North Jersey commercial power: choice and BGS

Three distribution systems, and why the address decides everything

Northern New Jersey is served by PSE&G, by Jersey Central Power & Light and by Rockland Electric, and the utility that serves a given street is the one whose tariff applies to it. That matters before any supply conversation starts, because delivery and demand charges are tariff-set and do not move when a supplier changes — the wires part of the bill is the same whether the account shops or not. The Board's own default-supply page names the state's electric distribution companies in one place: Atlantic City Electric, Jersey Central Power & Light, Public Service Electric and Gas, and Rockland Electric. Of those four, the first two carry most of the northern commercial load and the last serves a small northern area, so a business with properties in different towns can be dealing with more than one delivery utility without leaving the region. The settling question is not which utility serves New Jersey; it is which one serves the meter, and the utilities publish territory lookups for exactly that. Northern New Jersey's municipal map is dense, which is the second reason to check rather than assume: neighbouring towns can sit in different territories and in different programmes, and a portfolio that spans four towns may span three answers.

• The delivery utility is decided by the service address, not by the state or the county.
• Delivery and demand charges come from that utility's tariff and do not change with a supply switch.
• The Board names four EDCs statewide: ACE, JCP&L, PSE&G and Rockland Electric.
• Use the utility's own territory lookup to settle which tariff governs the meter.

Municipal aggregation: two programme types, and a 30-day opt-in

New Jersey's aggregation rules are more specific than most states' and they turn on which programme type a municipality has adopted. N.J.A.C. 14:4-6.4 governs the framework: a municipality or county may establish a stand-alone, multi-government or government-private aggregation programme, a government-private programme has to be authorised by ordinance or county resolution, and a county route depends on each participating municipality having authorised participation by ordinance. Each programme then executes an aggregation agreement with every distribution company that serves customers inside the municipality. The two government-private options are not the same product. Under Option 1, at N.J.A.C. 14:4-6.5, the notice travels to residential electric and gas customers inside the boundaries, and a notice goes to non-residential customers only if the municipality requests it — so a commercial account can sit inside an Option 1 programme's geography and hear nothing at all. Under Option 2, at N.J.A.C. 14:4-6.6, the public notice tells non-residential customers they are eligible to participate if they submit an opt-in response to the option administrator within 30 calendar days, and the rule is explicit that a customer who does not respond is not included. The practical upshot for a northern New Jersey business is that enrolment is a fact to establish, not an assumption: the notice names the option administrator, the selected supplier and the response route, and an account that never received one was either outside the geography, in a programme type that does not reach it, or opted out.

• A government-private programme needs an ordinance or county resolution, and an agreement with each LDC serving the municipality.
• Option 1 notice reaches residential customers; non-residential notice only if the municipality asks for it.
• Option 2 makes non-residential customers eligible only if they opt in within 30 calendar days.
• A programme cannot serve a municipality that already has one of its own.

What the default supply actually is, and who resets it

Businesses that never shop are supplied under Basic Generation Service, and the Board describes it as an obligation rather than a product: under the Electric Discount and Energy Competition Act of 1999 the distribution companies must obtain and provide supply for customers who do not switch to a third-party supplier, until the Board decides the obligation is no longer necessary. Two features of that description matter to a buyer. First, the power must be procured at prices consistent with market conditions, and what customers are charged is regulated by the Board and built from the reasonable and prudent cost of the service — including power purchased in the wholesale market and related capacity, ancillary and administrative costs as the Board determines. Capacity therefore sits inside the comparison, not beside it. Second, the benchmark is rebuilt on a schedule: the Board runs a proceeding each year and directs the companies, and invites other parties, to file proposals by 1 July for the supply year ahead. The Board's account of the most recent cycle is the clearest evidence of how granular the process is — orders at Docket ER24030191 and Docket ER25040190 approved the companies' joint proposals using a descending-clock auction for two thirds of the residential and small commercial requirement, took no position in those orders on the remaining third or on the commercial and industrial class, and started a further proceeding with proposals due 1 July 2026 to settle both. The classes are separate: BGS-RSCP prices residential and small commercial accounts, BGS-CIEP prices commercial and industrial ones, and a business comparing an offer against 'the utility rate' should know which of the two it is actually being compared against.

• BGS is the companies' obligation to supply customers who have not switched, under the 1999 Act.
• Charges are Board-regulated and include capacity, ancillary and administrative costs.
• The Board runs an annual proceeding with proposals filed by 1 July for the coming supply year.
• BGS-RSCP and BGS-CIEP are different classes, procured on their own schedules.

Who is allowed to sell, aggregate or advise

The Board licenses and registers the people a business will deal with, under N.J.A.C. 14:4-5, and the distinction between the two categories is worth knowing before a proposal arrives. Third-party electric and gas suppliers hold licences; energy agents, energy consultants and private aggregators hold registrations. A private aggregator registration is the one that catches people out: the rule at N.J.A.C. 14:4-5.1 provides that an entity may not combine end-user loads and arrange supply without registering as a private aggregator, with an exception for a government entity acting under the aggregation rules in N.J.A.C. 14:4-6. That is the mechanism behind a broker or a buyers' group acting for several sites. Both licencees and registrants file an annual information update within 30 days before the anniversary date of the licence or registration, with the renewal fee the rules set, and the Board publishes active licence and registration lists with anniversary dates — which makes it possible to check a counterparty rather than take a proposal's word for it. The Board also publishes the standardised contract summary format that third-party suppliers use, a consolidated-billing and purchase-of-receivables order that determines whether a supplier can bill you and buy your receivables, and the more recent statutory changes at P.L. 2019, c.100 that altered licence renewal.

• Suppliers are licensed; energy agents, consultants and private aggregators are registered.
• Combining end-user loads and arranging supply requires private aggregator registration, apart from the government exception.
• Annual information updates are filed within 30 days before the anniversary date.
• The Board publishes active lists with anniversary dates and a standardised contract summary format.

The other lever: programmes that change the load, not the commodity

Procurement answers what the kilowatt-hours cost. It does not answer how many of them the site needs, or when they are drawn, and in a dense northern market those are separate and sometimes larger questions. The state's Clean Energy Program publishes its business programmes alongside a subscriber route into community solar for premises that cannot host panels on their own roof, which is a real constraint in the northern urban and industrial corridor where roofs are small, shaded or leased. The ordering discipline is the same as anywhere else, with one local wrinkle: because the delivery tariff and the default supply are set by different bodies on different clocks, a measure that cuts consumption and a contract that reprices it show up in different parts of the bill at different times, and neither is a substitute for the other. Efficiency work changes the usage and demand the tariff is applied to; a supply contract changes the price applied to that usage. Reading a northern New Jersey bill correctly means knowing which of the two a given change will move.

• The state's Clean Energy Program publishes business programmes and a community solar subscriber route.
• Community solar suits premises that cannot host panels — common in the northern urban and industrial corridor.
• Delivery charges follow the tariff; supply follows the contract. They are set on different clocks.
• Cutting consumption and repricing supply are separate decisions, not alternatives.

What to send before quoting a northern New Jersey site

The work order for this market is short and specific. Start with twelve months of bills showing supply and delivery separately, because that history is what a supplier underwrites; on a consolidated bill the split has to be reconstructed from the tariff, which is why sending the raw bill matters. Add the delivery utility and the rate class, and interval data if the site is demand-metered, since the peak — not the annual volume — is what a demand charge is built on. Then the facts that change the answer in New Jersey specifically: whether the municipality runs an aggregation programme and of which type, whether the account was ever enrolled, whether the site is inside a municipal utility's territory rather than an investor-owned one, the building area if efficiency work is on the table, and the notice date on any contract already running. That last item sets the calendar, and in this market it is usually the binding constraint. One caveat applies to every energy page on this site and to this region in particular: 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. An enquiry places no order and switches no supplier — the account stays with its current supplier until a switch is actually completed, and the terms you are on today keep applying until then.

• Twelve months of bills with supply and delivery shown separately.
• Delivery utility, rate class, and interval data for demand-metered sites.
• Aggregation programme type and enrolment status; municipal utility territory; notice date on the current contract.
• Eligibility for competitive supply is decided by the address, the meter and the utility territory.
• HighGround may be compensated on completed purchases; an enquiry orders nothing and switches nothing.

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