int[], # we minimize the maximum outage cost over outage start times
outage_durations::Array{Int,1}=Int[], # one-to-one with outage_probabilities, outage_durations can be a random variable
outage_probabilities::Array{R,1} where R<:Real = [1.0],
outage_time_steps::Union{Nothing, UnitRange} = isempty(outage_durations) ? nothing : 1:maximum(outage_durations),
scenarios::Union{Nothing, UnitRange} = isempty(outage_durations) ? nothing : 1:length(outage_durations),
# Emissions and renewable energy inputs:
emissions_region::String = "", # AVERT emissions region. Default is based on location, or can be overriden by providing region here.
emissions_factor_series_lb_CO2_per_kwh::Union{Real,Array{<:Real,1}} = Float64[], # can be scalar or timeseries (aligned with time_steps_per_hour)
emissions_factor_series_lb_NOx_per_kwh::Union{Real,Array{<:Real,1}} = Float64[], # can be scalar or timeseries (aligned with time_steps_per_hour)
emissions_factor_series_lb_SO2_per_kwh::Union{Real,Array{<:Real,1}} = Float64[], # can be scalar or timeseries (aligned with time_steps_per_hour)
emissions_factor_series_lb_PM25_per_kwh::Union{Real,Array{<:Real,1}} = Float64[], # can be scalar or timeseries (aligned with time_steps_per_hour)
emissions_factor_CO2_decrease_fraction::Real = 0.01174,
emissions_factor_NOx_decrease_fraction::Real = 0.01174,
emissions_factor_SO2_decrease_fraction::Real = 0.01174,
emissions_factor_PM25_decrease_fraction::Real = 0.01174,
# fields from other models needed for validation
CO2_emissions_reduction_min_fraction::Union{Real, Nothing} = nothing, # passed from Site
CO2_emissions_reduction_max_fraction::Union{Real, Nothing} = nothing, # passed from Site
include_climate_in_objective::Bool = false, # passed from Settings
include_health_in_objective::Bool = false # passed from SettingsOutage indexing begins at 1 (not 0) and the outage is inclusive of the outage end time step. For instance, to model a 3-hour outage from 12AM to 3AM on Jan 1, outagestarttimestep = 1 and outageendtimestep = 3. To model a 1-hour outage from 6AM to 7AM on Jan 1, outagestarttimestep = 7 and outageendtimestep = 7.
Cannot supply singular outagestart(or end)timestep and multiple outagestarttimesteps. Must use one or the other.
If a single deterministic outage is modeled using outagestarttimestep and outageendtimestep, emissions and renewable energy percentage calculations and constraints will factor in this outage. If stochastic outages are modeled using outagestarttimesteps, outagedurations, and outage_probabilities, emissions and renewable energy percentage calculations and constraints will not consider outages.
This constructor is intended to be used with latitude/longitude arguments provided for the non-MPC case and without latitude/longitude arguments provided for the MPC case.
The default emissions_region input is determined by the site's latitude and longitude. Alternatively, you may input the desired AVERT emissions_region, which must be one of: ["California", "Central", "Florida", "Mid-Atlantic", "Midwest", "Carolinas", "New England", "Northwest", "New York", "Rocky Mountains", "Southeast", "Southwest", "Tennessee", "Texas", "Alaska", "Hawaii (except Oahu)", "Hawaii (Oahu)"]
PV
REopt.PV — TypePV is an optional REopt input with the following keys and default values:
array_type::Int=1, # PV Watts array type (0: Ground Mount Fixed (Open Rack); 1: Rooftop, Fixed; 2: Ground Mount 1-Axis Tracking; 3 : 1-Axis Backtracking; 4: Ground Mount, 2-Axis Tracking)
tilt::Real= array_type == 1 ? 10 : abs(latitude), # tilt = 10 deg for rooftop systems, abs(lat) for ground-mount
module_type::Int=0, # PV module type (0: Standard; 1: Premium; 2: Thin Film)
losses::Real=0.14,
azimuth::Real = latitude≥0 ? 180 : 0, # set azimuth to zero for southern hemisphere
gcr::Real=0.4,
radius::Int=0,
name::String="PV",
location::String="both",
existing_kw::Real=0,
min_kw::Real=0,
max_kw::Real=1.0e9,
installed_cost_per_kw::Real=1592.0,
om_cost_per_kw::Real=17.0,
degradation_fraction::Real=0.005,
macrs_option_years::Int = 5,
macrs_bonus_fraction::Real = 1.0,
macrs_itc_reduction::Real = 0.5,
kw_per_square_foot::Real=0.01,
acres_per_kw::Real=6e-3,
inv_eff::Real=0.96,
dc_ac_ratio::Real=1.2,
production_factor_series::Union{Nothing, Array{<:Real,1}} = nothing,
federal_itc_fraction::Real = 0.26,
federal_rebate_per_kw::Real = 0.0,
state_ibi_fraction::Real = 0.0,
state_ibi_max::Real = 1.0e10,
state_rebate_per_kw::Real = 0.0,
state_rebate_max::Real = 1.0e10,
utility_ibi_fraction::Real = 0.0,
utility_ibi_max::Real = 1.0e10,
utility_rebate_per_kw::Real = 0.0,
utility_rebate_max::Real = 1.0e10,
production_incentive_per_kwh::Real = 0.0,
production_incentive_max_benefit::Real = 1.0e9,
production_incentive_years::Int = 1,
production_incentive_max_kw::Real = 1.0e9,
can_net_meter::Bool = off_grid_flag ? false : true,
can_wholesale::Bool = off_grid_flag ? false : true,
can_export_beyond_nem_limit::Bool = off_grid_flag ? false : true,
can_curtail::Bool = true,
operating_reserve_required_fraction::Real = off_grid_flag ? 0.25 : 0.0, # if off grid, 25%, else 0%. Applied to each time_step as a % of PV generation.Multiple PV types can be considered by providing an array of PV inputs. See example in src/test/scenarios/multiple_pvs.json
If tilt is not provided, then it is set to the absolute value of Site.latitude for ground-mount systems and is set to 10 degrees for rooftop systems. If azimuth is not provided, then it is set to 180 if the site is in the northern hemisphere and 0 if in the southern hemisphere.
Wind
REopt.Wind — TypeWind is an optional REopt input with the following keys and default values:
min_kw = 0.0,
max_kw = 1.0e9,
installed_cost_per_kw = nothing,
om_cost_per_kw = 35.0,
production_factor_series = nothing,
size_class = "",
wind_meters_per_sec = [],
wind_direction_degrees = [],
temperature_celsius = [],
pressure_atmospheres = [],
macrs_option_years = 5,
macrs_bonus_fraction = 0.0,
macrs_itc_reduction = 0.5,
federal_itc_fraction = nothing,
federal_rebate_per_kw = 0.0,
state_ibi_fraction = 0.0,
state_ibi_max = 1.0e10,
state_rebate_per_kw = 0.0,
state_rebate_max = 1.0e10,
utility_ibi_fraction = 0.0,
utility_ibi_max = 1.0e10,
utility_rebate_per_kw = 0.0,
utility_rebate_max = 1.0e10,
production_incentive_per_kwh = 0.0,
production_incentive_max_benefit = 1.0e9,
production_incentive_years = 1,
production_incentive_max_kw = 1.0e9,
can_net_meter = true,
can_wholesale = true,
can_export_beyond_nem_limit = true
operating_reserve_required_fraction::Real = off_grid_flag ? 0.50 : 0.0, # Only applicable when off_grid_flag is True. Applied to each time_step as a % of wind generation serving load.size_class must be one of ["residential", "commercial", "medium", "large"]. If size_class is not provided then it is determined based on the average electric load.
If no installed_cost_per_kw is provided then it is determined from:
size_class_to_installed_cost = Dict(
"residential"=> 11950.0,
"commercial"=> 7390.0,
"medium"=> 4440.0,
"large"=> 3450.0
)The Federal Investment Tax Credit is adjusted based on the size_class as follows (if the default of 0.3 is not changed):
size_class_to_itc_incentives = Dict(
"residential"=> 0.3,
"commercial"=> 0.3,
"medium"=> 0.12,
"large"=> 0.12
)If the production_factor_series is not provided then NREL's System Advisor Model (SAM) is used to get the wind turbine production factor.
Wind resource values are optional, i.e. (wind_meters_per_sec, wind_direction_degrees, temperature_celsius, and pressure_atmospheres). If not provided then the resource values are downloaded from NREL's Wind Toolkit. These values are passed to SAM to get the turbine production factor.
ElectricStorage
REopt.ElectricStorageDefaults — TypeElectricStorage is an optional optional REopt input with the following keys and default values:
off_grid_flag::Bool = false
min_kw::Real = 0.0
max_kw::Real = 1.0e4
min_kwh::Real = 0.0
max_kwh::Real = 1.0e6
internal_efficiency_fraction::Float64 = 0.975
inverter_efficiency_fraction::Float64 = 0.96
rectifier_efficiency_fraction::Float64 = 0.96
soc_min_fraction::Float64 = 0.2
soc_init_fraction::Float64 = off_grid_flag ? 1.0 : 0.5
can_grid_charge::Bool = off_grid_flag ? false : true
installed_cost_per_kw::Real = 775.0
installed_cost_per_kwh::Real = 388.0
replace_cost_per_kw::Real = 440.0
replace_cost_per_kwh::Real = 220.0
inverter_replacement_year::Int = 10
battery_replacement_year::Int = 10
macrs_option_years::Int = 7
macrs_bonus_fraction::Float64 = 1.0
macrs_itc_reduction::Float64 = 0.5
total_itc_fraction::Float64 = 0.0
total_rebate_per_kw::Real = 0.0
total_rebate_per_kwh::Real = 0.0
charge_efficiency::Float64 = rectifier_efficiency_fraction * internal_efficiency_fraction^0.5
discharge_efficiency::Float64 = inverter_efficiency_fraction * internal_efficiency_fraction^0.5
grid_charge_efficiency::Float64 = can_grid_charge ? charge_efficiency : 0.0
model_degradation::Bool = false
degradation::Dict = Dict()
minimum_avg_soc_fraction::Float64 = 0.0REopt.Degradation — TypeDegradationInputs used when ElectricStorage.model_degradation is true:
Base.@kwdef mutable struct Degradation
calendar_fade_coefficient::Real = 2.46E-03
cycle_fade_coefficient::Real = 7.82E-05
time_exponent::Real = 0.5
installed_cost_per_kwh_declination_rate::Float64 = 0.05
maintenance_strategy::String = "augmentation" # one of ["augmentation", "replacement"]
maintenance_cost_per_kwh::Vector{<:Real} = Real[]
endNone of the above values are required. If ElectricStorage.model_degradation is true then the defaults above are used. If the maintenance_cost_per_kwh is not provided then it is determined using the ElectricStorage.installed_cost_per_kwh and the installed_cost_per_kwh_declination_rate along with a present worth factor $f$ to account for the present cost of buying a battery in the future. The present worth factor for each day is:
$f(day) = \frac{ (1-r_g)^\frac{day}{365} } { (1+r_d)^\frac{day}{365} }$
where $r_g$ = installed_cost_per_kwh_declination_rate and $r_d$ = p.s.financial.owner_discount_rate_fraction.
Note this day-specific calculation of the present-worth factor accumulates differently from the annually updated discount rate for other net-present value calculations in REopt, and has a higher effective discount rate as a result. The present worth factor is used in two different ways, depending on the maintenance_strategy, which is described below.
When modeling degradation the following ElectricStorage inputs are not used:
replace_cost_per_kwreplace_cost_per_kwhinverter_replacement_yearbattery_replacement_year
The are replaced by the maintenance_cost_per_kwh vector.
When providing the maintenance_cost_per_kwh it must have a length equal to Financial.analysis_years*365.
Battery State Of Health
The state of health [SOH] is a linear function of the daily average state of charge [Eavg] and the daily equivalent full cycles [EFC]. The initial SOH is set to the optimal battery energy capacity (in kWh). The evolution of the SOH beyond the first day is:
$SOH[d] = SOH[d-1] - h\left( \frac{1}{2} k_{cal} Eavg[d-1] / \sqrt{d} + k_{cyc} EFC[d-1] \quad \forall d \in \{2\dots D\} \right)$
where:
- $k_{cal}$ is the
calendar_fade_coefficient - $k_{cyc}$ is the
cycle_fade_coefficient - $h$ is the hours per time step
- $D$ is the total number of days, 365 *
analysis_years
The SOH is used to determine the maintence cost of the storage system, which depends on the maintenance_strategy.
Augmentation Maintenance Strategy
The augmentation maintenance strategy assumes that the battery energy capacity is maintained by replacing degraded cells daily in terms of cost. Using the definition of the SOH above the maintenance cost is:
$C_{\text{aug}} = \sum_{d \in \{2\dots D\}} 0.8 C_{\text{install}} f(day) \left( SOH[d-1] - SOH[d] \right)$
where
- the $0.8$ factor accounts for sunk costs that do not need to be paid;
- $C_{\text{install}}$ is the
ElectricStorage.installed_cost_per_kwh; and - $SOH[d-1] - SOH[d]$ is the incremental amount of battery capacity lost in a day.
The $C_{\text{aug}}$ is added to the objective function to be minimized with all other costs.
Replacement Maintenance Strategy
Modeling the replacement maintenance strategy is more complex than the augmentation strategy. Effectively the replacement strategy says that the battery has to be replaced once the SOH hits 80% of the optimal, purchased capacity. It is possible that multiple replacements could be required under this strategy.
The "replacement" maintenance strategy requires integer variables and indicator constraints. Not all solvers support indicator constraints and some solvers are slow with integer variables.
The replacement strategy cost is:
$C_{\text{repl}} = B_{\text{kWh}} N_{\text{repl}} f(d_{80}) C_{\text{install}}$
where:
- $B_{\text{kWh}}$ is the optimal battery capacity (
ElectricStorage.size_kwhin the results dictionary); - $N_{\text{repl}}$ is the number of battery replacments required (a function of the month in which the
SOHreaches 80% of original capacity); - $f(d_{80})$ is the present worth factor at approximately the 15th day of the month that the
SOHreaches 80% of original capacity.
The $C_{\text{repl}}$ is added to the objective function to be minimized with all other costs.
Example of inputs
The following shows how one would use the degradation model in REopt via the Scenario inputs:
{
...
"ElectricStorage": {
"installed_cost_per_kwh": 390,
...
"model_degradation": true,
"degradation": {
"calendar_fade_coefficient": 2.86E-03,
"cycle_fade_coefficient": 6.22E-05,
"installed_cost_per_kwh_declination_rate": 0.06,
"maintenance_strategy": "replacement",
...
}
},
...
}Note that not all of the above inputs are necessary. When not providing calendar_fade_coefficient for example the default value will be used.
Generator
REopt.Generator — TypeGenerator is an optional REopt input with the following keys and default values:
existing_kw::Real = 0,
min_kw::Real = 0,
max_kw::Real = 1.0e6,
installed_cost_per_kw::Real = 500.0,
om_cost_per_kw::Real = off_grid_flag ? 20.0 : 10.0,
om_cost_per_kwh::Real = 0.0,
fuel_cost_per_gallon::Real = 3.0,
fuel_slope_gal_per_kwh::Real = 0.076,
fuel_intercept_gal_per_hr::Real = 0.0,
fuel_avail_gal::Real = off_grid_flag ? 1.0e9 : 660.0,
min_turn_down_fraction::Real = off_grid_flag ? 0.15 : 0.0,
only_runs_during_grid_outage::Bool = true,
sells_energy_back_to_grid::Bool = false,
can_net_meter::Bool = false,
can_wholesale::Bool = false,
can_export_beyond_nem_limit = false,
can_curtail::Bool = false,
macrs_option_years::Int = 0,
macrs_bonus_fraction::Real = 1.0,
macrs_itc_reduction::Real = 0.0,
federal_itc_fraction::Real = 0.0,
federal_rebate_per_kw::Real = 0.0,
state_ibi_fraction::Real = 0.0,
state_ibi_max::Real = 1.0e10,
state_rebate_per_kw::Real = 0.0,
state_rebate_max::Real = 1.0e10,
utility_ibi_fraction::Real = 0.0,
utility_ibi_max::Real = 1.0e10,
utility_rebate_per_kw::Real = 0.0,
utility_rebate_max::Real = 1.0e10,
production_incentive_per_kwh::Real = 0.0,
production_incentive_max_benefit::Real = 1.0e9,
production_incentive_years::Int = 0,
production_incentive_max_kw::Real = 1.0e9,
fuel_renewable_energy_fraction::Real = 0.0,
emissions_factor_lb_CO2_per_gal::Real = 22.51,
emissions_factor_lb_NOx_per_gal::Real = 0.0775544,
emissions_factor_lb_SO2_per_gal::Real = 0.040020476,
emissions_factor_lb_PM25_per_gal::Real = 0.0,
replacement_year::Int = off_grid_flag ? 10 : analysis_years,
replace_cost_per_kw::Real = off_grid_flag ? installed_cost_per_kw : 0.0Generator replacement costs will not be considered if Generator.replacement_year >= Financial.analysis_years.
ExistingBoiler
REopt.ExistingBoiler — TypeExistingBoiler is an optional REopt input with the following keys and default values:
max_heat_demand_kw::Real=0,
production_type::String = "hot_water",
chp_prime_mover::String = "",
max_thermal_factor_on_peak_load::Real = 1.25,
efficiency::Real = NaN,
fuel_cost_per_mmbtu::Union{<:Real, AbstractVector{<:Real}} = [],
fuel_type::String = "natural_gas", # "restrict_to": ["natural_gas", "landfill_bio_gas", "propane", "diesel_oil"]
can_supply_steam_turbine::Bool = false,
fuel_renewable_energy_fraction::Real = get(FUEL_DEFAULTS["fuel_renewable_energy_fraction"],fuel_type,0),
emissions_factor_lb_CO2_per_mmbtu::Real = get(FUEL_DEFAULTS["emissions_factor_lb_CO2_per_mmbtu"],fuel_type,0),
emissions_factor_lb_NOx_per_mmbtu::Real = get(FUEL_DEFAULTS["emissions_factor_lb_NOx_per_mmbtu"],fuel_type,0),
emissions_factor_lb_SO2_per_mmbtu::Real = get(FUEL_DEFAULTS["emissions_factor_lb_SO2_per_mmbtu"],fuel_type,0),
emissions_factor_lb_PM25_per_mmbtu::Real = get(FUEL_DEFAULTS["emissions_factor_lb_PM25_per_mmbtu"],fuel_type,0)The maximum size [kW] of the ExistingBoiler will be set based on the peak heat demand as follows:
max_kw = max_heat_demand_kw * max_thermal_factor_on_peak_loadThe ExistingBoiler's fuel_cost_per_mmbtu field is a required input. The fuel_cost_per_mmbtu can be a scalar, a list of 12 monthly values, or a time series of values for every time step.
Must supply either: efficiency, chp_prime_mover, or production_type.
If efficiency is not supplied, the efficiency will be determined based on the production_type. If production_type is not supplied, the production_type will be determined based on the chp_prime_mover (one of ["recipengine", "microturbine", "combustionturbine", "fuelcell"]). The following defaults are used:
production_type_by_chp_prime_mover = Dict(
"recip_engine" => "hot_water",
"micro_turbine" => "hot_water",
"combustion_turbine" => "steam",
"fuel_cell" => "hot_water"
)
efficiency_defaults = Dict(
"hot_water" => 0.8,
"steam" => 0.75
)CHP
REopt.CHP — TypeCHP is an optional REopt input with the following keys and default values:
prime_mover::String = ""
fuel_cost_per_mmbtu::Union{<:Real, AbstractVector{<:Real}} = [] # REQUIRED
# Required "custom inputs" if not providing prime_mover:
installed_cost_per_kw::Union{Float64, AbstractVector{Float64}} = NaN
tech_sizes_for_cost_curve::Union{Float64, AbstractVector{Float64}} = NaN
om_cost_per_kwh::Float64 = NaN
electric_efficiency_half_load = NaN
electric_efficiency_full_load::Float64 = NaN
min_turn_down_fraction::Float64 = NaN
thermal_efficiency_full_load::Float64 = NaN
thermal_efficiency_half_load::Float64 = NaN
min_allowable_kw::Float64 = NaN
max_kw::Float64 = NaN
cooling_thermal_factor::Float64 = NaN # only needed with cooling load
unavailability_periods::AbstractVector{Dict} = Dict[]
# Optional inputs:
size_class::Int = 1
min_kw::Float64 = 0.0
fuel_type::String = "natural_gas" # "restrict_to": ["natural_gas", "landfill_bio_gas", "propane", "diesel_oil"]
om_cost_per_kw::Float64 = 0.0
om_cost_per_hr_per_kw_rated::Float64 = 0.0
supplementary_firing_capital_cost_per_kw::Float64 = 150.0
supplementary_firing_max_steam_ratio::Float64 = 1.0
supplementary_firing_efficiency::Float64 = 0.92
standby_rate_per_kw_per_month::Float64 = 0.0
reduces_demand_charges::Bool = true
can_supply_steam_turbine::Bool=false
macrs_option_years::Int = 5
macrs_bonus_fraction::Float64 = 1.0
macrs_itc_reduction::Float64 = 0.5
federal_itc_fraction::Float64 = 0.1
federal_rebate_per_kw::Float64 = 0.0
state_ibi_fraction::Float64 = 0.0
state_ibi_max::Float64 = 1.0e10
state_rebate_per_kw::Float64 = 0.0
state_rebate_max::Float64 = 1.0e10
utility_ibi_fraction::Float64 = 0.0
utility_ibi_max::Float64 = 1.0e10
utility_rebate_per_kw::Float64 = 0.0
utility_rebate_max::Float64 = 1.0e10
production_incentive_per_kwh::Float64 = 0.0
production_incentive_max_benefit::Float64 = 1.0e9
production_incentive_years::Int = 0
production_incentive_max_kw::Float64 = 1.0e9
can_net_meter::Bool = false
can_wholesale::Bool = false
can_export_beyond_nem_limit::Bool = false
can_curtail::Bool = false
fuel_renewable_energy_fraction::Float64 = FUEL_DEFAULTS["fuel_renewable_energy_fraction"][fuel_type]
emissions_factor_lb_CO2_per_mmbtu::Float64 = FUEL_DEFAULTS["emissions_factor_lb_CO2_per_mmbtu"][fuel_type]
emissions_factor_lb_NOx_per_mmbtu::Float64 = FUEL_DEFAULTS["emissions_factor_lb_NOx_per_mmbtu"][fuel_type]
emissions_factor_lb_SO2_per_mmbtu::Float64 = FUEL_DEFAULTS["emissions_factor_lb_SO2_per_mmbtu"][fuel_type]
emissions_factor_lb_PM25_per_mmbtu::Float64 = FUEL_DEFAULTS["emissions_factor_lb_PM25_per_mmbtu"][fuel_type]To model CHP, you must provide at least prime_mover from ["recipengine", "microturbine", "combustionturbine", "fuelcell"] or all of the "custom inputs" defined below. If primemover is provided, any missing value from the "custom inputs" will be populated from data/chp/chpdefaultdata.json, based on the primemover, boilertype, and sizeclass. boilertype is "steam" if `primemoveris "combustion_turbine" and is "hot_water" for all otherprime_mover` types.
fuel_cost_per_mmbtu is always required
AbsorptionChiller
REopt.AbsorptionChiller — TypeAbsorptionChiller is an optional REopt input with the following keys and default values and default values and default values:
min_ton::Real = 0.0,
max_ton::Real = 0.0,
cop_thermal::Real,
cop_electric::Real = 14.1,
installed_cost_per_ton::Real,
om_cost_per_ton::Real,
macrs_option_years::Real = 0,
macrs_bonus_fraction::Real = 0Boiler
REopt.Boiler — TypeBoilerWhen modeling a heating load an ExistingBoiler model is created even if user does not provide the ExistingBoiler key. The Boiler model is not created by default. If a user provides the Boiler key then the optimal scenario has the option to purchase this new Boiler to meet the heating load in addition to using the ExistingBoiler to meet the heating load.
function Boiler(;
min_mmbtu_per_hour::Real = 0.0,
max_mmbtu_per_hour::Real = 0.0,
efficiency::Real = 0.8,
fuel_cost_per_mmbtu::Union{<:Real, AbstractVector{<:Real}} = 0.0,
macrs_option_years::Int = 0,
macrs_bonus_fraction::Real = 0.0,
installed_cost_per_mmbtu_per_hour::Real = 293000.0,
om_cost_per_mmbtu_per_hour::Real = 2930.0,
om_cost_per_mmbtu::Real = 0.0,
fuel_type::String = "natural_gas", # "restrict_to": ["natural_gas", "landfill_bio_gas", "propane", "diesel_oil", "uranium"]
can_supply_steam_turbine::Bool = true
)HotThermalStorage
REopt.HotThermalStorageDefaults — TypeHotThermalStorage is an optional REopt input with the following keys and default values:
min_gal::Float64 = 0.0
max_gal::Float64 = 0.0
hot_water_temp_degF::Float64 = 180.0
cool_water_temp_degF::Float64 = 160.0
internal_efficiency_fraction::Float64 = 0.999999
soc_min_fraction::Float64 = 0.1
soc_init_fraction::Float64 = 0.5
installed_cost_per_gal::Float64 = 1.50
thermal_decay_rate_fraction::Float64 = 0.0004
om_cost_per_gal::Float64 = 0.0
macrs_option_years::Int = 0
macrs_bonus_fraction::Float64 = 0.0
macrs_itc_reduction::Float64 = 0.0
total_itc_fraction::Float64 = 0.0
total_rebate_per_kwh::Float64 = 0.0ColdThermalStorage
REopt.ColdThermalStorageDefaults — TypeCold thermal energy storage sytem; specifically, a chilled water system used to meet thermal cooling loads.
ColdThermalStorage is an optional REopt input with the following keys and default values:
min_gal::Float64 = 0.0
max_gal::Float64 = 0.0
hot_water_temp_degF::Float64 = 56.0
cool_water_temp_degF::Float64 = 44.0
internal_efficiency_fraction::Float64 = 0.999999
soc_min_fraction::Float64 = 0.1
soc_init_fraction::Float64 = 0.5
installed_cost_per_gal::Float64 = 1.50
thermal_decay_rate_fraction::Float64 = 0.0004
om_cost_per_gal::Float64 = 0.0
macrs_option_years::Int = 0
macrs_bonus_fraction::Float64 = 0.0
macrs_itc_reduction::Float64 = 0.0
total_itc_fraction::Float64 = 0.0
total_rebate_per_kwh::Float64 = 0.0DomesticHotWaterLoad
REopt.DomesticHotWaterLoad — TypeDomesticHotWaterLoad is an optional REopt input with the following keys and default values:
doe_reference_name::String = "",
blended_doe_reference_names::Array{String, 1} = String[],
blended_doe_reference_percents::Array{<:Real,1} = Real[],
addressable_load_fraction::Union{<:Real, AbstractVector{<:Real}} = 1.0, # Fraction of input fuel load which is addressable by heating technologies. Can be a scalar or vector with length aligned with use of monthly_mmbtu or fuel_loads_mmbtu_per_hour.
annual_mmbtu::Union{Real, Nothing} = nothing,
monthly_mmbtu::Array{<:Real,1} = Real[],
fuel_loads_mmbtu_per_hour::Array{<:Real,1} = Real[] # Vector of hot water fuel loads [mmbtu/hour]. Length must equal 8760 * `Settings.time_steps_per_hour`There are many ways in which a DomesticHotWaterLoad can be defined:
- When using either
doe_reference_nameorblended_doe_reference_namesin anElectricLoadone only needs to provide the input key "DomesticHotWaterLoad" in theScenario(JSON or Dict). In this case the values from DoE reference names from theElectricLoadwill be used to define theDomesticHotWaterLoad. - One can provide the
doe_reference_nameorblended_doe_reference_namesdirectly in theDomesticHotWaterLoadkey within theScenario. These values can be combined with theannual_mmbtuormonthly_mmbtuinputs to scale the DoE reference profile(s). - One can provide the
fuel_loads_mmbtu_per_hourvalue in theDomesticHotWaterLoadkey within theScenario.
Hot water and space heating thermal "load" inputs are in terms of energy input required (boiler fuel), not the actual energy demand. The fuel energy is multiplied by the boiler_efficiency to get the actual energy demand.
SpaceHeatingLoad
REopt.SpaceHeatingLoad — TypeSpaceHeatingLoad is an optional REopt input with the following keys and default values:
doe_reference_name::String = "",
blended_doe_reference_names::Array{String, 1} = String[],
blended_doe_reference_percents::Array{<:Real,1} = Real[],
addressable_load_fraction::Union{<:Real, AbstractVector{<:Real}} = 1.0, # Fraction of input fuel load which is addressable by heating technologies. Can be a scalar or vector with length aligned with use of monthly_mmbtu or fuel_loads_mmbtu_per_hour.
annual_mmbtu::Union{Real, Nothing} = nothing,
monthly_mmbtu::Array{<:Real,1} = Real[],
fuel_loads_mmbtu_per_hour::Array{<:Real,1} = Real[] # Vector of space heating fuel loads [mmbtu/hr]. Length must equal 8760 * `Settings.time_steps_per_hour`There are many ways to define a SpaceHeatingLoad:
- a time-series via the
fuel_loads_mmbtu_per_hour, - scaling a DoE Commercial Reference Building (CRB) profile or a blend of CRB profiles to either the
annual_mmbtuormonthly_mmbtuvalues; - or using the
doe_reference_nameorblended_doe_reference_namesfrom theElectricLoad.
When using an ElectricLoad defined from a doe_reference_name or blended_doe_reference_names one only needs to provide an empty Dict in the scenario JSON to add a SpaceHeatingLoad to a Scenario, i.e.:
...
"ElectricLoad": {"doe_reference_name": "MidriseApartment"},
"SpaceHeatingLoad" : {},
...In this case the values provided for doe_reference_name, or blended_doe_reference_names and blended_doe_reference_percents are copied from the ElectricLoad to the SpaceHeatingLoad.
Hot water and space heating thermal "load" inputs are in terms of energy input required (boiler fuel), not the actual energy demand. The fuel energy is multiplied by the boiler_efficiency to get the actual energy demand.
FlexibleHVAC
REopt.FlexibleHVAC — TypeFlexibleHVAC is an optional REopt input with the following keys and default values:
system_matrix::AbstractMatrix{Float64} # N x N, with N states (temperatures in RC network)
input_matrix::AbstractMatrix{Float64} # N x M, with M inputs
exogenous_inputs::AbstractMatrix{Float64} # M x T, with T time steps
control_node::Int64
initial_temperatures::AbstractVector{Float64}
temperature_upper_bound_degC::Union{Real, Nothing}
temperature_lower_bound_degC::Union{Real, Nothing}
installed_cost::Float64Every model with FlexibleHVAC includes a preprocessing step to calculate the business-as-usual (BAU) cost of meeting the thermal loads using a dead-band controller. The BAU cost is then used in the binary decision for purchasing the FlexibleHVAC system: if the FlexibleHVAC system is purchased then the heating and cooling costs are determined by the HVAC dispatch that minimizes the lifecycle cost of energy. If the FlexibleHVAC system is not purchased then the BAU heating and cooling costs must be paid.
There are two construction methods for FlexibleHVAC, which depend on whether or not the data was loaded in from a JSON file. The issue with data from JSON is that the vector-of-vectors from the JSON file must be appropriately converted to Julia Matrices. When loading in a Scenario from JSON that includes a FlexibleHVAC model, if you include the flex_hvac_from_json argument to the Scenario constructor then the conversion to Matrices will be done appropriately.
At least one of the inputs for temperature_upper_bound_degC or temperature_lower_bound_degC must be provided to evaluate the FlexibleHVAC option. For example, if only temperature_lower_bound_degC is provided then only a heating system will be evaluated. Also, the heating system will only be used (or purchased) if the exogenous_inputs lead to the temperature at the control_node going below the temperature_lower_bound_degC.
The ExistingChiller is electric and so its operating cost is determined by the ElectricTariff.
The ExistingBoiler default operating cost is zero. Please provide the fuel_cost_per_mmbtu field for the ExistingBoiler if you want non-zero BAU heating costs. The fuel_cost_per_mmbtu can be a scalar, a list of 12 monthly values, or a time series of values for every time step.
ExistingChiller
REopt.ExistingChiller — TypeExistingChiller is an optional REopt input with the following keys and default values:
loads_kw_thermal::Vector{<:Real},
cop::Union{Real, Nothing} = nothing,
max_thermal_factor_on_peak_load::Real=1.25The maximum size [kW] of the ExistingChiller will be set based on the peak thermal load as follows:
max_kw = maximum(loads_kw_thermal) * max_thermal_factor_on_peak_loadGHP
REopt.GHP — TypeGHP evaluations typically require the GhpGhx.jl package to be loaded unless the GhpGhx.jl package was already used externally to create inputs_dict["GHP"]["ghpghx_responses"]. See the Home page under "Additional package loading for GHP" for instructions. This GHP struct uses the response from GhpGhx.jl to process input parameters for REopt including additional cost parameters for GHP.
GHPstruct with outer constructor:
require_ghp_purchase::Union{Bool, Int64} = false # 0 = false, 1 = true
installed_cost_heatpump_per_ton::Float64 = 1075.0
heatpump_capacity_sizing_factor_on_peak_load::Float64 = 1.1
installed_cost_ghx_per_ft::Float64 = 14.0
installed_cost_building_hydronic_loop_per_sqft = 1.70
om_cost_per_sqft_year::Float64 = -0.51
building_sqft::Float64 # Required input
space_heating_efficiency_thermal_factor::Float64 = NaN # Default depends on building and location
cooling_efficiency_thermal_factor::Float64 = NaN # Default depends on building and location
ghpghx_response::Dict = Dict()
can_serve_dhw::Bool = false
macrs_option_years::Int = 5
macrs_bonus_fraction::Float64 = 1.0
macrs_itc_reduction::Float64 = 0.5
federal_itc_fraction::Float64 = 0.1
federal_rebate_per_ton::Float64 = 0.0
federal_rebate_per_kw::Float64 = 0.0
state_ibi_fraction::Float64 = 0.0
state_ibi_max::Float64 = 1.0e10
state_rebate_per_ton::Float64 = 0.0
state_rebate_per_kw::Float64 = 0.0
state_rebate_max::Float64 = 1.0e10
utility_ibi_fraction::Float64 = 0.0
utility_ibi_max::Float64 = 1.0e10
utility_rebate_per_ton::Float64 = 0.0
utility_rebate_per_kw::Float64 = 0.0
utility_rebate_max::Float64 = 1.0e10
# Processed data from inputs and results of GhpGhx.jl
heating_thermal_kw::Vector{Float64} = []
cooling_thermal_kw::Vector{Float64} = []
yearly_electric_consumption_kw::Vector{Float64} = []
peak_combined_heatpump_thermal_ton::Float64 = NaN
# Intermediate parameters for cost processing
tech_sizes_for_cost_curve::Union{Float64, AbstractVector{Float64}} = NaN
installed_cost_per_kw::Union{Float64, AbstractVector{Float64}} = NaN
heatpump_capacity_ton::Float64 = NaN
# Process and populate these parameters needed more directly by the model
installed_cost::Float64 = NaN
om_cost_year_one::Float64 = NaNSteamTurbine
REopt.SteamTurbine — TypeSteamTurbine is an optional REopt input with the following keys and default values:
size_class::Int64 = 1
min_kw::Float64 = 0.0
max_kw::Float64 = 0.0
electric_produced_to_thermal_consumed_ratio::Float64 = NaN
thermal_produced_to_thermal_consumed_ratio::Float64 = NaN
is_condensing::Bool = false
inlet_steam_pressure_psig::Float64 = NaN
inlet_steam_temperature_degF::Float64 = NaN
inlet_steam_superheat_degF::Float64 = 0.0
outlet_steam_pressure_psig::Float64 = NaN
outlet_steam_min_vapor_fraction::Float64 = 0.8 # Minimum practical vapor fraction of steam at the exit of the steam turbine
isentropic_efficiency::Float64 = NaN
gearbox_generator_efficiency::Float64 = NaN # Combined gearbox (if applicable) and electric motor/generator efficiency
net_to_gross_electric_ratio::Float64 = NaN # Efficiency factor to account for auxiliary loads such as pumps, controls, lights, etc
installed_cost_per_kw::Float64 = NaN # Installed cost based on electric power capacity
om_cost_per_kw::Float64 = 0.0 # Fixed O&M cost based on electric power capacity
om_cost_per_kwh::Float64 = NaN # Variable O&M based on electric energy produced
can_net_meter::Bool = false
can_wholesale::Bool = false
can_export_beyond_nem_limit::Bool = false
can_curtail::Bool = false
macrs_option_years::Int = 0
macrs_bonus_fraction::Float64 = 1.0