IRP Questions and Responses

Relevant questions or comments submitted using the form below or via email will be made public, along with Idaho Power’s responses, on this page.

We will respond to questions within two weeks.

IRP Questions, Comments and Responses

Following are IRP-related questions from members of Idaho Power’s IRP Advisory Council or other members of the public, either at IRPAC meetings or via email or using the form above. More information is available at

What measures is Idaho Power taking to detect methane leaks and fix them?
Generally, methane/natural gas leaks on Idaho Power’s system are insignificant with respect to the global concern. Idaho Power does not own or operate any natural gas compression stations, meaning leaks on Idaho Power’s system are minute.

Checks are performed to ensure leaks are not present following maintenance of turbine fuel systems. The Company performs required inspection and maintenance on the fuel supply piping.

Are you modeling price sensitivity of gas and coal with respect to possible carbon pricing or a national RPS?
Sensitivities for the 2021 IRP are being run assuming low and high natural gas price forecasts and different carbon price forecasts. In addition, two of the scenarios (Clean by 2045 and Clean by 2035) include reduced emission constraints to model RPS scenarios.

Where are microgrids included in the Aurora model, if at all?
While the scope of the 2021 IRP does not include microgrids, grid-sited storage projects are being set to take advantage of infrastructure deferral benefits. These storage projects, in some instances, may be leveraged to include a number of microgrid benefits.

Has Idaho Power looked at solar and/or wind potential at the Bridger site when coal units are shut down?
The 2021 IRP analysis includes the assumption that the transmission between Bridger and Idaho Power’s system can be utilized to access renewable generation in Wyoming.

Will Idaho Power include the total expected tons of CO2 emissions with each of the 2021 IRP scenarios?
The total carbon emissions will be included by portfolio in the 2021 IRP.

Does Aurora account for higher transmission and distribution losses, especially at peak summer heat?

Often, energy efficiency information from the potential study is given in MWh. Why is it showing in MW in the portfolio summaries?
Energy efficiency measures vary with time. Energy used over time is represented in MWh which is how the numbers are represented in the Potential Study.

The capacity of the energy efficiency measures is given in MW. This is the measure, consistent with other resources in the plan, that is shown on the charts included in the IRPAC presentations.

What are the electrification assumptions? What and by when for the rapid electrification scenario?
Electrification assumptions are shared in the Electrification Scenario Analysis presentation given at the IRPAC meeting on July 13, 2021.

Wouldn’t distributed generation help with loss of load risk?
The extent of how much a resource will help the Loss of Load Expectation (LOLE) analysis depends on the load shape and how well it aligns with high-risk hours. The load forecast includes customer-owned distributed generation and the energy storage connected to the distribution is modeled in the LOLE calculation.

How are the episodic costs from extreme weather included in the portfolio modeling?
Extreme weather events were used to help determine the Planning Reserve Margin used in the 2021 IRP. The model selects sufficient resources to meet this margin in addition to the demand forecast. In this way, through the selection of resources to meet demand in varying conditions, the model captures the associated costs.

What data does Idaho Power or WECC or NWPPC have about actual historical risks to inform this discussion in our modeling?
Idaho Power has a rich history of weather and load data (1960 to present) that allow for the comprehensive study of load impacts at varying temperatures. The statistical relationships that are defined are used in modeling and predicting future peaks for capacity planning. Idaho Power has accurately predicted peak demand impacts relatively close to actual peaks and is confident in its model during a large sweep of actual weather probabilities. It is the understanding of the Company that WECC aggregates and monitors the utilities’ peak forecasts for managing regional risk.

Has Idaho Power looked at wind in Owyhee County yet? Why doesn’t Idaho Power take over and build that 120 MW Jackpot solar itself? Why not start with Wood River Valley with the cost of $30 million transmission project there?
The Company is currently subject to an existing contract with the Jackpot Solar project under which Idaho Power is not the owner. However, Idaho Power is generally evaluating company ownership options for future resources, including those that are identified through the RFP that is currently being discussed.

Doesn’t the addition of 357 MW in 2024 create a stranded resource, if it gets retired in 10 years?
The conversion of 357 MW of coal generation to natural gas generation will not impact the depreciable life of the units. All portfolios shared at IRPAC Meeting 7 show an exit from these units in 2034.

— Posted Nov. 24, 2021

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