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Changes in Law

Thank you for trusting us with your energy supply. This page provides a central repository for regulatory changes. We’ve included current-year changes, as well as an archive, so you can quickly locate any changes in law that may impact your business.

Changes in Law

Thank you for trusting us with your energy supply. This page provides a central repository for regulatory changes. We’ve included current-year changes, as well as an archive, so you can quickly locate any changes in law that may impact your business.

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06-03-2026

Title
Daily market update-Jun 3, 2026
Snapshot Update Text
The July ’26 natural gas contract is trading up $0.01 at $3.18. The July ‘26 crude oil contract is up $2.34 at $96.10.
Summary Update Text

The natural gas market saw minimal movement yesterday, with the prompt month falling by just a penny to close the day at $3.167/MMBtu. The 2027 and 2028 strips both moved by less than a penny on the day, while 2029 and 2030 each fell by two cents. The market remains backwardated for 2028-2033. From a fundamentals perspective, natural gas production is expected to increase slightly to 107.5 Bcf/d. This is in line with recent days and just slightly above the May average. LNG export feedgas is forecasted to strengthen to 16.5 Bcf/d after falling below 16 Bcf/d yesterday. Overall demand is expected to remain mostly flat today. Market analysts are expecting a 99 Bcf injection into storage to be reported tomorrow for the week to May 29, which would be below the 5-year average of 101 Bcf and the year-ago injection of 119 Bcf. Storage levels would still remain at a healthy surplus to the 5-year average, but overall inventory would be flat with last year. Forecasts are showing warmer-than-average temperatures in the northern half of the U.S. through the end of the week, while the above-average temperatures become concentrated in the central part of the country next week.

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The easiest way to ensure your bill is paid on time every time is to set up AutoPay by logging in to your online account and following the steps to set up automatic payments. You may also wish to set up payments through your bank using ACH or EFT. If you are paying by check/money order through the mail, be sure that the check amount equals the exact amount due shown on your payment stub(s)/remittance slip. If you can’t submit the stub(s), you can include a listing of the accounts and the amounts due that you are submitting one check for. If you submit payment in the mail without the stub or an enclosure of account numbers and/or the amount of your check doesn’t match what is owed, this can result in processing delays or misapplied payments.

 

The stub/remittance slip is at the bottom of your invoice. It should be detached and included with your mailed payments.

Yes. To ensure we apply your payment accurately, please mail a document which includes the following information:

  • Customer account number
  • Invoice number
  • Amount to be applied to each contract account or invoice number

If applicable, this same information can also be referenced on your check voucher/skirt detail. Your check total should equal the balance due of all combined invoices that you are paying. Payments submitted without the proper details could take up to five business days to process once we receive them. As a reminder, there are fast easy options for paying online that can save you time and eliminate the need to gather and collate account information.

As a general rule, when a payment is received by us, it will be posted to your account within 24-48 hours. We recommend mailing your payment at least 5-7 business days before the payment due date to allow for delivery time by the U.S. Postal Service. Our overnight mail requires at least two business days for posting. As a reminder, to ensure swift processing, be sure to submit your mailed payment with the bill stub and ensure the check has the exact balance due.

 

No, you must submit the payment for the amount due as listed on your bill stub. To apply bill credits, which may have resulted from a previous overpayment and/or a corrected/adjusted invoice, please call Client Services at 844.737.6742.

If you’re mailing in a payment, detach your bill stub and submit with a check that equals the exact amount shown on the stub to the remittance address shown on the stub. If you’re paying online, payments can be made to one account/site as default either by logging in to your account or by using QuickPay.

Yes, you can submit one payment for multiple sites. If you’re mailing in a payment, be sure to submit all bill stubs and ensure the amount on the check equals the total of the amount due from all the bill stubs. If you’re paying online and you’re logged into your online account, you have the option of adding sites together and executing one payment transaction for multiple sites. Payments made online by credit card however can only be done by site (see below). 

Certain customers are eligible to pay by credit card online. This option will appear automatically if you qualify. You can make a one-time payment or set up recurring payments using a credit card by logging in to your account or by using QuickPay (one-time payment without logging in). Please keep in mind that credit card payments can only be made by site so if you have multiple sites and are paying online by credit card, you will have to execute a payment transaction for each site.

Payments submitted without bill stubs and/or reference information (i.e. customer account number, invoice number, and amount to be applied to each) can delay processing and take up to five business days to post. Additionally, payments submitted that don’t match the amount due on the invoice can also delay processing.

Our dedicated, U.S.-based Client Services team is here to answer your questions and help you with payment setup processes. Email PowerSupport@nrg.com or call us at 844.737.6742.

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2026

The following information is applicable to any service location(s) you have in the given regions denoted.

Change type/cost component, commodity impact and effective date NATURAL GAS: Core Daily Delivery program cost changes—June 1, 2026
Utility territory/region impacted NY: Long Island Light Company (LILCO) and Brooklyn Union Gas (BUG)
Explanation of change BUG and LILCO each implemented an update of costs for its Core Daily Delivery program, which went into effect on May 1, 2026. Core Daily Delivery is a natural gas delivery and storage service that we are required to purchase from the local utility to serve our natural gas customers. As a result of this cost update, we will be passing through the change in costs on your invoice, starting with June 2026 usage.
How/when will I see the change If you're billed by us: you will see the impact from this program cost change as a separate line item labeled "Change in Law 05/01/26,” beginning with any usage from June 1 forward. Please note that if you experienced a change in law in the past, you may have more than one change in law line item on your invoice. If you're billed by the utility on our behalf: you will see the impact from this program cost change as an adjustment in your unit price on your utility invoice, beginning with any usage from June 1 forward.
Change type/cost component, commodity impact and effective date NATURAL GAS: Pipeline rate decrease – Transco Interstate Pipeline – March 1, 2026
Utility territory/region impacted PA: Philadelphia Electric Co (PECO) and Philadelphia Gas Works (PGW)
Explanation of change The Federal Energy Regulatory Commission (FERC) approved a rate decrease filed by the Transco Interstate Pipeline Company (Docket No. RP24-1035), which took effect March 1, 2026. Changes in pipeline rates can impact pipeline capacity costs, which we are required to procure from the local distribution companies (LDCs) on behalf of our customers. Because the Transco pipeline supplies gas to the PECO and PGW service areas, there is a corresponding decrease in the cost of capacity behind these LDCs, as filed in their capacity release program (CRP) cost updates.
How/when will I see the change The impact of this capacity cost change will be displayed as a separate line item labeled "Change in Law 3/1/2026,” beginning with your April 2026 usage (invoiced in May).

The following information is applicable to any service location(s) you have in the given regions denoted.

Change type/cost component, commodity impact and effective date

 NATURAL GAS:  pipeline capacity cost changes – Nov. 1, 2025
Utility territory/region impacted NY: Orange & Rockland (O&R); PA: UGI pipeline capacity release programs
Explanation of change Orange & Rockland and UGI, each implemented their annual update of costs for their capacity release programs, which went into effect on Nov. 1, 2025. These programs cover natural gas delivery and storage services that we are required to purchase from the local gas utilities to serve our natural gas customers. As a result of the annual cost update, we will be passing through the changes in costs, starting with your December usage.
How/when will I see the change You will see the impact from the change in capacity release program costs as a separate line item labeled "Change in Law 11/01/2025,” beginning with usage from Dec. 1 forward.
Change type/cost component, commodity impact and effective date NATURAL GAS:  daily delivery service cost changes – Nov. 1, 2025
Utility territory/region impacted

NY: Consolidated Edison (ConEd), Keyspan: Brooklyn Union Gas (BUG) and Long Island Light Company (LILCO)
Explanation of change ConEd, BUG, and LILCO all implemented their annual update of costs for their daily gas delivery programs, which went into effect on Nov. 1, 2025. These programs cover natural gas delivery and storage services that we are required to purchase from the local gas utilities to serve our natural gas customers. As a result of the annual cost updates, we will be passing through the change in costs, starting with your December 2025 usage.
How/when will I see the change

If you’re billed by us: You will see the impact from the change in costs as a separate line item labeled "Change in Law 11/01/2025,” beginning with usage from Dec. 1 forward.

 

If you’re billed by the utility on our behalf: you will see the impact from this change in costs as an adjustment in your unit price on your utility invoice, beginning with any usage from Dec. 1 forward.
Change type/cost component, commodity impact and effective date NATURAL GAS:  pipeline capacity cost changes – Nov. 1, 2025
Utility territory/region impacted

New England gas utilities: Berkshire Gas, Colonial Gas, Connecticut Natural Gas, Energy North, Essex Gas, Eversource-NSTAR, Eversource Gas Company of Massachusetts (EGMA), Fall River Gas, Fitchburg Gas Company, Keyspan-Boston, National Grid-Rhode Island Energy, Northern Utilities Maine, Northern Utilities New Hampshire, Southern Connecticut Gas Company
Explanation of change The New England gas utilities reset the program requirements for the annual Capacity Release Program (CRP), which impacts the natural gas supply costs associated with Transportation, Capacity, Storage, and Peaking, which we are required to procure on behalf of our customers. As a result of the changes to the capacity release program requirements, we will be passing through the associated change in costs starting with your December 2025 usage.
How/when will I see the change

If you're billed by us: you will see this change in costs as a separate line item labeled "Change in Law 11/01/2025,” beginning with any billed usage from Dec. 1, forward.

If you're billed by the utility on our behalf: you will see the impact from this change in costs as an adjustment on your utility invoice near your gas supply charges, beginning with any usage from Dec. 1, forward.
Change type/cost component, commodity impact and effective date NATURAL GAS:  Primary point pipeline capacity cost increase – Nov. 1, 2025
Utility territory/region impacted NY: National Grid Niagara Mohawk (NiMo)
Explanation of change

The New York State Public Service Commission (PSC) recently approved National Grid-Niagara Mohawk’s (NGRID-Nimo) Gas Rate Case, 24-G-0323, which include changes to NiMo’s Firm Daily Balanced Retail Access program. Marketers like NRG are now required to contract for annual Primary Point Capacity (PPC) in a quantity sufficient to meet 100% of a firm daily balanced customer’s maximum peak day quantity (MPDQ). To comply with this new MPDQ requirement, NRG must obtain more primary point pipeline capacity, which will increase the cost to serve firm daily balanced customers.
How/when will I see the change

The cost impact of the change to NiMo’s Firm Daily Balanced Retail Access program will be displayed as a separate line item labeled "Change in Law 11/1/2025,” beginning with November 2025 usage (billed in December).
Change type/cost component, commodity impact and effective date NATURAL GAS:  Pipeline rate decrease/capacity and delivery cost changes – Sept. 1, 2025
Utility territory/region impacted RI: Rhode Island Energy (RIE); OH: Columbia Gas of Ohio and Enbridge Gas Ohio; VA: Columbia Gas of Virginia.
Explanation of change

On July 1, the Federal Energy Regulatory Commission (FERC) approved final rates in Columbia Gas’s General Natural Gas Act Section 4 rate case*, which resulted in a pipeline rate decrease. Increases and decreases in pipeline rates can cause changes in pipeline capacity and delivery costs, which we are required to procure from the local distribution companies (LDCs) on behalf of our customers.
How/when will I see the change

The impact from this change in costs will be displayed as a separate line item labeled "Change in Law 09/01/2025,” beginning with September 2025 usage.

 

* Docket Nos. RP24-1103-000/RP24-1103-001, Doc. Accession #20250701-5199 (July 1, 2025)
Change type/cost component, commodity impact and effective date NATURAL GAS:  Capacity Release Program cost changes – Aug. 1, 2025
Utility territory/region impacted NY: New York State Electric & Gas (NYSEG)
Explanation of change The New York State Electric & Gas Corporation (NYSEG) filed updated cost calculations with the New York Public Service Commission (PSC) for their capacity release program (CRP). This newly filed rates, which are effective Aug. 1, have decreased over the rates that took effect on April 1. This cost change is due in large part to a pipeline rate decrease from Columbia Gas (TCO) pipeline, which supplies gas to NYSEG’s service area. Increases and decreases in pipeline rates cause changes in the cost of pipeline capacity, which we are required to procure on behalf of our customers.
How/when will I see the change The impact from this change in costs will be displayed as a separate line item labeled "Change in Law 08/01/2025,” beginning with August 2025 usage.
Change type/cost component, commodity impact and effective date NATURAL GAS:  Pipeline rate increase (Transco pipeline)/Core Daily Delivery Service Program cost changes – May 1, 2025
Utility territory/region impacted NY: Keyspan-Brooklyn Union Gas (BUG) and Keyspan-Long Island (LILCO)
Explanation of change Earlier this year the Federal Energy Regulatory Commission (FERC) approved a rate increase filed by the Transco Interstate Pipeline Company (Docket No. RP24-1035), which took effect March 1, 2025. Increases in pipeline rates can cause increases in pipeline capacity and delivery costs, which we are required to procure from the local distribution companies (LDCs) on behalf of our customers. As a result of the Transco rate increase, Keyspan-Brooklyn Union Gas (BUG) and Keyspan-Long Island (LILCO) initiated updates to their Core Daily Delivery Service (DDS) program, which caused a change in costs for DDS effective May 1, 2025.
How/when will I see the change

The impact of the DDS change in costs will be displayed as a separate line item labeled "Change in Law 5/1/2025,” beginning with June 2025 usage (billed in July).
Change type/cost component, commodity impact and effective date NATURAL GAS:  Pipeline rate increase (Columbia Gas/Transco pipelines)/capacity cost increase – May 1, 2025
Utility territory/region impacted D.C., MD, VA: Washington Gas & Light (WGL)
Explanation of change The Transco Interstate Pipeline Company and Columbia Gas Transmission, LLC, both filed General Natural Gas Act Section 4 rate cases with the FERC (Docket No. RP24-1035 and Docket No. RP24-1103-000) that resulted in rate increases. Because these pipelines supply gas to the WGL service area, there is a corresponding increase in the cost of capacity behind WGL. Pipeline capacity is a required component of natural gas supply and all customers, regardless of who supplies their natural gas (the utility or a retail supplier), are subject to pipeline capacity costs.
How/when will I see the change The impact from this cost change will be displayed as a separate line item labeled "Change in Law 5/1/2025,” beginning with May 2025 usage.

Change type/cost component, commodity impact and effective date

 NATURAL GAS:  Pipeline rate increase – Transco Interstate Pipeline – March 1, 2025
Utility territory/region impacted PA: Philadelphia Electric Co (PECO) and Philadelphia Gas Works (PGW)
Explanation of change

The Federal Energy Regulatory Commission (FERC) approved a rate increase filed by the Transco Interstate Pipeline Company (Docket No. RP24-1035), which took effect March 1, 2025. Increases in pipeline rates can cause increases in pipeline capacity costs, which we are required to procure from the local distribution companies (LDCs) on behalf of our customers. Because the Transco pipeline supplies gas to the PECO and PGW service areas, there is a corresponding increase in the cost of capacity behind these LDCs, as filed in their capacity release program (CRP) cost updates.
How/when will I see the change The impact of the capacity cost change will be displayed as a separate line item labeled "Change in Law 3/1/2025,” beginning with your April 2025 usage (invoiced in May). Although the changes went into effect Mar. 1, we are not applying the cost changes retroactively.
Change type/cost component, commodity impact and effective date NATURAL GAS:  Pipeline rate increase – Columbia Gas Pipeline – April 1, 2025
Utility territory/region impacted PA: UGI Utilities, Inc.; OH: Columbia Gas of Ohio and Enbridge Gas Ohio; VA: Columbia Gas of Virginia; RI: Rhode Island Energy
Explanation of change

Columbia Gas Transmission, LLC, a subsidiary of TC Energy, filed a General Natural Gas Act Section 4 rate case with the FERC (Docket No. RP24-1103-000) that resulted in a rate increase for pipeline capacity costs. Increases in pipeline rates can cause increases in pipeline capacity and delivery costs, which we are required to procure from the local distribution companies (LDCs) on behalf of our customers. Because the Columbia Gas pipeline supplies gas to the above utilities, there is a corresponding increase in the cost of gas delivery in these service areas.
How/when will I see the change The impact from the rate change will be displayed as a separate line item labeled “Change in Law 4/1/2025,” beginning with April usage.
Change type/cost component, commodity impact and effective date NATURAL GAS:  Capacity Release Program cost changes - April 1, 2025
Utility territory/region impacted NY: New York State Electric & Gas (NYSEG)
Explanation of change

Each year the New York State Electric & Gas Corporation (NYSEG) files updated cost calculations with the New York Public Service Commission (PSC) for their capacity release program (CRP). This year’s filed rates, which are effective April 1, have increased over last year’s. This increase is due in large part to pipeline rate increases from Algonquin (AGT) and Columbia Gas (TCO) pipeline companies, which supply gas to NYSEG’s service area. Increases in pipeline rates cause increases in pipeline capacity, which we are required to procure on behalf of our customers.
How/when will I see the change The impact from the change in costs will be displayed as a separate line item labeled "Change in Law 4/1/2025,” beginning with your April 2025 usage.

The following information is applicable to any service location(s) you have in the given regions denoted.

Change type/cost component, commodity impact and effective date

 NATURAL GAS:  Capacity Release Program cost changes
Utility territory/region impacted NY: Orange & Rockland (O&R).
Explanation of change Orange & Rockland (O&R) implemented its annual update of costs for its Mandatory Capacity Release Program (CRP), which went into effect on Nov. 1, 2024. The CRP is a natural gas delivery and storage service that we are required to purchase from O&R to serve our natural gas customers. As a result of the annual cost update, we will be passing through the change in costs on your invoice, which could be a charge or a credit, starting with your December 2024 usage.
How/when will I see the change

If you're billed by us: you will see the impact from the CRP costs as a separate line item labeled "Change in Law 11012024,” beginning with any usage from Dec. 1 forward. Please note that if you experienced a change in law in the past, you may have more than one change in law line item on your invoice.

If you're billed by the utility on our behalf: you will see the impact from the change in CRP costs as an adjustment in your unit price on your utility invoice, beginning with any usage from Dec. 1 forward.
Change type/cost component, commodity impact and effective date NATURAL GAS:  Capacity Release Program cost changes
Utility territory/region impacted New England utilities: Berkshire Gas, Eversource-Yankee, Colonial Gas, Fall River Gas, Connecticut Natural Gas, Fitchburg Gas Company, Energy North, Keyspan - Boston, Essex Gas Company, Rhode Island Energy, Eversource - NSTAR, Northern Utilities Maine, Eversource-EGMA (the new Baystate), Northern Utilities New Hampshire, Southern Connecticut Gas Company.
Explanation of change Earlier in 2024, the New England utilities reset the program requirements for the annual Capacity Release Program (CRP), which impacts the costs associated with Transportation, Capacity, Storage, and Peaking—natural gas supply components we are required to procure on behalf of our customers.
How/when will I see the change

The impact from the change in CRP requirements will be displayed as a separate line item labeled "Change in Law 11012024,” beginning with December usage. Although the CRP changes were effective on Nov. 1, 2024, we will not be billing retroactive cost changes.
Change type/cost component, commodity impact and effective date NATURAL GAS:  Algonquin pipeline rate increase
Utility territory/region impacted New England utilities that receive all/part of their supply from Algonquin
Explanation of change Earlier in 2024, Algonquin Gas Transmission, LLC (the ownership entity of the Algonquin Pipeline), filed a transmission rate case (RP24-781)—the first one since 2019—that resulted in a rate increase. Pipeline transmission costs are a required component of natural gas supply service, and this rate increase impacts all natural gas consumption that flows through the Algonquin Pipeline—which serves all or part of most of New England’s local distribution companies (LDCs).
How/when will I see the change The impact from the Algonquin transmission rate change will be displayed as a separate line item labeled “Change in Law 12012024,” beginning with January usage. Although this increase was effective Dec. 1, 2024, we will not be billing retroactive cost changes. In addition, since this rate case is still in progress, if there is a change in rate in the future, we will provide true-up adjustments for any billed cycles where the original rate was applied.
Change type/cost component, commodity impact and effective date NATURAL GAS: increase in Peaking Demand charge
Utility territory/region impacted NY: National Grid—Niagara Mohawk (NiMo).
Explanation of change National Grid-Niagara Mohawk (NIMO), implemented its annual update of costs for its Peaking Demand charge¹ on Nov. 1, 2024, which resulted in a cost increase. The Peaking Demand charge, applicable to National Grid’s Monthly Balancing Service, is a natural gas component that we are required to purchase in order to serve our natural gas customers. As a result of this, we will be passing through this change in costs on your invoice, starting with your November 2024 usage.
How/when will I see the change You will see the impact of this Peaking Demand charge increase as a separate line item labeled "Change in Law 110124,” beginning with your first invoice with November billing dates or with your first billing cycle after service start.
¹ Source: NY Public Service Commission #219  
Change type/cost component, commodity impact and effective date NATURAL GAS: Daily Delivery Service/Core Daily Balancing program cost changes
Utility territory/region impacted NY: Consolidated Edison (ConEd), Brooklyn Union Gas (BUG), and Long Island Lighting Co. (LILCO).
Explanation of change ConEd, BUG, and LILCO each implemented its annual update of costs for its Daily Delivery Service (DDS) program/Core Daily Balancing (CDB) program, which went into effect on Nov. 1, 2024. DDS/CDB is a natural gas delivery and storage service that we are required to purchase from the local utility to serve our natural gas customers. As a result of the annual cost update, we will be passing through the change in costs on your invoice, which could be a charge or a credit, starting with your November 2024 usage.
How/when will I see the change

If you're billed by us: you will see the impact from this program cost change (a charge or credit) as a separate line item labeled "Change in Law 110124,” beginning with any usage from Nov. 1 forward. Please note that if you experienced a change in law in the past, you may have more than one change in law line item on your invoice.

If you're billed by the utility on our behalf: you will see the impact from this program cost change as an adjustment in your unit price on your utility invoice, beginning with any usage from Nov. 1 forward.
Change type/cost component, commodity impact and effective date

NATURAL GAS: ConEd peaking demand rate increase

Effective date of change: April 1, 2024
Utility territory/region impacted Consolidated Edison (ConEd)
Explanation of change

ConEd implemented out-of-cycle changes to its peaking demand rates, which are part of natural gas daily delivery service (DDS) and which we are required to purchase from ConEd to serve our natural gas customers. Normally ConEd updates these rates annually and the changes are effective November 1—and they remain in place through the winter season. These out-of-cycle rate changes resulted in a net increase over the original annual rate change that was effective in November.
How/when will I see the change

If you're billed by us: you will see the impact from this increase in demand rate as a separate line item labeled "Change in Law 04012024,” beginning with any usage from April 1 forward. Please note that if you experienced a change in law in the past, you may have more than one change in law line item on your invoice.

If you're billed by ConEd on our behalf: you will see the impact from this increase in demand rate as an adjustment in your unit price on your ConEd invoice, beginning with any usage from April 1 forward.
Change type/cost component, commodity impact and effective date

ELECTRICITY: ERCOT System Admin Fee increase

Effective date of change: Feb. 1, 2024
Utility territory/region impacted ERCOT/Texas
Explanation of change At its open meeting in November 2023, the Public Utility Commission of Texas voted to approve an increase in the Electric Reliability Council of Texas'(ERCOT’s) System Administration Fee. ERCOT manages the flow of electric power to more than 26 million Texas customers, representing about 90 percent of the state’s electric load. As a non-profit entity, ERCOT is funded by the System Administration Fee.
How/when will I see the change

This charge will appear in the prior period pass-thru section of the invoice, labeled as “TX-ERCOT Admin Fees – CIL” for any invoices that containing billing dates from Feb. 1, forward.
Change type/cost component, commodity impact and effective date NATURAL GAS: change in Capacity Release Program requirements; cost changes associated with Transportation, Capacity, Storage, and Peaking
Utility territory/region impacted New England: Berkshire Gas, Essex Gas Company, Keyspan–Boston, Fall River Gas, Eversource–NSTAR, Fitchburg Gas Company, Colonial Gas, Connecticut Natural Gas, National Grid Rhode Island, Eversource–EGMA (Baystate), Northern Utilities New Hampshire, Northern Utilities Maine, Eversource–Yankee, Southern Connecticut Gas Company, and Energy North
Explanation of change

In November, the New England utilities reset the program requirements for the annual Capacity Release Program (CRP),² which impacts the natural gas supply costs associated with Transportation, Capacity, Storage, and Peaking, which we are required to procure on behalf of our customers. Changes to the CRP parameters can increase or decrease the costs associated with procuring these components, which are assigned based on your individual usage profile. All customers, regardless of who supplies your natural gas (the utility or a retail supplier), are subject to these costs.

 

As a result of the annual update to the CRP requirements, we will be passing through the associated change in costs on your invoice starting with your February 2024 usage.
How/when will I see the change

If you're billed by us: you will see the impact from the CRP change (a charge or credit) as a separate line item labeled "Change in Law 02012024,” beginning with any billed usage from Feb. 1, forward. Please note that if you experienced a change in law/change to purchase price in the past, you may have more than one change in law line item on your invoice.

If you're billed by the utility on our behalf: you will see the impact from the CRP change (a charge or credit) as an adjustment on your utility invoice near your gas supply charges, beginning with any usage from Feb. 1, forward.

² Sample program change documentation from Berkshire Gas for reference purposes.

  
 

The following information is applicable to any service location(s) you have in the given regions denoted.

Change type/cost component, commodity impact and effective date

 ELECTRICITY: Inventoried Energy Program (IEP) added cost
Effective date of change: Dec. 1, 2023 – Feb. 29, 2024
Utility territory/region impacted New England (NEISO):  CT, MA, RI, ME, NH.
Explanation of change

Since 2018, ISO-NE has taken several steps to plan for adequate generation resources and fuel supply for those generators during the winter months to ensure reliable electricity production during periods of extreme cold weather. One such step was to create the Inventoried Energy Program (IEP) in 2019, which is similar to the Winter Reliability Program of years' past. The IEP is a temporary program that pays certain generators for maintaining energy inventories during the winters of 2023/24 and 2024/25. This—along with keeping certain generators, like Mystic, online beyond their retirement—is part of the ISO's overall fuel security planning approach. 

The costs associate with the IEP program will be passed through to customers from December to February 23/24 and 24/25.
How/when will I see the change IEP charges are passed through as part of a line item labeled "Fuel Security" for any billing dates from Dec. 1, 2023 to Feb. 29, 2024. Please note, the Mystic RMR costs, which began in June 2022 and are part of the overall ISO-NE Fuel Security Program, are also part of this line item and will continue to be passed through all year.
Change type/cost component, commodity impact and effective date NATURAL GAS: Daily Delivery Service/Core Balancing Program cost changes
Effective date of change: November 1, 2023
Utility territory/region impacted NY: Consolidated Edison (ConEd), Brooklyn Union Gas (BUG), Long Island Lighting Co. (LILCO), and Orange & Rockland (O&R).
Explanation of change

ConEd, BUG, LILCO, and O&R each implemented its annual update of costs for its Daily Delivery Service (DDS) program/Core Daily Balancing (CDB) program, which went into effect on Nov. 1, 2023. DDS/CDB is a natural gas delivery and storage service that we are required to purchase from the local utility to serve our natural gas customers. As a result of the annual cost update, we will be passing through the change in costs on your invoice, which could be a charge or a credit, starting with your November 2023 usage.
How/when will I see the change

If you're billed by us: you will see the impact from this program cost change (a charge or credit) as a separate line item labeled "Change in Law 110123,” beginning with any usage from Nov. 1 forward. Please note that if you experienced a change in law in the past, you may have more than one change in law line item on your invoice.

If you're billed by the utility on our behalf: you will see the impact from this program cost change as an adjustment in your unit price on your utility invoice, beginning with any usage from Nov. 1 forward.
Change type/cost component, commodity impact and effective date ELECTRICITY: ERCOT Contingency Response Service (ECRS) new charge
Effective date of change: June 2023 meter read
Utility territory/region impacted ERCOT/Texas
Explanation of change ERCOT Contingency Response Service (ECRS) is a new ancillary service that is procured daily and was created through Nodal Protocol Revision Request (NPRR) 863. The ERCOT Board approved it in February 2019 and for the past several years has been working toward implementing it. ECRS will complement and provide support to the other four procured ancillary services ERCOT uses and is another measure to help keep supply and demand balanced and mitigate real-time operational issues.
How/when will I see the change Beginning on your July invoice (June meter read dates) this charge will appear in the prior period pass-thru section of the invoice, labeled as “ERCOT Cont Reserve Serv (ECRS).”
 

The following information is applicable to any service location(s) you have in the given regions denoted.

Change type/cost component, commodity impact and effective date

 ELECTRICITY: Firm Fuel Supply Service (FFSS) added cost
Effective date of change: November 2022
Utility territory/region impacted ERCOT/Texas
Explanation of change

In 2021 and 2022, the Public Utility Commission of Texas (PUCT) and the Electric Reliability Council of Texas (ERCOT) approved several regulatory changes that increase or add energy supply costs in Texas, including:

 

Firm Fuel Supply Service (FFSS):This service was developed consistent with directives from the Texas Legislature and the Public Utility Commission of Texas's (PUCT's) order for ERCOT to develop and procure a firm-fuel product as part of the Commission's Phase I Market Design efforts and in response to Texas Senate Bill 3. This firm fuel supply service (FFSS) product provides additional grid reliability and resiliency during extreme cold weather and compensates generation resources that meet a higher resiliency standard. FFSS will be procured for the obligation period of November 15 through March 15 each year.
How/when will I see the change FFSS was passed through on invoices starting in December 2022 and labeled "Firm Fuel Supply Service." This charge will be applied to meter read dates from Nov. 15-March 15 on an annual basis.
Change type/cost component, commodity impact and effective date ELECTRICITY: Reliability Must Run (RMR) added cost
Effective date of change: June 1, 2022
Utility territory/region impacted New England (NEISO): CT, MA, RI, ME, NH
Explanation of change

When the owners of the Mystic Generating Station announced that they were going to retire several units in 2022, the ISO-NE, after studying and identifying the resulting adverse consequences for New England's energy security, moved to retain the Mystic units for an additional two years, in an effort to give the region time to implement reliability solutions before the units' eventual retirement in 2024.

 

As a result, all customers in New England will be subject to Reliability Must Run (RMR) charges, effective June 1, 2022, which cover the costs to keep generation units running beyond their scheduled retirement.
How/when will I see the change RMR charges were passed through as a new/separate line item labeled "Reliability Must Run", starting with August 2022 invoices.
Change type/cost component, commodity impact and effective date ELECTRICITY: ancillary services obligation increase
Effective date of change: April – June 2022
Utility territory/region impacted ERCOT/Texas
Explanation of change

In 2021 and 2022, the Public Utility Commission of Texas (PUCT) and the Electric Reliability Council of Texas (ERCOT) approved several regulatory changes that increased or added energy supply costs in Texas, including:

 

Ancillary Services obligation increase: To help ensure there is enough capacity to serve customers through periods of emergency, ERCOT significantly increased the ancillary services obligations (specifically Non-Spin Reserves) that LSEs like us must procure for our customers.

 
How/when will I see the change

The ancillary services increases were passed through as follows:

 

Ancillary Services 2022 increase started April 2022 and is labeled as "Ancillary Service Obligation Adj." on your invoice. It covers billing dates from Mar. 1, 2022 forward.

 

Ancillary Services 2021 increase started in June 2022 and is labeled "AncillaryServiceObligationAdj: 7/21-2/22" on your invoice. It covers billing dates from July 2021 thru February 2022.
Change type/cost component, commodity impact and effective date ELECTRICITY: securitization added costs and credits
Effective date of change: August – September 2022
Utility territory/region impacted ERCOT/Texas
Explanation of change

In 2021 and 2022, the Public Utility Commission of Texas (PUCT) and the Electric Reliability Council of Texas (ERCOT) approved several regulatory changes that increased or added energy supply costs in Texas, including:

 

Securitization charges: The PUCT issued Orders1 that allow ERCOT to obtain approximately $3 billion in funds to help stabilize the wholesale electricity market. ERCOT will assess these charges, which will impact load serving entities (LSEs), including retail electric providers (REPs) like NRG, who can then pass these charges on to their customers. Securitization charges are comprised of:

 

  • Default Securitization Charge2: a non-bypassable charge that is effective in January 2022.

  • Uplift Securitization Charge3: a non-bypassable charge, which will be effective in early Q2 2022.

 

Securitization credit: NRG customers (including transmission-level customers who did not opt-out) that were charged ancillary services costs over $9,000 MWh and reliability deployment price adder (RDPA) charges for usage during Winter Storm Uri, received a credit to offset those charges in an amount proportional to NRG's recovery of its exposure.

 

  • 1 Docket Nos. 52321 (Default Securitization) and 52322 (Uplift Securitization)
  • 2 PUCT Docket No. 52321
  • 3 PUCT Docket No. 52322
How/when will I see the change

The securitization charges/credit was/were passed through at different points in time during 2022 as follows:

 

Default Securitization (current): was passed thru on invoices starting in August 2022 and labeled as "Market Securitization (Debt) Financing: Default" (covers July 2022 forward)

 

 

Securitization Credit: appeared on August 2022 invoices labeled as "Market Securitization Subchapter N – Credit"

 

Uplift Securitization: was passed thru on invoices starting in September 2022 and labeled as "Market Securitization (Debt) Financing: Uplift" Note: Uplift Securitization Charges will not be assessed to transmission-voltage level ESIDs that have opted out of the uplift portion of securitization.

 

Default Securitization (back bill): was passed thru on invoices starting in November 2022 and labeled as "Market Securitization: Default 1/1/22- 6/30/22." (covers the back-billing of costs back to the effective date)
 

Frequently asked questions

Did you ever want to know a little bit more about regulatory changes and how they impact your business? The following FAQs will provide answers to the most common questions. Please refer to our listing of specific regulatory changes that have been implemented for more information on what changes may have impacted your business (i.e. service locations).

A regulatory change (sometimes called a change in law) is any law, tariff, order, rule, tax, decision, or other type of mandate passed by a regulatory body (local, regional, federal, etc.), or a change by any LDC, EDC or ISO that changes the cost to supply your electricity or natural gas. A typical regulatory change will impact the rate (either up or down) associated with a particular energy supply charge or will modify a requirement—such as adding a new, higher solar requirement to a state renewable portfolio standard, that increases or decreases the cost to comply with the standard. Sometimes a new program is put in place and the costs socialized—which can result in a new supply charge.

The most common regulatory changes occur with transmission charges. This happens in part because transmission owners are often required by the system operators under which they operate to file new rate calculations annually or bi-annually. Your transmission costs are comprised of several components and any one of those components can increase or decrease when transmission owners file updated calculations, including: network integration transmission service (NITS), regional transmission expansion plan (RTEP) and transmission enhancement charge (TEC).

 

In addition to transmission costs, renewable portfolio standard, gross receipts tax (GRT), ancillary services (in ERCOT) and demand-based charges, including, capacity and resource adequacy, are often impacted by regulatory changes.

Regulatory changes can impact anyone's business, regardless of who supplies their energy—and they can amount to an increase or decrease in charges. While we make every effort to mitigate regulatory changes that result in cost increases, language in our contracts indicates that we can pass through certain changes in the cost to serve. We are very transparent about these changes, rather than hiding them in other costs and fees. The type of product you have with us will dictate the extent that you may notice (and be notified by us of) these cost changes.

 

For example, customers that have a product that passes through their individual energy supply components at cost (i.e. their invoice has an itemized list of charges each month) will be used to seeing fluctuations in the individual charges/rates from month to month. There is really nothing new that happens when a cost component goes up or down due to a regulatory change because the charge is transparent on the invoice each month. Normally we don't send notifications of a regulatory change to customers who have this type of product.

 

Customers that have a fixed price product that wraps some/all of their retail supply charges into a single fixed price or fixed adder tend to be impacted more by regulatory changes. This is because we must provide reconciliation of the cost change—since all cost components are wrapped into the fixed price or adder—which can mean passing through the net increase or decrease in costs via a new line item or adjusting the fixed price in an amount equal to the increase/decrease. If you're reading this, you likely fall into this category and receive courtesy notifications from us when a regulatory change impacts your business. The information on this website will give you access to any changes that may impact your business. Your service location(s) will determine which regional regulatory change(s) may impact your business.

Regulatory changes will impact your account once the change/law/mandate, etc. is "effective." All regulatory matters have effective dates that guide us in terms of when we need to begin applying a regulatory change to your account.

 

How you actually see the change on your invoice will depend on who bills you for your energy supply charges. Generally speaking:

 

If you are billed by us for your electricity or natural gas supply, we will typically pass through a regulatory change as a separate line item on your invoice under your supply charge(s). For electricity, we will label the line item to match the specific cost component that is impacted by the regulatory change. For example, a regulatory change that impacts your transmission costs could be presented as: "Transmission Cost Adjustment." For natural gas, it's a little more general and we'll typically label the charge/credit resulting from a regulatory change as: "Change in Law X.XX.XX."

 

If you are billed by your local utility on our behalf for your supply charges, we will typically change your fixed rate (up or down) in an amount equal to the cost change. Sometimes (in certain utility territories), we are able to pass cost changes through as a separate line item, in which case it will be labeled according to the cost component that is impacted i.e. "Transmission Cost Adjustment."

 

Helpful terms and definitions for your business

When it comes to the regulatory side of energy supply, things can get confusing with terms and acronyms. Here are some of the most common terms you'll come across in the world of energy regulatory speak.

Ancillary Services: Charges for the services required to support and maintain reliable operation of the electric grid. These charges are based on federally-regulated tariffs.

Burnertip: A reference point (i.e. the meter at your home or business) for measuring and billing natural gas supply. If you are being served by a retail supplier for your natural gas and your agreement specifies that your gas is billed at the burnertip, the local distribution company (LDC) fuel costs associated with delivery to the burnertip will be billed by your supplier.

Capacity (unforced: UCAP or installed: ICAP): Capacity is a requirement of the independent system operators (ISOs)/regional transmission organizations (RTOs) in several electricity markets. These charges help guarantee that there will be sufficient generation to meet the maximum energy requirements of the market at all times. The costs associated with these payments are passed through to consumers either by their utility or their retail electric provider and are based in part on your peak demand during the peak demand days (as determined and measured by the ISO).

Change in Law: A change in law or regulatory change is any law, tariff, order, rule, tax, decision, or other type of mandate passed by a regulatory body (local, regional, federal, etc.) that impacts your energy supply costs.

Citygate: A reference point for measuring and billing natural gas supply. If you are being served by a retail supplier for your natural gas and your agreement specifies that your gas is billed at the citygate, you will be billed by your local distribution company (LDC) for fuel charges (see "fuel charges" below).

Congestion: An ISO/RTO charge that is brought about by the limitations of the transmission system. The costs associated with more expensive generation are translated into congestion costs from the ISO/RTO. When available lower-cost supply cannot be delivered to the demand location due to transmission limitations, higher-cost generation closer to the load must be used to meet demand.

Federal Energy Regulatory Commission (FERC): An independent agency within the Department of Energy that regulates the interstate transmission of electricity, natural gas and oil. FERC has jurisdiction over interstate electricity sales, wholesale electric rates, hydroelectric licensing, natural gas pricing, oil pipeline rates and gas pipeline certification.

Fuel charges: Fuel charges, which are part of natural gas supply service, cover the fuel that is lost through the pipeline between the local distribution company (LDC) citygate and the point of delivery (business or residence).

Independent System Operators (ISOs)/Regional Transmission Operators (RTOs): Independent, federally-regulated entities that coordinate regional electricity transmission in a non-discriminatory manner and ensure the safety and reliability of the electric systems in their regions.

Independent System Operator (ISO) Administrative Fee or Grid Management Fee: This fee funds the operations of the ISO in your service area. An ISO operates the interstate power system and coordinates statewide electricity supply.

Losses: A regulated charge that compensates the utility for electricity losses that occur between the point of generation and delivery to your business. It is based on information provided by your utility and ISO/RTO.

Reliability Must Run (RMR): RMR covers the costs for generators to keep their generation units running beyond their scheduled retirement to help maintain reliability of the grid.

Renewable Portfolio Standard (RPS): If your state mandates participation in a renewable energy program, your supplier is required to procure a portion of your power from renewable sources. RPS obligations are common in most states and many suppliers pass the charges associated with RPS compliance on to customers either as a separate charge or as part of an all-inclusive rate.

Transmission charges: are part of the basic electric service charges (regulated) that every customer must pay. These charges cover the cost to move electricity from the generation facility over the transmission lines. Transmission costs are comprised of several components, each of which can change in cost during the course of a year or contract term:

NITS: network integration transmission service

RTEP: regional transmission expansion plan

TEC: transmission enhancement charge