20170829Utah_OCS Set 5 (1-11).docx

BEFORE THE PUBLIC SERVICE COMMISSION OF UTAHIn the Matter of the Voluntary Request:Docket No. 17-035-39Of Rocky Mountain Power for Approval:Office of Consumer ServicesOf Resource Decision to Repower:Fifth Data Request toWind Facilities:Rocky Mountain Power:August 25, 2017Please provide responses to:Gavin MangelsonPhilip HayetOffice of Consumer ServicesJ. Kennedy and Associates, Inc.160 East 300 South 570 Colonial Park Drive, Suite 305Salt Lake City, Utah 84111Roswell, GA 30075(801) 530-6480(770) [e-mail]@jkenn.com
Please provide the inflation rate used in the development of the wind-integration costs used in the repowering economic evaluation. Please reconcile this with the Company’s response to OCS 1.36.
Refer to “IRP Repower LGIA Limit v13 WIC Dunlap.xlsm,” “Existing” tab, cell E135.
Please reconcile this 2.51% to the Company’s response to OCS 1.36.
Is this difference in inflation rate assumed across all the “WIC” revenue requirement models?
Does the Company usually assume inflation on the integration costs?
What would the impact be to the analysis and the benefit of repowering if the integrations costs were not inflated?
What would the impact be to the analysis and benefit of repowering if the inflation rate used to determine integration costs was consistent with the value found in cell J25 in the excel file supplied in response to OCS 1.36.
Refer to “IRP Repower LGIA Limit v13 WIC Dunlap.xlsm,” “Existing” tab, rows 110 to 122. Please provide the workpapers supporting these values and explain what these are used for. Please explain why these forward prices are different between states and projects within the same state, and if these are derived from a specific fuel forecast.
Refer to the Company’s estimates for wind generation.
Does the Company anticipate that existing wind facilities and re-powered wind facilities may degrade over time? Please explain and provide evidence showing that wind performance does/does not degrade over time.
Do the energy estimates provided account for potential degradation over time? Please explain.
Please provide all workpapers used to determine the hourly energy patterns for existing and repowered projects pasted in the following files/ tabs:
IRP Repower LGIA Limit v13 WIC LJ.xlsm /Generation (LGIA Limited)
IRP Repower LGIA Limit v13 40-Yr LJ.xlsm /Generation (LGIA Limited)
IRP Repower No Limit v13 WIC LJ.xlsm / Generation (No LGIA Limited)
Please see “Repower Results Direct Testimony.xlsm” tab: “Price-Policy Annual – PaR” rows 16 and 20. Please explain what Energy Efficiency/ DSM costs are included in PaR under the variable costs category (row 16) and what costs are included as fixed costs (row 20). Please provide workpapers for each providing the derivation of each DSM cost.
Please explain why the Long-Term Contracts change between the “baseline” and “with wind repowering” cases (see “Repower Results Direct Testimony.xlsm” tab: “Price-Policy Annual – PaR” lines 10 and 36 (specifically cells X10 and X36). Are these contracts priced relative to wholesale market costs? Please explain.
Please explain why the Long-Term Contracts change between “baseline” in the Mod Gas, Mod CO2 scenario and the High Gas, 0 CO2 scenarios (see “Repower Results Direct Testimony.xlsm” tab: “Price-Policy Annual – PaR” lines 10 and 505 (specifically cells X10 and X505). Are these contracts priced relative to wholesale market costs? Please explain.
Refer to “IRP Repower LGIA Limit v13 WIC LJ.xlsm” tab: “LJ” rows 13, 14, and 22.
Please explain why PTC are included in the total revenue requirement that is then levelized.
Please explain why Wind Integration Costs and Wind Production Tax Costs are not included in the levelized cost calculations.
Please explain why PTC and Wind Production Tax Costs are treated differently.
Refer to “Repower Results Direct Testimony.xlsm” tab: “Price-Policy Annual – PaR” line 89, cells E89 and F89. Please explain why the net capital recovery is negative.
Refer to OCS 1.11.
Please provide the Aurora wholesale market price forecasts for the longest time period available in each of the 9 fuel price scenarios that the Company considered.
Please provide a narrative explanation and accompanying workpapers detailing the process to aggregate/convert these market price forecasts derived from Aurora (hourly, monthly, on-peak, off-peak etc) to the inputs that were used in SO and PaR.
Please provide standard Aurora output reports for the longest run performed for the Mod/Mod case.
Please provide a summary of the generic options available in the Aurora modeling of the WECC region and how they compare to the generic types of available in System Optimizer.
Please provide a sensitivity economic evaluation in which you assume the expansion plan is the same in both the Status Quo and Repower cases. Then the only different in the analysis should be the modeling of the repowered wind resources. Please provide the same workpapers/spreadsheets/results as were provided for the Company’s analysis.