Massachusetts commercial gas: DPU and winter

Six companies, five brands, three territory families

The Department of Public Utilities' annual report lists six investor-owned local distribution companies: Berkshire Gas Company; Boston Gas Company, doing business as National Grid; Eversource Gas Company of Massachusetts, formerly Bay State Gas Company and before that Columbia Gas of Massachusetts; Fitchburg Gas and Electric Light Company, doing business as Unitil; Liberty Utilities (New England Natural Gas Company) Corporation; and NSTAR Gas Company, also doing business as Eversource. Five brands, six regulated companies: Eversource holds two of them, which is the first thing that makes a Massachusetts gas portfolio harder to read than a single-utility state, because two sites under one parent can sit in different schedules with different class codes and different applicability tests. National Grid adds a second layer, because its commercial classes are written per territory - Boston Gas proper, the former Essex customers, and the former Colonial Gas customers - and all three still appear in the current rate material under one company. The operating company and the territory letter on the bill govern the account; the parent brand does not. Geographically, Boston Gas covers the metropolitan core, Eversource serves central and eastern Massachusetts through NSTAR Gas and the former Columbia Gas territory, Berkshire Gas the west, Liberty the southeast around Fall River, and Fitchburg the north-central area.

• The Department lists six investor-owned LDCs under five brands.
• Eversource holds two: NSTAR Gas and Eversource Gas Company of Massachusetts, formerly Columbia Gas of Massachusetts.
• National Grid is Boston Gas Company, and bills former Essex and Colonial territory under its own classes.
• The operating company and territory letter on the bill govern the account, not the parent brand.

The G-class ladder: three territories, two different tests

Commercial and industrial classes all begin with G, and the class on the bill is set by the operating company's own schedule. Within National Grid's Massachusetts gas territory the schedules are not uniform, and the difference that matters is the test that decides the class. For Boston Gas classes - G-41B through G-54B - the deciding measure is maximum hourly meter capacity rather than annual volume: small is 500 cubic feet per hour or less, medium runs from 501 to 1,500, large from 1,501 to 12,000, and extra large is anything above 12,000. The low-load-factor and high-load-factor families mirror those four sizes, so G-41B to G-44B are the low-load-factor classes and G-51B to G-54B the high-load-factor ones, with low load defined as 70 per cent or more of twelve-month consumption falling between November and April. The former Essex territory, still billed under E-suffixed classes, uses annual therms instead: up to 22,000 therms for G-41E, 22,001 to 100,000 for G-42E and more than 100,000 for G-43E, with the high-load-factor family at 45,000 and 180,000 and a low-load line of 73 per cent. Former Colonial territory uses annual therms at 20,000 and 100,000 on both families, with its low-load line at 72 per cent. The practical consequence is that a Boston Gas site cannot infer its class from a therm count and a Colonial-territory site cannot infer it from meter capacity; the applicability language in the schedule decides, and the bill already states which class is being applied.

• Boston Gas classes G-41B to G-54B key on maximum hourly meter capacity.
• Boston capacity bands: 500 cubic feet per hour or less, 501 to 1,500, 1,501 to 12,000, above 12,000.
• Former Essex classes key on annual therms at 22,000 and 100,000, high-load-factor lines at 45,000 and 180,000.
• Former Colonial classes key on annual therms at 20,000 and 100,000.
• The low-load line is 70 per cent of November-to-April consumption in Boston, 73 in Essex and 72 in Colonial territory.

Transportation: buying your own commodity

A commercial site that qualifies can move onto transportation service, taking its gas commodity from a competitive marketer while the distributor keeps delivering through its mains. The utility continues to read the meter, maintain the service, respond to leaks and balance the system, and the account stays on its delivery class; only the commodity changes hands. Eligibility is not uniform. A tariff may key transportation to an annual therm level, a maximum hourly meter capacity, a load factor, or a combination, and it generally also requires a transportation service agreement with the distributor, a qualified supplier, and daily or monthly nomination and balancing obligations. Because the tests differ by company and class, the first step is always to identify which class the delivery bill is already on. On the bill itself, a transportation account still carries the distributor's delivery charges and the local distribution adjustment; what leaves the utility's own supply is the commodity line, which the marketer's contract replaces.

• Transportation moves only the commodity; the distributor still delivers and balances.
• The account keeps its delivery class while a marketer supplies the gas.
• Eligibility may key on annual therms, hourly meter capacity or load factor.
• A transportation agreement, a qualified supplier and nomination duties are typical conditions.

Supply and delivery on the bill: GAF and LDAF

A Massachusetts gas bill separates the commodity from the delivery service through two filed mechanisms. The Department of Public Utilities names them as clauses: the Cost of Gas Adjustment Clause, which recovers what the company paid for gas supply, and the Local Distribution Adjustment Clause, which recovers distribution-related costs that are deliberately left out of base rates. The factors that appear on the bill - the gas adjustment factor and the Local Distribution Adjustment Factor, or LDAF - are the arithmetic that follows from those filings. The cadence is worth knowing because it explains why the supply line moves and the delivery line does not: gas adjustment filings are semi-annual, reflecting the seasonal swing in the market price of gas, and the Department reviews them for accounting accuracy and prudent practice before approving new factors effective 1 May and 1 November. The Department also requires interim filings when projected collections of gas supply costs move by more than five per cent, which is why a mid-season bill can change without any change to the contract. The LDAF works on a fully reconciling basis, recovering things such as energy efficiency programmes and gas system enhancement investment, and because it reconciles, an over- or under-collection is trued up rather than kept. For a buyer the structure is the point: the supply factor tracks a cost the company passes through, the LDAF tracks distribution programmes, and neither is a distribution margin the company negotiates with you.

• The Department's clause names are the Cost of Gas Adjustment Clause and the Local Distribution Adjustment Clause.
• Bills show the resulting gas adjustment factor and the LDAF.
• Gas adjustment filings are semi-annual, with factors effective 1 May and 1 November.
• Interim filings follow when projected supply-cost collections move by more than five per cent.
• The LDAF reconciles fully, so over- and under-collections are trued up.

Licensing: the marketer must be on the DPU list

Selling competitive gas supply in Massachusetts requires certification by the Department of Public Utilities, which annually certifies the suppliers and agents that sell competitive supply to utility customers. That certification is separate from the customer's contract: signing a supply agreement does not itself establish that the counterparty is authorised to enrol customers at a given distributor. Before signing, a business should confirm the marketer appears on the department's current list, check the legal entity named in the contract, and establish whether the counterparty is acting as principal supplier, broker or agent, because that determines where its obligations sit if the supply goes wrong. The distributor can also be asked whether that marketer is authorised to enrol on its system.

• The department certifies competitive gas suppliers and agents annually.
• Certification is separate from the supply contract and must be checked independently.
• Establish whether the counterparty is a principal, broker or agent.
• Ask the distributor whether the marketer may enrol accounts on its system.

Why winter costs more: pipelines and LNG

New England has limited pipeline connectivity to the producing regions, and its principal routes are the Algonquin Gas Transmission and Tennessee Gas Pipeline systems. In cold weather those pipelines can run near their maximum, and ISO New England has said that during extended cold the region may need LNG injected into the system to meet both heating demand and gas-fired generation. The Everett LNG terminal in Boston Harbor connects to both of those pipeline systems, and imported LNG matters at the margin: the Energy Information Administration reports that on peak-demand days it can contribute as much as 35 per cent of New England's gas supply. In 2024 the department approved long-term seasonal contracts running to May 2030 with National Grid, Eversource and Unitil to keep winter supply flowing from Everett. The result is a pronounced winter premium that is an infrastructure constraint, not a pricing preference. The concentration is extreme: almost all LNG imported into the United States arrives through New England, and almost all of it between November and March, which is why the peak-day share lands in the coldest weeks rather than across the year.

• New England's principal pipeline routes are Algonquin Gas Transmission and Tennessee Gas Pipeline.
• ISO-NE says the pipelines run near maximum in winter and LNG injections are needed.
• The Everett LNG terminal in Boston Harbor feeds both pipeline systems.
• EIA: imported LNG can contribute up to 35 per cent of the region's gas on peak-demand days.
• Seasonal contracts with National Grid, Eversource and Unitil run to May 2030.

Aggregation is electric only

Massachusetts writes municipal aggregation around electricity. General Laws chapter 164, section 134 lets a municipality aggregate the electric load of customers within its borders and submit a plan to the Department of Public Utilities for approval, and the department maintains the list of approved programmes. There is no comparable statewide municipal gas aggregation. A business in a town with a community-choice electric programme therefore faces two different situations in the same building: the electricity supply may already have been procured for it, while the gas account is untouched and remains either the distributor's default supply or the business's own contract with a certified marketer.

• Municipal aggregation in Massachusetts is an electric mechanism under G.L. c. 164, s. 134.
• There is no equivalent statewide municipal gas aggregation programme.
• A town's electric programme does not reach the gas account.
• Gas supply is either the distributor's default or the business's own contract.

What to gather before a Massachusetts gas quote

A Massachusetts gas request starts with the same few documents: twelve months of consumption in therms by month, the account and meter numbers, the service address, and the distributor as the meter shows it - because the operating name, not the brand, sets the tariff. Add the current agreement's end date and the notice period required to leave it, and a statement of whether the site is already on transportation or on the distributor's default supply. One eligibility caveat applies to every energy page on this site: competitive supply depends on the service address, the meter and the utility territory, and municipal utilities, cooperatives and some jurisdictions have no choice at all. HighGround may receive compensation from providers on completed purchases, and an inquiry places no order and switches no supplier.

• Twelve months of therms by month, the account and meter numbers, and the service address.
• The distributor as the meter shows it, including the legacy operating name.
• The current agreement's end date and the notice period required to leave it.
• Whether the site is on transportation or the distributor's default supply.
• Submitting an inquiry places no order and switches no supplier.

Who holds the pipeline capacity on a transportation account

A Massachusetts transportation customer buys the commodity but does not contract for interstate pipeline capacity itself. The local distribution company holds the firm capacity on Algonquin Gas Transmission and Tennessee Gas Pipeline, together with the upstream transportation, storage and peaking resources that make up its supply portfolio, and it makes that capacity available to marketers through its tariffed transportation service and its capacity pool rather than requiring each customer to acquire pipeline capacity separately. A marketer's Department of Public Utilities licence is not itself a capacity right: the licence authorises retail supply, while the capacity has to come through the distributor's tariffed arrangement, a capacity release, or another permitted route. The allocation a marketer receives tracks its assigned load and the distributor's operating constraints rather than being unlimited, and the distributor's own long-term supply contracts, which combine the commodity with the capacity to move it, are filed with the department for review when they run longer than a year under General Laws chapter 164, section 94A. The practical consequence for a commercial buyer is that the question is not only what the commodity price is but how the marketer is serving the winter load behind it.

• The distributor, not the customer, holds the firm capacity on Algonquin and Tennessee.
• Capacity reaches a marketer through the distributor's tariffed pool or a capacity release.
• A DPU licence authorises retail supply but is not itself a pipeline capacity right.
• Marketer allocations track assigned load and the distributor's operating limits.
• Distributor supply contracts over one year are filed for review under G.L. c. 164, s. 94A.
• Ask how the marketer serves winter load, not only what the commodity price is.

What a transportation account owes in winter

Winter changes the obligations more than it changes the arithmetic. Distributors tighten nomination, balancing and daily-delivery requirements, and a marketer's capacity allocation is driven by peak-month or peak-day requirements by customer class rather than by annual average use, so a site whose draw is steady across the summer but spiky in January can end up under-allocated if the estimate behind the contract was built on an annual therm figure. Storage, peaking and supplemental supply do more of the work, and failing to deliver gas the account has nominated can trigger imbalance charges, operational-flow-order charges or curtailment under the tariff. Distributors also retain limited recall rights over capacity when system reliability requires it. For a buyer the point is that a transportation contract is an operating obligation as well as a purchase: the marketer has to be able to nominate the account's winter load, not merely quote a price for it. A site whose January draw is far above its annual average should ask how its capacity was sized before it compares offers.

• Winter tightens nomination, balancing and daily-delivery requirements.
• Capacity is driven by peak-month or peak-day need by class, not annual average use.
• A draw that is steady in summer can still be under-allocated for January.
• Storage, peaking and supplemental supply carry more of the winter load.
• Imbalance, operational-flow-order and curtailment provisions apply when deliveries miss.
• Distributors keep limited recall rights over capacity for system reliability.

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