HAWSCO General Water Rate Application Decision

In proceeding 28445, the Alberta Utilities Commission (the Commission) issues its decision and findings regarding the 2024-2025 general rate application of Harmony Advanced Water Systems Corporation (HAWSCO).  HAWSCO provides water services to the Harmony community in Rocky View County on the western border of Calgary.



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AMP Decision

The Alberta Utilities Commission (the Commission) issues its decision on the Revised Adjusted Metering Practice (AMP) implementation plan submitted by the AESO (Decision 28441-D02-2024). The AESO’s original AMP plan was rejected by the Commission in 2022, but the AESO was permitted to apply again if it provided clearer estimates for all scopes of work and a cost-benefit analysis. Evidence and arguments for this proceeding showed that parties were split into three groups – supportive of the plan without delay, supportive but in favour of a later implementation, and generally opposed.  



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Review and Variance of Corix Decision

In proceeding 28707, the Alberta Utilities Commission (the “Commission”) issues its decision regarding phase 2 of the review and variance application of Corix Utilities (Foothills Water) Inc. (“Corix”). The application focused on two issues:

  • Billing and customer service costs that Corix were not included in the calculation of shared administration costs.
  • The approved return on equity percentage, which had changed from 8.5 percent to 9.28 percent during the proceeding.


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AltaLink 2024-2025 GTA: Wildfire Mitigation and Salvage Expenditure Arguments

In proceeding 28174, the Alberta Utilities Commission (the Commission) approved the negotiated settlement of AltaLink Management Ltd. (AltaLink) on all issues except for those matters related to AltaLink’s wildfire mitigation plan and its salvage expenditures. Parties recently delivered their arguments regarding these outstanding issues, which focused on AltaLink’s newly proposed wildfire mitigation programs and its forecast salvage expenditures calculation.



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AltaLink Application Regarding Destroyed Assets

In proceeding 28750, AltaLink Management Ltd. (AltaLink) applies to recover its expenditures incurred to repair, replace, and salvage its transmission facilities that were damaged or destroyed in the 2023 Spring wildfire and snow events. AltaLink calculates that the total expenditure is $24.7 million, which it requests to be included in its 2024 opening rate base and net salvage reserve where applicable. AltaLink is filing this application now because it only recently finished determining the total scope of repair and expenditures and the 2023 Spring wildfire and snow events occurred after AltaLink filed its 2024-2025 GTA which is currently being considered in proceeding 28174.[1]



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Fortis – Battle River Power Asset Transfer Compensation Decision

In proceeding 28358, the Alberta Utilities Commission (the Commission) issues its decision regarding compensation for site transfers between FortisAlberta Inc. (Fortis) and the rural electrification association (REA) Battle River Power Coop REA Ltd. (Battle River Power).

Over five years ago, several municipalities with which Fortis has a franchise agreement, annexed land that overlapped with existing REA service areas. Fortis requested that the REA areas be altered to align with its municipal franchise agreements. In Decision 22164-D01-2018, the Commission granted Fortis’s request contingent on there being a municipal bylaw requiring customers in the annexed area to connect to Fortis. Since then, many successful transfers have taken place between REAs and Fortis. However, a transfer of 50 sites remained outstanding for which Forts and Battle River Power could not come to an agreement.[1]



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The Renewable Moratorium Lifts and Intended Policy Changes

Readers may recall our previous update on Alberta’s renewable generation moratorium in which the Government of Alberta paused the approval of renewable generation and required the Alberta Utilities Commission to commence an inquiry regarding the development and impact of renewable generation in the province. The moratorium was lifted on February 29, 2024, and the Commission will now assess those applications that were affected by the pause on an individual basis to determine whether an immediate decision can be issued or if they require further processing. However, the Alberta Government has made known its intention to enact legislation that will affect renewable development in the province. Additionally, the Commission plans to initiate a stakeholder consultation regarding the application requirements for renewable projects.[1]



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EPCOR Energy 2024-2025 Energy Price-Setting Plan (EPSP) Application and Arguments

In proceeding 28717, EPCOR Energy Alberta GP (EPCOR Energy) submits its 2024-2025 energy price-setting plan application to the Alberta Utilities Commission (the Commission) for review and approval. This price-setting plan is what EPCOR Energy will use to determine the regulated rate option (RRO) charge that it provides to eligible customers in the service areas of EPCOR Distribution & Transmission Inc. and FortisAlberta Inc.[1]



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Revised AMP Implementation Evidence and Argument

In Proceeding 28441, interveners submit their evidence in support or opposition to the revised adjusted metering practice (AMP) plan applied for by the Alberta Electric System Operator (AESO). The AESO’s original AMP plan was rejected by the Alberta Utilities Commission (the Commission) in 2022. Evidence in this proceeding was submitted by AltaLink Management Ltd. (AltaLink), and the AESO in support of the implementation plan, by Fortis arguing for changes to the timing of AMP, and by the DCG Consortium in opposition to the plan.



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ENMAX’s R&V Application of the PBR3 K-bar Mechanism

In proceeding 28574, ENMAX Power Corporation (ENMAX) applies for a review and variance of the K-bar mechanism approved by the Alberta Utilities Commission (the Commission) for the third generation of performance-based regulation (PBR3). ENAMX asserts that the Commission erred in believing that the K-bar would provide ENMAX with sufficient funding and seeks the Commission to grant a review of the PBR3 K-bar. ENMAX’s case is grounded in its concern that the approved K-bar does not meet ENMAX’s needs to fund the replacement of its aging assets or to respond to the growing need to modernize the grid. Furthermore, ENMAX states that the current K-bar will force the utility to choose which benefits its customers will forgo and that it may have to put off investment into reliability drivers, externally driven projects, and grid modernization to prioritize safety on its network.[1]



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