In Proceeding 27256, the Alberta Utilities Commission (the “Commission”) publishes its final Hydrogen Inquiry Report that details its considerations and recommendations for hydrogen blending in Alberta.
In proceeding 26616, the Alberta Utilities Commission (the “Commission) issues its decision regarding the cost-of-service review for both ATCO Gas (“ATCO”) and Apex Utilities Inc. (“Apex”) in preparation for the third term of performance-based regulation (“PBR3”).
Readers may remember our previous article summarizing ATCO and Apex’s cost-of-service rebasing application whereby both utilities realign their distribution facility owner costs and revenues in preparation for PBR3. The intervenors argued that the applicants had not demonstrated how they would share efficiencies with ratepayers, that efficiencies should be quantified, that the applicants’ cost escalators overstate actual costs, and that certain capital projects should be excluded from each applicant’s rate base. The applicants responded by stating their efficiencies would be shared through lower rates, that their escalators are based on reasonable factors, and that the capital projects under question are prudent and necessary.
On August 18, the Alberta Utilities Commission (AUC) reopened ATCO Electric Ltd.’s 2018-2020 (now 2018-2021) deferral account application (Proceeding 26573).
On October 7, 2021, the AUC temporarily suspended ATCO Electric’s deferral account disposition in response to a complaint that costs related to the Jasper Interconnection Project were not prudently incurred. Specifically, through an investigative process, ATCO was found to have sole-sourced a contract at above-market rates. The AUC completed a separate process to determine penalties for ATCO Electric.
In Proceeding 27562, Direct Energy Regulated Services (“Direct Energy”) submits is energy price setting plan (“EPSP”) to establish regulated rates to the Alberta Utilities Commission (the “Commission”).
In Proceeding 27495, ENMAX Energy Corporation (“ENMAX Energy”) submits its 2023-2024 Regulated Rate Option (“RRO”) energy price setting plan application to the Alberta Utilities Commission (“AUC”) for approval.
In proceeding 26617 the Alberta Utilities Commission (the “Commission”) issues its decision regarding the cost-of-service negotiated settlements of ENMAX Power Corporation (“ENMAX”) and EPCOR Distribution & Transmission Inc. (“EPCOR”) in preparation for the next term of performance-based regulation (“PBR”).
In proceeding 26615 the Alberta Utilities Commission (the “Commission”) issues its decision regarding the cost-of service reviews proposed by ATCO Electric Ltd. (“ATCO”) and FortisAlberta Inc. (“Fortis”) in preparation for the third term of performance-based regulation (“PBR”).
In Proceeding 26911, the Alberta Electric System Operator (“AESO”) and the intervenors submit their arguments to the Alberta Utilities Commission (the “Commission”) for and against the AESO’s proposed bulk and regional rate design and modernized demand opportunity service (“DOS”).
The Alberta Utilities Commission (AUC) recently posted its draft version of an updated Rule 022 on cost recovery for participating in a rate proceeding.
In September 2021, the AUC released a bulletin outlining its goals to improve participation and encourage efficiency of proceedings. The AUC set up an engagement process on how Rule 022 can be amended to achieve these goals. Participants in the engagement process have since provided written and oral submissions. Recently, the AUC posted an updated version of Rule 022 and is awaiting feedback from participants by August 10.
In Proceeding 26911 the Alberta Electric System Operator (“AESO”) and several intervenors cross-examine each other’s evidence for and against the various bulk and regional rate design proposals before the Alberta Utilities Commission (the “Commission”).
Readers may remember our previous article describing the AESO’s rebuttal evidence for their bulk and regional rate design and modernized demand opportunity service application. The current rate design collects transmission costs through a mix of energy and peak demand billing determinants where a monthly coincident peak charge (“12-CP”) recovers two thirds of demand costs.