How Net Metering Works in South Carolina

Net metering in South Carolina is utility- and tariff-specific, not one statewide exchange rate. Before trusting a solar savings estimate, identify the legal utility name on a current bill, the base rate and solar rider the new system would use, and any customer cohort attached to an existing system. Then model when the home uses electricity, when solar is consumed on site, and when electricity crosses the meter.

That distinction matters in 2026. A new Dominion Energy South Carolina residential system generally enters Solar Choice with a time-of-use rate. A new Duke customer needs the permanent Residential Solar Choice structure for either Duke Energy Carolinas or Duke Energy Progress—not a blended “Duke” assumption. Santee Cooper retail uses hourly net billing under its distributed-generation rider. Each electric cooperative can set different terms.

Start with the bill, not the city

Do not identify a South Carolina electric utility from a city, ZIP code, county, or neighbor’s solar proposal. Service territories can meet or overlap within the same broader market. A cooperative member also does not become a Santee Cooper retail customer simply because Santee Cooper supplies electricity to that cooperative at wholesale.

Use a recent electric bill to record:

• the full legal utility name;
• the base rate or schedule;
• every rider shown on the account;
• whether the account already uses time-of-use billing;
• the meter or service-point identifier; and
• for an existing solar system, the original interconnection application date, approved capacity, and current solar rider.

The South Carolina utility guide can help you understand the major providers, but the bill and the utility’s account record control. Dominion Energy South Carolina, Duke Energy Carolinas, and Duke Energy Progress are separate regulated utilities. Santee Cooper has its own retail rates. Berkeley Electric, Palmetto Electric, Edisto Electric, Horry Electric, and other cooperatives are not interchangeable.

Net metering, net billing, and self-consumption are different

Solar proposals often collapse three different transactions into one annual “solar offsets usage” number. Separate them before comparing quotes.

Bill event	What happens	What to verify
Behind-the-meter use	Solar serves a home load before electricity crosses the utility meter	How much solar and load occur at the same time
Tariff netting	Imports and exports offset according to the rider’s measurement period	Instantaneous, hourly, TOU-period, monthly, or another interval
Residual export	Electricity left after the tariff’s netting step receives a credit	Current cents per kWh, TOU treatment, eligibility, and effective date
Credit carryforward	An unused credit or energy balance moves to another bill	Whether it moves as kWh or dollars and what it can offset
True-up or reset	Remaining credits receive a final treatment on a defined date	Payout method, value, reset date, and whether the balance expires

“One-to-one” or “full-retail” net metering generally means an eligible exported kilowatt-hour can offset a purchased kilowatt-hour at the applicable retail energy value under the tariff. It does not necessarily remove customer charges, minimum charges, taxes, non-bypassable riders, demand charges, or grid-access fees.

Net billing separates the value of imported electricity from the value of residual exported electricity. Santee Cooper’s current rider is a clear example: it calculates imports and exports within each hour, then charges positive hourly net use and credits negative hourly net use at different values.

Solar Choice tariffs can contain both netting and a lower residual export credit. That is why labeling a program only “net metering” or “net billing” is less useful than reading the actual calculation.

South Carolina solar billing at a glance in August 2026

The table below is a navigation aid, not a substitute for the live tariff. Rates and charges are dated because utilities and regulators can revise them.

Provider on the retail bill	Typical path for a new residential application	Netting and excess treatment	Important limits and charges
Dominion Energy South Carolina	Solar Choice rider with Rate 5 TOU	Tracks on-, off-, and super-off-peak energy; carries eligible excess forward; remaining excess is paid at avoided cost and reset in November	Up to 20 kW AC; $13.50 minimum bill in the tariff effective July 2026; interconnection and additional facility costs can apply
Duke Energy Carolinas	Rider RSC with Schedule R-STOU	Nets imports and exports monthly within TOU periods; remaining net excess receives the rider’s monthly credit	Up to 20 kW AC; nameplate-based non-bypassable charge; R-STOU minimum calculation; grid-access fee above the stated system threshold
Duke Energy Progress	Its own Rider RSC / R-STOU path	Similar Solar Choice architecture, but DEP has separate tariff leaves, rates, riders, and transition notices	Do not copy DEC rates; confirm DEP base schedule, credit, minimum, riders, and interconnection terms
Santee Cooper retail	Distributed Generation Rider DG-25	Nets within each hour; positive hourly net usage is charged and negative hourly net usage receives the export credit	Residential system limited to the lesser of 20 kW or estimated maximum monthly demand; $10 DG rider customer charge plus applicable charges; application and approval required
Electric cooperative or municipal utility	Provider-specific policy	Varies by provider; may use a surplus rider, net-metering rider, avoided-cost credit, or no standard retail export option	Provider-specific sizing, capacity, fees, insurance, equipment, meter, and approval rules

The immediate buying lesson is simple: an annual production estimate cannot establish bill impact on its own. The model needs the correct tariff and the timing of load and generation.

Existing systems may belong to a different customer cohort

An older system can have different treatment from a new system at the same address. The original application date, tariff history, change of ownership, expansion, or equipment modification can matter.

The South Carolina Office of Regulatory Staff’s Energy Freedom Act summary describes the main statutory sequence for regulated utilities:

Original application timing	General statutory milestone	What the owner should do in 2026
Before May 16, 2019	Full-retail treatment ran through December 31, 2025 under the applicable legacy framework	Read the utility’s transition notice and current account rider; do not assume the old treatment continued unchanged
May 16, 2019 through May 31, 2021	Eligible customers may retain statutory treatment through May 31, 2029	Preserve the original application and rider records; verify the consequence of a sale, expansion, or account change
June 1 through December 31, 2021	Interim Solar Choice riders applied	Confirm the interim rider’s sunset and transition options with the specific utility
January 1, 2022 onward	Permanent Solar Choice tariffs applied at regulated utilities	Use the current utility-specific rider and base rate, not a legacy net-metering summary

This table is not a promise that a particular account qualifies. For example, Dominion reported to the PSC in February 2026 that its NEM 2.0 rider had terminated on December 31, 2025 while NEM 3.0 customers remained. Duke established Net Metering Transition riders with limited election windows for qualifying legacy and interim customers.

If you are buying a home with solar, request the interconnection agreement, permission-to-operate notice, original application date, approved capacity, current bills, and every utility transition letter. If you plan to enlarge an existing array or add equipment, obtain the utility’s written treatment before signing a construction contract. Do not assume grandfathered terms transfer or survive a modification.

Dominion Energy South Carolina Solar Choice

Dominion’s current Residential Solar Choice rider applies with Rate 5 Time-of-Use Residential Service to qualifying residential customer-generators who applied on or after June 1, 2021. The version reviewed for this guide is effective for bills rendered on and after the first July 2026 billing cycle.

How the energy calculation works

The rider separates on-peak, off-peak, and super-off-peak energy. Within a monthly bill, excess in each period first reduces usage according to the rider. Remaining excess can move to lower-priced TOU periods in descending price order during that bill. A subsequent remaining energy balance carries to a future month.

During the November billing cycle, unused accumulated excess is paid at Dominion’s avoided cost—the off-peak winter energy credit in Rate PR-1—and the accumulated excess-energy account resets. That is materially different from saying every export receives full retail value indefinitely.

The rider also states a $13.50 monthly minimum bill as of the July 2026 effective date. Credits do not erase the basic facilities charge. Current prices and TOU periods come from Rate 5 and related riders, so a proposal should identify the tariff version used rather than present one evergreen “Dominion rate.”

Eligibility, meters, and interconnection

Residential generating capacity under this rider may not exceed 20 kW AC. The system must be intended primarily to offset the customer’s own requirements, comply with applicable standards, and complete Dominion’s interconnection application and agreement.

The tariff calls for a generation meter that measures output and a bidirectional billing meter configured for time-of-use measurement. It also permits customer responsibility for certain additional transformer or utility-facility costs when the utility determines they are required.

Use Dominion’s solar technical resources to retrieve the current rider, Rate 5 schedule, metering diagrams, equipment requirements, and generator-interconnection documents. Our Dominion Energy South Carolina solar guide adds local project context, but the live utility documents govern.

What a Dominion proposal should show

• The confirmed Solar Choice and Rate 5 assumptions.
• Production and household usage by TOU period, not only annual totals.
• The amount expected to be consumed on site, carried forward, and left at the November true-up.
• The current minimum bill and other unavoidable charges.
• System AC capacity and how it stays within eligibility rules.
• Who submits interconnection, supplies the required meter socket, handles corrections, and pays a utility-upgrade cost if one is identified.

A system that produces the same annual energy as the home consumes can still leave a utility bill. Timing, minimum charges, rider components, and annual true-up treatment explain why.

Duke Energy Carolinas and Duke Energy Progress are separate

“Duke Energy” is not precise enough for a South Carolina solar model. Duke Energy Carolinas and Duke Energy Progress have separate tariffs and service territories. A proposal must name the legal utility on the bill and cite that utility’s current rider.

Duke Energy Carolinas Residential Solar Choice

The current Duke Energy Carolinas Rider RSC, effective January 1, 2026, places participating residential customers on Schedule R-STOU. It permits systems up to 20 kW AC.

Under the rider, electricity supplied by Duke and electricity delivered by the customer-generator are netted monthly within each TOU pricing period. Critical-peak exports are netted against on-peak imports under the tariff’s specified rule. Remaining net excess energy in a TOU period receives a monthly credit rather than becoming a full-retail bank for later seasons.

As of the January 1, 2026 rider, that Duke Energy Carolinas net-excess credit is $0.0419 per kWh. This dated figure is not a statewide Duke rate and should be refreshed when a proposal is prepared.

Rider RSC includes a non-bypassable charge based on system nameplate capacity. The Duke Energy Carolinas Schedule R-STOU effective August 1, 2026 also contains:

• a minimum customer-and-distribution charge calculation that brings specified components to $30 when they otherwise total less;
• a $5.86 monthly grid-access fee per kW above 15 kW for systems larger than 15 kW; and
• separate TOU prices and other applicable riders.

The $30 item is a minimum calculation, not an automatic extra $30 stacked on every bill. Likewise, a grid-access fee does not apply to every system: the current schedule applies it only above its defined capacity threshold. A credible quote calculates these provisions as written.

Duke Energy Carolinas also requires compliant interconnection and a bidirectional meter. Its RSC tariff conveys system environmental attributes to the company, so a proposal should not represent renewable energy certificates as a homeowner asset without reconciling that tariff provision.

Duke Energy Progress and transition accounts

Duke Energy Progress has its own tariffs. The current DEP Renewable Net Metering Rider filing confirms that legacy RNM closed to new participants on June 1, 2021. It identifies the December 31, 2025 sunset for pre-May 16, 2019 applications and the May 31, 2029 sunset for later eligible legacy applications.

The PSC-approved Duke Net Metering Transition tariff filing created an alternative transition path for qualifying DEC and DEP legacy or interim customers. The election window runs from six months before through 12 months after the applicable transition start date, and service can continue for up to ten years from that date before transfer to the permanent RSC path.

That transition tariff is not available to a brand-new 2026 solar applicant simply because it sounds more favorable. Eligibility follows the original system cohort and utility notice.

For a new DEP project, retrieve DEP’s current RSC rider, R-STOU schedule, net-excess credit, minimum-charge provisions, non-bypassable riders, and interconnection requirements. Do not copy Duke Energy Carolinas’ $0.0419 credit or its entire bill structure into a DEP model.

Our Duke Energy solar guide for South Carolina is a starting point. The decision document should still name either Duke Energy Carolinas or Duke Energy Progress.

Santee Cooper retail uses hourly net billing

Santee Cooper says directly that it does not offer one-to-one net metering. Its current DG-25 Distributed Generation Rider, effective April 1, 2025 and still listed in August 2026, performs a calculation within each hour.

For each hour, metered customer generation delivered to Santee Cooper is subtracted from energy delivered to the customer. Hours with positive net usage are summed and charged under the applicable rate. Hours with negative net usage are summed and credited at the DG rider’s export value.

As of this review, DG-25 states:

• a $0.0415 per kWh energy credit, subject to adjustment at least annually;
• an additional $10 monthly residential customer charge under the DG rider;
• residential capacity limited to the lesser of 20 kW or estimated maximum monthly demand; and
• a minimum that includes the applicable rate-schedule customer charge, the DG rider charge, and any applicable demand charges.

If the monthly calculation produces a net credit, Santee Cooper issues a check when the amount is at least $50. A credit below $50 is applied to the next billing month. That dollar carryforward should not be described as retail kilowatt-hour banking.

Santee Cooper’s EmpowerSolar information lists a $100 nonrefundable interconnection fee in the current process. DG-25 is first-come, first-served and available only with Santee Cooper approval. The system must meet the utility’s interconnection standard, insurance requirements, and any required distribution upgrades.

The Santee Cooper generator-interconnection page provides the request, completion certificate, and terms for certified inverter-based rooftop systems up to 20 kW. Installation and local inspection are not, by themselves, permission to operate in parallel with the grid.

Read our Santee Cooper solar guide for related project questions. Apply this section only if the retail bill names Santee Cooper.

South Carolina electric cooperatives set their own terms

South Carolina cooperatives are member-owned utilities with provider-specific rates and interconnection policies. There is no “SC co-op buyback rate.” Two current examples show why.

Berkeley Electric Cooperative

Berkeley Electric’s renewable-energy page says new residential and small-business solar installations use its Renewable Generation Surplus rate. As of August 10, 2026, the page states:

• residential eligibility up to 20 kW AC, subject to a usage-based sizing formula;
• a 6.03-cent-per-kWh surplus credit, updated around March 1 each year;
• availability only on specified non-demand, non-time-of-day rates;
• a $150 interconnection application fee and possible additional inspection fees; and
• no energization until Berkeley Electric installs the bidirectional meter.

Berkeley’s page also requires the interconnection application before installation and lists drawings, insurance, contract information, inspection, and disconnect/meter steps. See our Berkeley Electric Cooperative solar guide for the local project path.

Palmetto Electric Cooperative

Palmetto Electric’s published Net Metering Rider for Residential and Commercial Rates uses its own eligibility and capacity provisions. The rider limits residential capacity to the lesser of estimated maximum annual demand or 20 kW and describes first-come availability within a 0.2% aggregate-cap provision.

These examples do not establish the terms for Edisto Electric, Horry Electric, Blue Ridge Electric, York Electric, or another cooperative. Ask the cooperative serving the meter for its current:

1. base rate and distributed-generation rider;
2. netting interval and export-credit value;
3. program capacity and application availability;
4. system-sizing limit;
5. application, study, meter, inspection, and upgrade fees;
6. insurance and equipment requirements;
7. credit carryforward and true-up terms; and
8. written permission-to-operate process.

If the cooperative cannot confirm an export option, model a non-export or self-consumption design only after it confirms the interconnection configuration it will allow. A battery or export-control setting does not automatically waive utility review.

Model a solar bill in the correct order

A useful model does not multiply annual solar production by one retail rate. Build it in this sequence.

1. Use interval data when the tariff is time-sensitive

Hourly utility data is preferable for hourly net billing. Fifteen-minute or hourly data can also improve TOU analysis. If only monthly totals are available, label the result as a coarser estimate and do not invent a self-consumption percentage.

2. Simulate solar production by interval

Use the proposed DC array size, inverter limits, orientation, tilt, shade, weather source, and system losses. Keep production modeling separate from bill modeling so a reviewer can challenge either assumption.

3. Serve the home’s load first

Within each interval, the smaller of load and available solar is behind-the-meter self-consumption. Remaining load is a grid import. Remaining solar is a grid export, subject to the utility’s rules.

4. Apply the tariff’s netting step

Group imports and exports exactly as the rider directs: by hour for Santee Cooper DG-25, by monthly TOU period for Duke RSC, or by Dominion’s Solar Choice ordering and carryforward rules. Do not convert everything into one annual bucket.

5. Apply residual export credits and resets

Use the dated export rate and the rider’s treatment of unused balances. A monthly cash credit, a carried kilowatt-hour balance, and a November avoided-cost payout are not equivalent.

6. Add costs solar does not avoid

Include the applicable basic customer charge, minimum calculation, rider fee, non-bypassable charge, grid-access fee, taxes, demand charges, and any other current tariff component. Show which items can and cannot be offset by solar credits.

7. Test at least three cases

• expected production and current usage;
• lower production or higher evening usage; and
• a future load change such as an EV, heat pump, pool, addition, or reduced occupancy.

The result is still an estimate. Weather, household behavior, outages, equipment availability, rate changes, and utility decisions can change actual bills.

A battery changes timing, not the utility rules

A battery may store midday solar for evening loads, provide selected backup during an outage, or respond to TOU prices. It does not create energy, eliminate conversion losses, make savings certain, or change the tariff by itself.

Compare solar-only and solar-plus-storage using the same roof design and load data. For the battery case, include:

• usable capacity rather than only nameplate capacity;
• continuous and surge output relative to the planned loads;
• round-trip and standby losses;
• reserve settings for outage backup;
• charge-source and export controls required by the rider;
• degradation and warranty throughput or cycle terms;
• installed battery and electrical scope; and
• any utility program obligation or dispatch right.

If the homeowner’s primary goal is outage resilience, define essential loads and target duration before discussing economics. If the primary goal is TOU shifting or export reduction, interval data and the current tariff should demonstrate the opportunity. Our battery-storage service guide explains the separate backup-sizing decision.

Avoid a circular sales argument: a weaker export credit does not automatically prove that an expensive battery pays for itself. It only increases the value of carefully examining self-consumption and storage.

Interconnection is separate from permitting and installation

A local electrical permit, passed inspection, and completed rooftop installation do not necessarily authorize parallel operation. The serving utility controls interconnection to its distribution system.

A typical project can involve:

1. confirming the account, tariff path, and system-size eligibility;
2. submitting an application, equipment data, site plan, and one-line electrical diagram;
3. completing any utility screening or study;
4. accepting identified meter, transformer, protection, or distribution-upgrade terms;
5. obtaining local permits and constructing the approved design;
6. completing local inspection and submitting the utility’s completion documents;
7. receiving or installing the required bidirectional or production metering; and
8. receiving written authorization before normal parallel operation.

The order and forms vary. Do not let an installer promise a universal approval time or tell you interconnection is unnecessary because a battery is included. Ask the serving utility in writing if a non-export configuration changes its application requirements.

Sunburst’s residential solar installation process includes utility-interconnection coordination, but the utility makes its own technical and tariff decisions.

Audit a solar proposal before you sign

Use this checklist for every proposal, including ours.

Utility and tariff

• Does the proposal name the exact utility shown on the bill?
• Does it name the base schedule, solar rider, and customer cohort?
• Is each changing rate dated and linked to the official source?
• Does it distinguish self-consumption, tariff netting, and residual exports?
• Does it show credit carryforward, true-up, and reset rules?

Bill model

• Does the analysis preserve hourly or TOU timing where the tariff requires it?
• Are current basic, minimum, non-bypassable, grid-access, rider, demand, and tax items included?
• Are annual escalation assumptions visible and optional?
• Can you see a lower-production or load-change case?
• Is the projected result labeled as an estimate with clear limitations?

Design and interconnection

• Is system size shown in both DC and AC where relevant?
• Does the design stay within the rider’s capacity and usage limits?
• Are module, inverter, battery, export-control, and metering configurations specified?
• Who submits each utility document and answers correction requests?
• Who pays application, study, meter, inspection, transformer, or upgrade costs?
• Does the schedule distinguish installation completion from permission to operate?

Existing solar

• Has the installer reviewed the original application and interconnection agreement?
• Could expansion, ownership transfer, inverter replacement, or battery addition change the rider?
• Has the utility confirmed the treatment in writing?

For a broader contract comparison, use the solar quote comparison worksheet. If you want the same utility-first review applied to your property, request a solar assessment for your bill and address. We can compare a solar-only and storage case while keeping production, credits, approval, and savings as estimates rather than certain outcomes.

When to proceed, investigate, or wait

Proceed to detailed design when the utility and tariff are confirmed, the roof or site is workable, the system fits the interconnection rules, the bill model preserves timing, and the cash or financing terms still make sense under a conservative case.

Investigate further when:

• the system already has legacy or interim net-metering status;
• the property is being bought or sold;
• an expansion or inverter change is planned;
• the model uses a city to assign a utility;
• a cooperative rider has a capacity limit or discretionary availability;
• a large system approaches a grid-access or sizing threshold;
• utility upgrades are unknown; or
• the battery model lacks interval usage and operating assumptions.

Wait when the provider or applicable rider cannot be verified, interconnection availability is unresolved, the proposal assumes an expired program, the installer will not disclose the tariff math, the roof needs a near-term replacement, or the project only works under one optimistic production or rate scenario.

“Wait” does not mean solar can never fit. It means the decision lacks a verified input that materially changes the economics or permission to operate.

How Sunburst applies utility rules to your design

Sunburst designs to the rules of the provider on your bill. That means confirming the tariff and program that applies to your account, sizing the array against the export treatment rather than against a generic offset target, filing the interconnection application ourselves, and tracking permission to operate as a separate milestone from the electrical inspection.

Statewide summaries — including ours — go stale as programs change, so we verify the current terms at design time for Dominion Energy South Carolina, Duke Energy, Santee Cooper or your cooperative before a proposal is issued. Where a battery is involved, the timing benefit is modeled separately from the utility rules, because storage changes when you use energy rather than how the utility credits it.

Read next: system sizing, comparing quotes and payback arithmetic. See our net metering guide, residential solar service, solar installers by city, or how export credits land on a bill in Columbia versus Fort Mill. Book a free assessment to have yours confirmed against the meter.

Frequently asked questions

Is one-to-one net metering still available for a new South Carolina home?

Do not assume it is. New residential customers of the major regulated utilities generally enter permanent Solar Choice tariffs, while Santee Cooper retail and cooperatives use their own structures. Some existing regulated-utility systems have cohort-specific treatment. Confirm the account, original application date if applicable, and live tariff.

What is the South Carolina solar buyback rate?

There is no statewide buyback rate. Dominion’s residual treatment, Duke Energy Carolinas’ monthly RSC credit, Duke Energy Progress’ current credit, Santee Cooper’s DG-25 credit, and cooperative surplus rates differ. Each can change. The netting interval and charges matter alongside the cents-per-kWh figure.

Do solar credits roll over from month to month?

Sometimes, but in different forms. Dominion Solar Choice can carry an excess-energy balance before its November true-up. Santee Cooper carries a net dollar credit below its check threshold. Duke permanent RSC values monthly net excess under its rider. Read the exact utility and cohort tariff before using “rollover” in a financial model.

Does net metering eliminate the electric bill?

No universal rule makes that possible. Customer charges, minimum calculations, riders, taxes, grid-access fees, demand charges, and unoffset imported energy can remain. A system that matches annual consumption can still import during higher-value periods and export during lower-value periods.

Does a battery avoid interconnection requirements?

Not automatically. A battery-backed or zero-export design still connects electrical equipment at the premises and must follow the serving utility’s applicable rules. Obtain the utility’s written requirements for the proposed configuration before installation.

Does adding a battery always improve solar savings?

No. A battery can shift energy and provide backup, but installed cost, efficiency losses, usable capacity, control settings, degradation, warranty, load timing, and the tariff determine the financial result. Compare identical solar-only and battery cases with interval data.

Can I oversize solar and sell the extra electricity?

Residential riders generally limit system capacity and tie eligibility to the customer’s needs. Dominion and Duke permanent residential riders cap eligible capacity at 20 kW AC; Santee Cooper uses the lesser of 20 kW or estimated maximum monthly demand; cooperatives can impose different usage formulas and program caps. Interconnection approval is required.

Does grandfathered net metering transfer when a house is sold?

Do not assume it does. The new owner may need a new or amended interconnection agreement, and the utility can apply current transfer and tariff rules. Review the original application, utility agreement, current rider, capacity, and written transfer instructions before closing.

Who regulates net metering in South Carolina?

The South Carolina Public Service Commission regulates investor-owned utilities including Dominion Energy South Carolina, Duke Energy Carolinas, and Duke Energy Progress. Santee Cooper, electric cooperatives, and municipal utilities have different governance and tariff processes. State law supplies a framework but does not create identical retail terms for every provider.

Sources and methodology

This guide was researched and reviewed on August 10, 2026. We checked the live Sunburst sitemap and canonical article, South Carolina law and regulatory guidance, then the current utility tariffs and interconnection materials. The core sources were:

• S.C. Code Title 58, Chapter 40 and the ORS Energy Freedom Act overview for the regulated-utility framework and application cohorts.
• Dominion’s July 2026 Residential Solar Choice rider, solar technical resources, and 2026 NEM annual report.
• Duke Energy Carolinas’ January 2026 Rider RSC, August 2026 Schedule R-STOU, and the PSC Solar Choice docket and transition record.
• Duke Energy Progress’ 2026 Renewable Net Metering filing and the DEC/DEP Net Metering Transition filing.
• Santee Cooper’s DG-25 rider, EmpowerSolar program, and generator-interconnection materials.
• Berkeley Electric’s renewable-energy and interconnection page and Palmetto Electric’s published net-metering rider as examples of why cooperative rules must be checked provider by provider.

Tariffs, credits, base rates, rider charges, capacity availability, and interconnection procedures can change. Recheck the named utility’s current documents and account-specific eligibility before signing a contract or relying on a projection.