Data

For the L4L rate class, the negative values for certain hours are due to the supply from customer generators that are in excess of load usage. Information regarding the breakdown of generation and load is not available at this time.

PLCs by rate class within a Customer Group is not available at this time.

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.

The distribution loss percentage can be found in section 6.8 of the document located at: https://www.pplelectric.com/-/media/PPLElectric/Shared-Content/master-pages/gen-supplier-coord-tariff/6-load-forecasting.pdf

The NYPA supply contract is expected to be renewed and the new contract signed by both parties in mid-April 2017. Upon being signed, the contract will be posted to the website.

PPL Electric has posted actual load values associated with NYPA supply on its website. Updates will not be posted at this time. The new contract is expected to be issued and signed in April 2017, going into effect in June 2017. The term of the new contract is expected to be from June 2017 through May 2032. Once the new contract is fully executed, it will be posted on the PPL Electric website.

All load volumes will be de-rated in accordance with PJM marginal loss implementation procedures. DS Suppliers will be responsible for and be paid by PPL Electric based on the hourly loss de-rated load.

Starting June 1, 2015, the SC&I threshold was reduced to include only customers with less than 100 kW annual peak demand; LC&I includes all customers with annual peak demand equal to or above 100 kW. Load Data posted to the RFP website reflects this C&I designation since June 1, 2015. However, PPL Electric does not expect to provide hourly load based on the new classification on a historical basis prior to June 1, 2015.

In PPL Electric’s Load Data and Billing Data sets, the rate groups MP1 and MT1 were previously part of the LP4 and LP5 rate groups (prior to the 500kW demand split of DSP I, and the 100kW demand split of DSP III). As such, PPL Electric defines these groups, MP1 and MT1, as “hourly priced equivalent” rate groups in that they receive hourly priced service.  This is to help differentiate MP1 or MT1 customers from other LP4 or LP5 customers in PPL Electric’s systems who are on fixed price service. As such, customers on these MP-1 and MT-1 rates do receive hourly or spot market service and pricing.

PPL Electric has implemented a revised demand split in June 2015 and again in December 2017, where C&I default service customers with peak demand below 100kW were classified to be Small C&I, and default service customers with peak demand at or above 100kW were classified to be Large C&I. The contribution of this demand split was minimal when determining the PLC. Also of note, the 100kW demand threshold shift was implemented in a one-time-only fashion, associated with the default service plan at that time. For DSP IV, the determination of peak demand will be based on the customer’s ICAP peak load contribution assigned for the 2016-2017 PJM Planning Year. Once implemented default service customers are not reshuffled between Large and Small C&I customer groups.   For information related to default service customers, please see the daily PLC aggregate summary data provided by Customer Group as well as the hourly load data provided by Customer Group.

There are a variety of reasons why monthly billed sales at the retail meter times the loss factors do not yield the same value as the sum of hourly loads at the generation level. These include the fact that loss factors are average loss factors and that losses in some months may be higher or lower than that implied by the loss factors. However, the primary reason for the difference is that the comparison you are making is for different time frames. Monthly billed sales reflect what PPL Electric is billing each month and includes usage of the customer in the prior month. For example, billed sales for a bill issued on September 3, will be all counted toward September monthly billed sales, even though the usage occurred mainly in August and would be included mainly in August hourly loads. Monthly billed sales for any month reflect the billing cycle and generally reflect usage over the current and prior month, with different proportions for each customer depending on when a customer's bill is issued. There is no calculation that will align monthly billed sales and hourly loads.

To gain a better understanding of how PLCs are calculated, please see the following presentation.

Historical load data provided on the RFP Web site are not de-rated for marginal losses. However, hourly loss deration factors are provided on the RFP Web site so that each supplier may perform this calculation. For settlement purposes, suppliers will be responsible for the hourly loss de-rated load, and will be paid by PPL Electric for this hourly loss de-rated load.

Yes, the load data provided is in Eastern Prevailing Time.

Both values are correct, but include different components. The value of 7629.6MW is the PPL Electric Zonal Target and does not include municipality or NYPA load. This is the base target PPL Electric ties to on a daily basis. The value of 7844 includes municipality load and NYPA load.

You are correct. The historical hourly load data are presented based on the hour ending values.

This information is provided in the “Load Data” file posted to the Data section of the RFP website. Hourly load data is provided for total retail (Default Service customers and shopping customers), but the information is provided by rate class.

Both values are correct and contain different components, resulting in slightly different values at any given point in time. First, the load values provided on the website through the “Load Data” file are the best available at a given point in time, but do not contain any updates or reconciliation that may occur at a later date through a Settlement B or Settlement C process. As such, values may be higher or lower at any given hour than actual final values reported through PJM’s website. Second, the values provided, as found on the PJM website contains different inputs in relation to the load data provided on the website. For instance, the PJM data contains Non-Utility Generation (NUG) load that is negative (i.e. Generation) and excludes different accounts, such as FERC and Municipality accounts. The data provided on the PPL Electric website is meant to give the best, publically available data possible at a point in time for supplier to understand historic usage at a point in time, but may not be a value that is ultimately settled upon through the PJM process.

All load values are for total retail customers (including shopping customers) in the load data file. PPL Electric does not have historical hourly load data broken down between default service customers and shopping customers. PPL Electric does provide monthly shopping sales and monthly shopping bill counts by rate schedule in this file.

Yes.  All load data is presented in kWh format.

You are incorrect, the historical hourly load data given in the Load Data file includes all appropriate line losses and reflects closely to what PPL Electric has reported to PJM to derive PPL Zonal Load. Specifically, the hourly load of each rate group have been appropriately multiplied by the correct loss factor. All Residential and Small C&I customer classes have “Secondary” loss factors applied (1.08047231). Large C&I customers have different loss factors – Primary, Transmission, or Secondary and are broken up as follows: Primary Rate Groups are ISP, LP4 and MP1;  Transmission Rate Groups are LP5, LP6, LPEP, and MT1; Secondary Rate Groups are MG3 and OP3.  For avoidance of doubt, both the historical load data series for the period prior to 2010 as well as for the period for 2010 onwards are for total retail customers (i.e., default service and shopping customers) and include all losses.

Your understanding is correct.  Please see Data-FAQ-18.

No, NYPA load values, supplied by the Allegheny Energy Cooperative, are at the retail level (without losses). PPL Electric adds transmission level losses to the values found in the NYPA Load file before submitting to PJM.

PPL Electric accepts NYPA supply at the Transmission Level and adds transmission level losses to the NYPA values found in the NYPA data file before submitting to PJM. NYPA supply values found in the NYPA data file are at the retail level (no losses). To derive the values supplied to PJM, transmission level losses must be applied.

The historical load values reflect the hourly load of all retail customers, and includes both default service and shopping customers.  This data does not include any adjustments for PURPA, NYPA or block supply. This data is net of any behind-the-meter generation, which means that it includes only the energy distributed to the customer by PPL Electric.

There has been a number of updates to the NYPA Agreement over the term of the agreement. The original NYPA Agreement as well as NYPA supply data has been provided as a courtesy to bidders.  The NYPA hourly energy values as found on the Historical Hourly Load NYPA Supply data file are the most up-to-date data available with respect to historical NYPA energy supply.

Updated Billing Data for the October 2017 solicitation is posted to the Data page of the RFP website.

An interim agreement that extends the term of NYPA agreement has been posted to the Data page of the RFP website.

The lighting data for the period of July 18, 2017 and onward was not finalized by the time that the Load data was posted.  This information will be provided in the next data update, which will occur prior to the Bid Proposal Due Date.

Network Service Peak Load (NSPL) data is available in the “NSPL-NITS” tab of the Load Data file posted to the Data page.

On October 20, 2016, PPL Electric converted from an old Meter Data Management System (MDMS) to a new MDMS. During this conversion process significant data corrections, customer data reconciliation, duplicate account and meter elimination, and meter data validation occurred.  As a result of this migration, the new MDMS now has more accurate load values, which you have correctly identified as occurring near November 2016.  Also, load data presented in the data file is point in time – as such, it typically does not have the benefit of Settlement B reconciliation or other similar data corrections that are reported to PJM.

An interim agreement that extends the term of the current NYPA agreement to October 15, 2017 has been posted to the Data page of the RFP website. The term of the new contract is expected to be from June 2017 through May 2032. PPL Electric has posted actual load values associated with NYPA supply on its website.

This FAQ has been updated for clarity on April 8, 2019. Please see below Data-FAQ-10 for response.

All suppliers who were serving the load at the time of switching to the new MDMS were notified of such change prior to the implementation.  Also, new hourly load data for default service by Customer Group has been posted to the Data page of the RFP website for RFP Bidders.

New hourly load data for default service by Customer Group has been posted to the Data page of the RFP website for RFP Bidders. At this time, PPL Electric does not expect to provide other types of data than what is currently available on the RFP website.

New hourly load data for default service by Customer Group has been posted to the Data page of the RFP website for RFP Bidders. At this time, PPL Electric does not expect to provide other types of data than what is currently available on the RFP website.

With reference to the data entitled “Default Service Load Data (June 2015 – Present)”, the data reflects reconciled MWh values sent to PJM by PPL Electric, which includes all the applicable distribution and transmission losses (including PJM assigned 500kV losses and unaccounted for energy), but is not derated for marginal losses. For the Residential Customer Group, the data includes the load served by the long-term block product and excludes the load served by NYPA supply. All load volumes will then be derated in accordance with PJM marginal loss implementation procedures by PJM. Suppliers will be responsible for and be paid by PPL Electric based on the hourly loss derated load. (Please note that an earlier response to this question incorrectly indicated that the data has been derated for marginal losses, which is not true.)

The Load Data file has been updated to include LPEP hourly load through January 31, 2018.

MT1 customers are LP5 customers that are deemed not shopping. The Billing Data file has been updated by changing the label of “LP5” customers under the non-shopping tabs to now be designated “MT1”.

PPL Electric provides PLC data by customer class for the 2018/2019 PJM planning period in the file ‘Load Data (2010 – Present) posted to the Data page of the RFP website.

PPL Electric provides monthly shopping sales and monthly shopping bill counts by rate schedule in the file ‘Billing Data (2010 – Present)’ posted to the Data page of the RFP website.

The “Daily ICAP & NITS Tag Data“ file provided on the Data page of the RFP website provides the daily breakdown of PLC by default service and shopping customers.

The posted peak load values, found on the Capacity tab of the Load Data file, are correct as presented. The total load values ties to the PJM prescribed target value exactly. Please note, the 2018 ICAP value presented commences on June 1, 2018. While the overall ICAP target decreased, this does not necessarily mean that all customer groups unilaterally decrease as well. As seen with the underlying values – the Residential customer group ICAP increased, while other customer groups ICAP decreased. From 2009 to 2010 planning periods, the ICAP target value also decreased, but at this time, the Small C&I customer group saw an increase. The values, while seemingly anomalous, is in fact correct.

PPL Electric acknowledges that there are two anomalous data points in the “Load Data (2010 – Present)” file: November 5, 2017 HE200 load in the “SCI_Load_2015+” tab and December 6, 2017 HE200 in load in the “LCI_Load_2015+” tab.  At the moment, PPL Electric cannot provide updated data for these data points before the RFP Bid Proposal Due Date and the data posted to the Data page is the best available at a given point in time.

At the moment, PPL Electric expects to provide a final update to the data currently provided on the RFP website before the RFP Bid Proposal Due Date. The RFP Manager will send out an announcement when the updated data is posted to the RFP website.

The “Total MW” column found on the “Capacity” tab of the “Rate Load Data 2010+” workbook ties to the PPL Area Peak Load Contribution Assignment, less the NYPA generation supply. For example, the direct tie to the PPL Area Peak Load Contribution Assignment with NYPA supply included for 2018/2019 ICAP is 6,600.00, where NYPA supply accounts for 6.2MW, dropping the shown value to 6,593.8MW.

PPL Electric does not expect to provide another update to the data currently provided on the RFP website before the RFP Bid Proposal Due Date.   All data provided is the most up-to-date and PJM settlement approved data available.

NYPA and block energy supply contracts are energy-only contracts. Capacity, AECs, and ancillary services are the responsibility of PPL Electric to acquire through PJM.

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

The data for the Residential Customer Group in the file “Default Service Load Data (June 2015 – Present)” includes the load served by the long-term block product. Please see Data-FAQ-37 for information.

The historical load data are at wholesale level and not retail level. Further, the line loss values used for settlement have not changed. As stated in Data-FAQ-31, PPL Electric converted from an old Meter Data Management System (MDMS) to a new MDMS in October 2016, which resulted in more accurate load values. As stated in Data-FAQ-10, comparing the monthly billed sales data with the hourly load data is not appropriate and there are many reasons why monthly billed sales at the retail meter times the loss factors do not yield the same value as the sum of hourly loads at the generation level. Please see Data-FAQ-10 and Data-FAQ-31 and Data-FAQ-37 for additional information.

Annual PLC information for the 2019/2020 PJM Planning Year is not available by rate class for Default Service Customers only. However, the “Daily ICAP & NITS Tag Data” file provided on the Data page of the RFP website provides the daily breakdown of PLC by default service and shopping customers.

PPL Electric has implemented a revised demand split in June 2015 and again in December 2017, where C&I default service customers with peak demand below 100kW were classified to be Small C&I, and default service customers with peak demand at or above 100kW were classified to be Large C&I. Such shift was at one-time-only fashion per each DSP where the June 2015 demand split was done under the third Default Service Program (DSP III) and the December 2017 demand split was done under the fourth Default Service Program (DSP IV).

The 100kW demand split is applied to GS3 and LP4 customers based upon each customer’s ICAP tag. GS3 and LP4 customers with ICAP tags less than 100kW are deemed Small C&I and customers with an ICAP tag 100 kW or above are deemed Large C&I. Of note, ICAP tags are updated annually; however, PPL Electric has only been approved to assess and reorganize GS3 and LP4 customer demand splits once each plan, at the plan’s commencement. In June 2015, at the start of the third Default Service Program (DSP III), PPL Electric reviewed customer’s ICAP tags, applying the 100kW demand split accordingly. In December 2017, shortly after the commencement of the fourth Default Service Program (DSP IV), PPL Electric again reviewed customer ICAP tags and applied the 100kW demand split. Each shift occurs one-time-only per each DSP.

Data on the estimated demand split that occurred at the beginning of the DSP3 is provided as “C&I Demand Split Statistics” tab in the Rate Load Data. Once the 100kW was implemented, the subsequent customer adjustment that occurred going into DSP4 was not substantive. PPL Electric does not track customer movement during the 100kW demand split adjustments and does not have this information to provide.

Yes, the Rate Load Data includes the load served by the block energy in the “RES_Load_2015+” tab.

RFP Bidders may make its analysis based on all historical data posted to the Data page of the RFP website for RFP Bidders. The data posted is the best available at a given point in time. All suppliers who were serving the load at the time of switching to the new MDMS were notified of such change prior to the implementation.

The eligible residential hour load data (which includes both default service and shopping customers) provided in the “Rate Load Data” file is not exactly comparable to the default service hourly load data provided in the “Default Service Load Data” file. The “Rate Load Data” reflects data that is point in time as initially provided to PJM (Settlement A) and does not reflect final settled data whereas the “Default Service Load Data” reflects final PJM settled data for the default service load after the Settlement B process. As such we are unable to perform the calculations that would reconcile the two datasets. Please also see Data FAQ-26 and Data FAQ-38 for additional information.

The load values provided on the website through the “Load Data” file are the best available at a given point in time, but do not contain any updates or reconciliation that may occur at a later date through a Settlement B or Settlement C process. As such, the data reflects what is initially reported to PJM (as opposed to reconciled data).

The “Rate Load Data” reflects the data that is point-in time generation aggregation data. It does not include FERC and Company Use load data. It is as initially provided to PJM (Settlement A) and does not reflect the final settlement data after Settlement B or Settlement C. In summary, Rate Load Data is best available, actual, point in time load data and cannot be directly tied to the settled data found at PJM.

The PPL Electric CAP SOP does not currently have any customers participating on the program. From June 1, 2018 through February 29, 2020 no retails suppliers participated in the program; therefore, the program went dormant, no longer accepting CAP customers. Beginning March 1, 2020 the program became active; however, PPL Electric has no statistics on customer participation at this time.

This LPEP data shown is correct. Current load for this contract is zero.

With respect to the data file under “Rate Load Data (2010 – Present)”, the TOU Load is provided separately and is mutually exclusive from other data series in that file (i.e., the data in RS TOU column is not included in data values of the RS column). With respect to the date file under “Billing Data (2010 – Present)”, the TOU Load is provided separately and is mutually exclusive from other data series in that file (i.e., the data in RS TOU column is not included in data values of the RS column). With respect to the data file under “Default Service Load Data (June 2015 – Present)”, the TOU values are included in the default service data to the extent that TOU load is served by default service suppliers. You can find the results of each TOU RFP solicitation on the TOU-RFP results page.  For example, the TOU RFP failed to procure tranches for each of the Residential and the Small Commercial & Industrial Customer Groups in the May 2019 and October 2019 solicitations, which is associated with the supply period June 1, 2019 through May 31, 2020. As such, under the TOU Contingency Plan, the TOU Load for the applicable supply period (June 1, 2019 through May 31, 2020) has been included in the Default Service Load for the applicable period and served by the Default Service Suppliers providing Default Service Supply. 3. As stated in Data-FAQ-40 and Data-FAQ-43, PLCs by rate class within a Customer Group is not available at this time.  PPL Electric provides PLC data by customer class for each PJM planning period in the file ‘Rate Load Data (2010 – Present) posted to the Data page of the RFP website. The “Daily ICAP & NITS Tag Data“ file provided on the Data page of the RFP website provides the daily breakdown of PLC by default service and shopping customers. No additional data is readily available at this time.

Previous RFP results can be found on the RFP Results page under the Default Service RFP section (https://ppldsp.com/default-service-rfp/rfp-results/) and the Archives page under the Background Information section (https://ppldsp.com/background/archives/).

Thank you for pointing this out to us.  The data was errantly removed when updating the values for the 2020/21 period. A revised NYPA file with corrected data has been posted to the Data page of the RFP website.

Thank you for pointing this out to us. The POLR_Load data file has been reviewed and updated for all three customer groups from December 1, 2019 through June 30, 2020.

Data reported in the Rate Load Data file (updated September 11, 2020) and in the ICAP & NITS data file (updated August 28, 2020) are correct.  The aggregate capacity values displayed in the Rate Load Data file provide point in time data as reported to PJM as of December 31st of each year, when the initial customer tags are created and peak load values are established. Prior to implementation of new ICAP tags on June 1, subsequent data updates occur including updates and corrections of customer tag values, and customers leaving or entering PPL Electric service territory. Both impact the resulting ICAP and NITS file values.  The differences identified between the daily ICAP and NITS file and the Rate Load Data file include these differences. It should be noted that the aggregate capacity and transmission values are meant to be estimated markers only due to the nature of their creation, with actual ICAP and NITS values reported in the ICAP and NITS data file as the final, actual value, as reported daily to PJM for settlement purposes.

PPL Electric’s calculation methodology will not be adjusted or changed for the 2020/21 ICAP and NITS period when determining customer ICAP and NITS tags.  All data currently provided on the RFP website will continue; however, PPL Electric does not expect to provide any additional data at this time.

All data currently provided on the RFP website will continue; however, PPL Electric does not expect to provide any additional data at this time.

Average customer data including average customer tag values can be found at: https://www.pplelectric.com/-/media/PPLElectric/At-Your-Service/Docs/General-Supplier-Reference-Information/2020/2020PPLElectricPLCDefaultValuesandLossFactors.pdf?la=en

The Residential data reported in the Default Service Load Data file are correct. All data from December 2019 through June 2020 has been redownloaded to provide the best available settlement date for all customer groups.

First, please note that the “Rate Load Data (2010-present)” data file has been updated on September 11, 2020 with updated annual data in the “Capacity” tab. Second, there are a variety of reasons why the comparison you are making between the daily Default Service PLC values and the Billing Data is inappropriate. One reasons this is inappropriate is that the comparison you are making is for different time frames. The “Daily ICAP & NITS Tag Data (Nov 2016 – Present)“ file provided on the Data page of the RFP website provides the daily breakdown of PLC by default service and shopping customers whereas the “Billing Data (2010-present)” file provides monthly billed sales and count information based on what PPL Electric is billing each month and includes usage of the customer in the prior month. Please see Data-FAQ-11 for more information.

PPL Electric provides metered hourly load by customer group in the file ‘Rate Load Data (2010 – Present)’ posted to the Data page of the RFP website.

The data provided is directly from the PPL Electric Meter Data Management System, used to create the submission files that are reported to PJM. Please see Data-FAQ-31.

The data provided in both ICAP and NITS tabs, highlighted in ‘grey’ is estimated data only. This is not final submissions data to PJM and will be updated in later data updates once finalized.

Given the potential changes in customer usage as a result of COVID-19, PPL Electric has updated the Default Service Load data file to provide unreconciled Settlement A data for the months of July and August 2020.  This data is being provided as a one-time action, which will be overwritten in future auctions with reconciled Settlement B data. The Settlement A data provided is intended to be used as a best estimate for default service load, pending the finalization of the Settlement B data in future months. As Settlement B data becomes available for these time periods, PPL Electric will overwrite the Settlement A data with final, Settlement B data. Should Settlement B data become available prior to October 5, 2020, the Company will issue an update, replacing the Settlement A values. If completed, the RFP Manager will send out an announcement if and when the update is posted to the RFP website. Response revised on October 1, 2020