DS Data

No. The level of block supply amount under DSP VI provided has not been derated for PJM’s marginal losses.

This data is correct. Negative hourly load values for the LP5 (Large Power, 69 kV+) class can occur due to retail level net metering and behind the meter generation, not because of outages or data errors.  Some LP5 customers have on site generation (such as solar or CHP), and during certain hours, often low load periods, generation can exceed the customer’s usage.  When this happens, power is exported back to the grid and is recorded as negative load at the meter.  These negative values are an expected result of how retail level load is measured for customers with on site generation.

Pursuant to Section 1.1.4 of the RFP Rules, the Default Service Load for each Customer Group is the Full Requirements Service for PPL Electric’s retail customers within that Customer Group, excluding customers that have chosen to take service from an Electric Generation Supplier. In other words, the Default Service Load does not include shopping load.
For the purposes of this RFP, the Default Service Load will be reduced by any net excess generation purchased from net metering (customer generation) as well as supply the Company is obligated to purchase pursuant to the Public Utility Regulatory Policies Act. In addition, for the Residential Customer Group, the Default Service Load will be reduced by NYPA supply and block purchases. For level of block purchases, please see “Level of Block Supply under DSP VI” (https://ppldsp.com/default-service-rfp/documents/).
Additionally, it is important to note, in the data file “Rate Load Data (2015 – Present)”, and the tabs “RES_LOAD_2015+”, “SCI_LOAD_2015+”, and “LCI_LOAD_2015+”, these data include all customer (default service and shopping) load data by hour, for the rate schedules provided.
For information related to the data posted on the website, please see the “Summary Document” (https://ppldsp.com/data/).

This data is not available. PPL Electric has provided the data files posted to the Data section of the RFP website for informational purposes only and for the convenience of RFP Bidders. No additional data is available at this time.
Loss factors (also referred to as deration factors) are published in the Deration Factor Data files available on the PPL DSP website under the Data section. These files provide the multipliers used to convert retail-level usage to wholesale volumes by rate class and period.
To estimate AEPS obligations, suppliers should use retail-level load data (excluding losses), as AEPS compliance is based on retail sales. The deration factors are not applied when calculating AEPS volumes but are useful for modeling wholesale settlement volumes.

AEPS Basis: AEPS compliance is based on retail sales, so using the raw load data (excluding losses) is appropriate for estimating AEPS costs on a prospective basis.
Retail Load Data: Hourly load data posted on the PPL DSP website under the Rate Category & Load Data section. These values reflect customer-level usage before losses are applied, which aligns with how AEPS obligations are calculated.
TOU Adjustments: The Rate Load Data file also includes Time-of-Use (TOU) breakdowns, which may help refine your estimates depending on your modeling approach.

The Daily ICAP & NITS Tag data file provides the final ICAP & NITS customer tag data submitted to PJM by default service and shopping customers, separately. There is no additional data for ESG (Shopping) customers broken down by customer groups available.

The 571 MW of incremental load referenced by PPL is tied to projects that have signed formal agreements. These agreements typically outline the project scope, expected timelines, and technical requirements. While they reflect a high likelihood that the load will come online, they don’t always guarantee a specific in-service date. Additional agreements, such as Construction Service Agreements (CSAs), are executed later and provide more detailed scheduling and obligations.
Because these agreements often contain commercially sensitive information, they aren’t publicly available. If any of the forecasted load is delayed, the overall zonal capacity obligation remains the same. In that case, the cost of capacity could be spread across a smaller actual load, potentially leading to a daily zonal scaling factor (DZSF) greater than 1.0.

Thank you for pointing this out to us. A revised Default Service Load Data file with corrected data has been posted to the Data page of the RFP website.

All data provided in the Billed Sales and Counts file are correct. First, please note that the billing data file does not equate to the posted settlement data as it incorporates updates and adjustments to customer billing. For example, billing data tracks instances of cancel-billing, where customer ‘counts’ and associated kWhs may be higher or lower due to the cancelling of a bill in one period and rebilling in another period. For this reason, customer counts may jump or drop, which is a function of the billing process and not actual settlement activities or movements. Further, the billing data reflects the actions of customers moving to and from default service supply and retail suppliers. The reasons for such movements are unknown to PPL Electric and are subject to the customer’s actions (or in some instances, events of suppliers returning customers to default supply). For these reasons, there is no single answer to why customer counts or fluctuations occur, but it is a product of all activities, both billing and non-billing, that result in the figures provided.

The Billed Sales and Count Data includes updated billed sales information and customer counts, cancel-rebills, and/or data reprocessing. The Billing Data is meant to provide suppliers with indications in billing, shopping, and aggregated customer counts. There is no single answer as to why customer counts or fluctuations occur—it is likely due to billing and non-billing activities. Please also refer to FR-Data-FAQ-15.

The data found in the daily ICAP & NITS file is accurate and is what was settled on through PJM. Dips or jumps in both ICAP and NITS tag values often correspond with customer migration. PPL Electric’s Price-to-Compare (PTC) changes on June 1 and December 1 of each year – the change in tag values corresponds with the June 1 PTC change. Further, on June 1 the new ICAP tags for the year also went into effect.

There is no migratory event between default service and shopping for residential customers during this period to the knowledge of PPL Electric. The data provided is accurate. PPL does not have additional information regarding changes in Default Service Load on that date.

For historical level of block supply since November 2016, you can refer to the Daily ICAP & NITS Tag Data (Nov 2016 – Present) file, which has block supply broken out for residential customer load. For historical level of block supply before November 2016, you can refer to the Aggregate PLC Summary Data files (2011 – 2016) file, which also has level of block supply broken out for residential customer load.

A summary document describing all Data files is posted to the Data page of the RFP website.

Per DSP VI settlement, PPL Electric’s Standard Offer Program (SOP) will be discontinued as of June 1, 2025. The SOP was available to residential customers, and Small C&I customers under 25 kW peak demand, and excludes CAP customers. Customers who participated in the SOP are shopping customers. The SOP load is provided, in aggregate, in the Billing Data file – represented as a component of the shopping figures in that file. No additional data is available at this time.

Yes. As stated in the Summary tab, updated definition of LP5 includes MT1 as of August 24, 2021. To reiterate, the rate class “MT-1” is included in the rate class “LP5/MT1” or “LP5”.

The data for the rate schedule “LP-5” on the sheets “MonthlyBillSales” is equal to the sum of the data for the rate schedule “LP-5” on the sheet “ShoppingBillSales” and the data for the rate schedule “MT-1” on the sheet “Non-ShoppingBillSales”.

The data for the rate schedule “LP-5” on the sheets “MonthlyBillCounts” is equal to the sum of the data for the rate schedule “LP-5” on the sheet “ShoppingBillCounts” and the data for the rate schedule “MT-1” on the sheet “Non-ShoppingBillCounts”.

In reference to the data file “Billing Data (2010 – Present)”, the rate schedule “BL – Borderline Service – Electric Utilities” should be included in the GS-1 load data on the sheets “Non-ShoppingBillSales” and “Non-ShoppingBillCounts”. In other words, to calculate the GS-1 class billing data, the supplier should add the “BL” class data to the GS-1 data for non-shopping customers.

A portion of the default service load for the Residential Customer Group is served by block products. Currently there are two 50 MW long-term block products procured in DSP V. One 50 MW product expires on May 31, 2026. The other 50 MW product expires on November 30, 2026. PPL Electric has also procured three 10-year 50 MW block products for a supply period June 1, 2026 – May 31, 2036 through the long-term block supply RFP.

Hence, under DSP VI, the scheduled block supply amount is:

• June 1, 2025 – May 31, 2026: 100 MW
• June 1, 2026 – November 30, 2026: 200 MW
• December 1, 2026 – May 31, 2036: 150 MW

(Updated January 30, 2026)

Between 5/23/21 and 5/26/21, PPL experienced system issues impacting the submission of ICAP and NITS data to PJM. While PPL attempted to resubmit data for this period, PJM denied the submission. As a result, the values provided in the data file accurately provides the data as submitted to the market.

The data provided correctly shows increased customer shopping in both the Residential and Small C&I customer classes. This migration to shop is not occurring due to municipal aggregation, community choice aggregation, or other similar shopping programs and is instead the result of individual decisions by customers to shop with a retail supplier. The exact reasons for customers’ decisions are not known to PPL Electric as this information is not provided to the Company by customers.

Time-of-Use (TOU) loads are a component of this procurement, under the currently effective Default Service RFP, within the Residential and Small Commercial & Industrial customer groups, respectively. TOU loads are not procured separately, either through special product or pricing offers, but instead are blended into the basic default service product offerings. As per Section 1.13 of the Default Service RFP Rules, “for the purposes of this RFP, Time-of-Use load will be included in the calculation of Default Service Load.” Further, TOU ICAP and NITS values are also included in the Default Service Load Data and Daily ICAP & NITS Tag Data. Finally, TOU rates are not included in this procurement. Per the PA PUC approved Default Service Plan, TOU rates are a calculation completed by PPL Electric based upon the PPL Electric Price-to-Compare; however, as defined above, are not a separate bid or product.

Currently, PPL Electric does not have any supply obligations related to PURPA. The composition of load procured outside of full requirements contracts by PPL Electric includes net metering customer supply, block energy contracts and NYPA load, where appropriate.

PPL Electric does not nominate ARRs or bid into the PJM FTR auctions. Auction Revenue Rights (ARRs) are assigned to winning wholesale suppliers according to the load they are serving. Wholesale suppliers nominate the ARRs and receive the benefits associated with those nominations through the PJM ARR/FTR auction. Given the timing of the PJM ARR nomination process (February and March, annually), there are instances where a wholesale supplier is provided the opportunity to nominate the ARRs, but may not have a corresponding contract for that future period, either because their current contract ends prior to June 1 and/or the PPL Electric Default Service RFP in February has yet to occur. If a supplier no longer provides supply, the ARRs nominated are transferred by PJM to the resulting supplier(s) for that period. Only net zero and positive positions are transferred – thus winning suppliers are not harmed by another suppliers’ prior nominations.

PJM provides and implements the rules associated with ARRs and FTRs, as found on their website. PPL Electric does not get involved in the supplier ARR nomination process. As such, PPL Electric does not have any information on the paths that are chosen by each supplier during the ARR nomination process.