|
|
|
|
|
Pa. ALJs Would Approve Settlement In PPL Electric Rate Case Which Removes Proposed Per-Transaction EDI Fee On Retail Suppliers; Other Changes To Supplier Tariff
The following story is brought free of charge to readers by VertexOne, the exclusive EDI provider of EnergyChoiceMatters.com
Two Pennsylvania PUC ALJs would approve, without modification, a non-unanimous settlement in PPL Electric Utilities' rate case at the Pennsylvania PUC which would remove, from a proposed supplier coordination tariff, PPL Electric Utilities' original proposal that retail electric suppliers (EGSs) shall be subject to a per-transaction fee for EDI transactions
As first reported by EnergyChoiceMatters.com, PPL Electric Utilities had originally proposed that PPL Electric Utilities would, "directly assign EDI Transaction fees to each EGS [electric generation supplier, aka retail supplier] for their EDI transactions. PPL Electric will charge its actual costs incurred for EDI transaction fees."
This previously proposed provision would not be adopted under the settlement, with the ALJs recommending approval of the settlement in its entirety without modification
Further discussion of the retail market issues addressed by the settlement may be found below, following discussion of the sole contested issue in the rate case
The rate case had only one contested issue, which was PPL Electric's proposed change in how customers are measured for categorization into a default service class (fixed price vs hourly), with the change mainly being applicable to certain customer-generators
PPL Electric proposed to use a customer's "maximum registered peak load" for the purpose of classifying customers into their respective default service rate schedules (this would essentially move many "no load" customer-generators into the hourly priced service class, instead of the small customer fixed price service class)
Certain customer generators had objected to such proposal, as the change would alter their compensation for excess generation, since such compensation is based on the default service rate, and the change would move "no load" customers into the category of being paid hourly rates for their excess generation, rather than the flat small customer default service rate
Under the settlement on the maximum registered peak load issue, PPL Electric and the Joint Solar Advocates would agree that certain existing customer-generators, and additional customer-generators subject to a cap, would be grandfathered into their existing default service rate class for a period of 10 years (i.e., until December 31, 2036), at which time such customer-generators would become subject to classification pursuant to the terms of PPL Electric’s default service rate classifications that are in place on or after January 1, 2037
Specifics concerning the grandfathering and eligibility can be found in ECM's prior story here
Additionally, the settlement would modify the design of the hourly rates paid under net metering to customers in the hourly priced default service class, to newly include, in the compensation, components for capacity, line losses, and a gross-up for GRT, thereby raising the compensation, to address concerns from opponents of hourly-based rate compensation
The ALJs would adopt the settlement's provisions concerning how customers are categorized into a default service class (fixed price vs hourly)
The ALJs said that the change proposed under the settlement is needed to properly classify "no load" customers, "and mitigate the rate impact that [their] projects’ net metering compensation has on Small C&I customers’ default service rates."
Turning back to other retail market provisions of the settlement, which were not contested, PPL Electric would, under the settlement as recommended for adoption, start charging DUNS Testing Fees to retail suppliers
Specifically, PPL Electric Utilities had proposed to allocate, to EGSs, DUNS Testing Fees incurred by PPL Electric for on-boarding new or modified EGSs into its systems. PPL Electric had proposed to recover, from EGSs, DUNS testing fees for the following types of testing: (1) 'Full' testing, which is to test DUNS activity for a new supplier; and (2) 'Abbreviated' testing, which is to test DUNS activity for an existing supplier requesting an additional DUNS number. The DUNS fees were proposed to be directly assigned to the EGS for each test performed.
At the time of PPL Electric's original proposal, the DUNS testing costs were $4,867.20 for full testing and $2,215.98 for abbreviated testing.
Under the settlement, the DUNS testing fees would be adopted with an effective date of January 1, 2027
Under the settlement, PPL Electric would also delete all proposed new credit requirements for EGSs, including the previously proposed provisions discussed below
PPL Electric had originally proposed to include in the EGS tariff new language stating that PPL Electric requires an initial credit amount of $250,000 from an EGS, and that PPL Electric shall adjust the amount required, "commensurate with the financial risks placed on the Company by an EGS, including recognition of an EGS’s performance."
Full details of PPL Electric's originally proposed EGS credit provisions, which would not be adopted under the settlement, are available in ECM's prior story here
Under the settlement, PPL Electric further agrees that all EGSs currently registered and operating in its service territory will be allowed to continue service on an uninterrupted basis until January 1, 2028, regardless of the changes to the requirements for registration of coordination services adopted under the settlement
The EGSs currently registered and operating in the PPL Electric service territory will need to provide the information and materials required under the revised coordination tariff (including any newly required information and materials) no later than January 1, 2028, in order to continue operating in PPL Electric’s service territory
The settlement recommended for adoption strikes a provision which would have limited available rate options to be used by EGSs
The specific following proposed language has been struck from the coordination requirements under the settlement: "for EGSs that use Consolidated EDC Billing, a copy of the EGS’s rate schedule must be provided to the Company. When an EGS requests the implementation of 'Standard Rates' on or after registration, or revisions to existing Standard rate schedules, the Company will implement the requested EGS rate schedule(s) within 14 calendar days. Standard Rates include fixed cents per kWh rates, starting from $0.0500 through $0.1199 per kWh in $0.0001 increments, and up to four decimal place precision. A 'percent off' of shopping rates would be available from 1% through 50% off the Price to Compare in one-half percent increments. An EGS will be limited to no more than 200 discrete Rate Ready rates per calendar quarter. Additionally, any rate design other than the one specified in Rule 12.1 may delay power flow to a Customer billed under Consolidated EDC Billing"
R-2025-3057164
ADVERTISEMENT Copyright 2026 EnergyChoiceMatters.com. Unauthorized copying, retransmission, or republication
prohibited. You are not permitted to copy any work or text of EnergyChoiceMatters.com without the separate and express written consent of EnergyChoiceMatters.com
April 17, 2026
Email This Story
Copyright 2026 EnergyChoiceMatters.com
Reporting by Paul Ring • ring@energychoicematters.com
NEW Jobs on RetailEnergyJobs.com:
• NEW -- Channel Partner Manager -- Retail Energy
• NEW -- Manager of Sales, Commercial -- Retail Supplier
• NEW -- Commercial Sales Support Specialist -- Retail Supplier
• NEW -- Channel Partner Manager - TX -- Retail Supplier
• NEW / Refreshed 2/24/26 -- Manager, ISO Coordination (electricity), Retail Supplier
|
|
|
|
|