Transmission Services Meeting Overview
Manager of Transmission Services, Terry Wolf, leads a meeting discussing MRES profile, true-up for 2015, member rate information, regulatory changes, and transmission projects. The meeting covers important details such as member served, generation capacity, renewable energy sources, FERC background, and regulatory issues. Future rate adjustments and calculations are also outlined for 2017.
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Presentation Transcript
August 26, 2016 Terry Wolf, Manager of Transmission Services
Agenda Meeting Purpose MRES Profile MRES and MMU True-up for 2015 MRES member historical rate information Question/Answer
Meeting Purpose MRES background Regulatory Changes / Timelines MRES and MMU specific rate information MRES true-up info on Attachment O/GG/M from 2015. MMU true-up info on Attachment O from 2015. True-up from 2015 along with forecast for 2017 will be incorporated into rates to be effective on January 1, 2017. MRES member rate information ALP Utilities (ALP), Benson Municipal Utilities (BMU), Detroit Lakes Public Utilities (DLPU), Hutchinson Utilities Commission (HUC), and Worthington Public Utilities (WPU).
- 60 Members served - Transmission: ~362 miles - Generation: ~744 MW - Renewable: ~86 MW Missouri River Energy Services Rugby Wind Project Fort Peck Dam Garrison Dam ITA Canyon Ferry Dam Big Horn River CapX Fargo Yellowtail Dam CapX Brookings Oahe Dam Watertown Power Plant Irv Simmons Point Beach Nuclear Plant Marshall Wind Project Big Bend Dam Gavin s Point Dam Odin Wind Project Fort Randall Dam Worthington Wind Project Laramie River Station MBPP MRES Member Exira Station MRES Generation Resource Red Rock Hydroelectric Plant Planned MRES Generation Resource Federal Hydroelectric Dam Transmission Projects (MBPP, Irv Simmons, ITA, CapX (Fargo, Brookings)
MRES FERC Background Transmission facilities are owned by Western Minnesota Municipal Power Agency (WMMPA) FERC Declaratory Order (EL08-22, 12/08) combines financial statements for ATRR Attachment O effective 6/1/11 Incentive filing (EL11-45, 6/11) CapX; Fargo P2 & P3, and Brookings CWIP, Abandon Plant, Hypothetical cap structure 205 filing (ER12-351, 11/11) FERC Approved ER12-351, and EL 11-45 on January 20, 2012
Regulatory / FERC Issues Complaint against MISO TOs regarding ROE and certain TOs regarding capital structure (EL14-12) and (EL15-45) Unknown timing and impacts Resolved in 2016??
Regulatory / FERC Issues, Procedures and Timing cont. By June 1st Post actual calculations and true-ups based on prior year s Rate Information By September 1st Meet with Interested Parties to discuss the actual prior year s Rate information By October 1st Post FLTY info for MRES December 1st Deadline for information requests By January 10th Must respond to information requests January 31st Deadline for informal challenges March 15th Annual Informational filing March 31st Deadline for formal challenges
True-up of Attachment O / GG / MM MRES and MMU MMU doesn t have any GG or MM costs Forward Rate Requirements Rate Base Operating Expenses Revenue Requirement and Rate Network Rate Summary
MRES 2015 True-Up Adjustment Overview Actual $6,530,415 Projected $6,712,484 Difference ($182,069) Net Revenue Requirement (a) Divisor True-Up Divisor 667,836 684,556 16,720 Projected Rate ($/kW/Yr) $9.806 True-Up (Divisor Difference x Projected Rate) $163,950 (b) Interest (a * interest rate) ($18,119) (c) Total 2015 True-Up Adjustment (Under Recovery) ($18,219) (a+b+c)
2015 MRES Annual Transmission Revenue Requirement Distribution MRES Total ATRR Attachment O, GG, MM $22,045,883 Attachment O MISO MISO Revenue Credits as Off-set $6,171,771 Attachment GG Attachment MM 28% CapX Fargo CapX Brookings $ 495,037 $6,530,415 $10,843,343 $ 4,895,732 2% (After True-up) 48% 22% MISO Non-MISO (SPP) UMZ PRICING ZONE OTP PRICING ZONE $3,515,825 $3,013,589 54% of Att O 46% of Att O 10
MRES member Attachment O Information Standard MISO templates for 5, and FLTY for 1 MRES is MISO TO on behalf of 6 MRES members MRES is contact for any initial questions OTP JPZ ALP Prior Year BMU 1 Year Lag DLPU 1 Year Lag GRE JPZ HUC - Prior Year ITC-M JPZ - WPU 1 Year Lag NSP JPZ MMU - FLTY
MMU 2015 True-Up Adjustment Overview Actual $2,034,477 Projected $2,214,780 Difference ($180,303) Net Revenue Requirement (a) Divisor True-Up Divisor 77,864 79,348 1,484 Projected Rate ($/kW/Yr) $25.971 True-Up (Divisor Difference x Projected Rate) $38,541 (b) Interest ((a + b) * interest rate) ($9,438) (c) Total 2015 True-Up Adjustment (Under Recovery) ($151,200) (a+b+c)
Revenue Requirements for 2016 ALP BMU DLPU HUC MMU WPU Net Attachment O Revenue Requirement $ 315,415 $ 83,243 $ 315,415 $ 2,944,285 $ 2,079,243 $ 246,014
Questions If you have any questions after the meeting, please submit via e-mail to Terry Wolf: twolf@mrenergy.com All questions and answers will be posted on the MRES OASIS website along with any follow-up questions received within two weeks from the date of inquiry on the OASIS site. (http://oasis.midwestiso.org/OASIS/MRET )
