North Carolina stands at a pivotal juncture in its renewable energy evolution. For over a decade, the state has maintained a reputation as a solar heavyweight, consistently ranking among the top five states in the nation for total installed solar capacity. However, this statistical dominance was historically built on the back of utility‑scale projects—massive solar farms in rural counties driven by the Public Utility Regulatory Policies Act (PURPA) and the state's Renewable Energy and Energy Efficiency Portfolio Standard (REPS). The residential sector, by contrast, remained relatively dormant, constrained by low electricity rates and a lack of direct incentives compared to peer states.
In 2025, this paradigm has fundamentally shifted. The residential market is no longer a passive participant but a central focus of grid modernization efforts. The policy landscape has matured from simple generation‑based rewards to complex, behavior‑based incentive structures designed to integrate Distributed Energy Resources (DERs) into the grid's operational logic. The introduction of Duke Energy’s PowerPair pilot program, the transition to the "Solar Choice" time‑of‑use tariffs, and the persistence of the federal Investment Tax Credit (ITC) have created a sophisticated, albeit intricate, financial environment for homeowners.1
This report provides an exhaustive examination of the residential solar ecosystem in North Carolina as of late 2025. It analyzes the interplay between federal tax policy, state‑level property tax abatements, and the divergent incentive structures of investor‑owned utilities (IOUs) versus electric cooperatives. Furthermore, it explores the economic implications of the "Solar Coaster"—the rapid fill‑rates of rebate capacities—and the strategic necessity of battery storage in maximizing return on investment (ROI).
The narrative that follows is not merely a catalog of available funds but a strategic guide to the mechanics of these instruments. It elucidates how a homeowner in Duke Energy Carolinas territory faces a radically different economic calculus than one served by the Piedmont Electric Membership Corporation, and why 2025 represents a critical window of opportunity before specific "bridge" mechanisms expire or reach saturation.4
2. Federal Financial Instruments: The Bedrock of Solar Economics
While state and utility incentives provide localized variability, the Federal Residential Clean Energy Credit serves as the foundational economic driver for solar adoption across the United States, including North Carolina. Codified under Section 25D of the Internal Revenue Code, this instrument was significantly strengthened and extended by the Inflation Reduction Act (IRA) of 2022, providing a stable policy horizon through the early 2030s.7
2.1 Section 25D: The Residential Clean Energy Credit
As of the 2025 tax year, the Section 25D credit allows a taxpayer to claim a credit against their federal income tax liability equal to 30% of the qualified solar electric property expenditures. Unlike a tax deduction, which reduces taxable income, a tax credit reduces the tax owed dollar‑for‑dollar, making it the most potent financial lever available to residential investors.8
2.1.1 Eligibility and Scope
The scope of "qualified expenditures" under Section 25D is comprehensive. It encompasses the cost of the photovoltaic (PV) panels, inverters, racking systems, wiring, and—crucially—labor costs for onsite preparation, assembly, and installation. This includes permitting fees, inspection costs, and even developer fees if they are integrated into the turnkey contract price.7
For a typical North Carolina residential installation, which averages between $2.37 and $3.21 per watt, a 10‑kilowatt (kW) system might cost approximately $30,000 upfront. The 30% ITC provides a $9,000 reduction in tax liability, bringing the net cost down to $21,000 before accounting for any additional state or utility incentives.9
Table 1: Federal Solar Tax Credit Phase‑Down Schedule (Section 25D)
| Tax Year | Credit Percentage | Market Implication |
|---|---|---|
| 2022 – 2032 | 30% | Peak incentive period; drives current ROI models. |
| 2033 | 26% | Initial signal for market contraction or maturation. |
| 2034 | 22% | Final phase of subsidized residential adoption. |
| 2035 Onward | 0% | Expiration (absent new legislation). |
The stability of the 30% rate through 2032 provides long‑term certainty for the industry, allowing installation companies in North Carolina to plan workforce development and supply chains without the "boom and bust" cycles that characterized the pre‑2022 market.7
2.1.2 The Strategic Decoupling of Battery Storage
A pivotal modification introduced by the IRA and effective in 2025 is the treatment of battery storage. Previously, under older IRS guidance, battery systems were only eligible for the tax credit if they were charged exclusively (100%) by the on‑site solar panels. This created significant operational constraints, preventing homeowners from using the grid to charge batteries during off‑peak hours or for storm preparation.10
Under the current Section 25D rules, battery storage technology with a capacity of at least 3 kilowatt‑hours (kWh) is eligible for the full 30% credit, regardless of its charging source. This decoupling is a game‑changer for grid flexibility. It allows North Carolina homeowners to participate in Virtual Power Plant (VPP) programs—such as Duke Energy's PowerPair Cohort B—where the utility might charge the battery from the grid in anticipation of a peak event, without jeopardizing the homeowner's tax credit eligibility.11
2.2 Mechanics of Claiming and Carry‑Forward
The Section 25D credit is non‑refundable. This is a critical distinction for retirees or low‑income households in North Carolina who may have limited tax liability. If a homeowner generates a $9,000 tax credit but only owes $4,000 in federal taxes for the year the system was "placed in service," the IRS will not refund the remaining $5,000 in cash.7
However, the tax code allows for the carry‑forward of unused credit. The remaining $5,000 can be applied to reduce tax liability in the subsequent tax year, and theoretically for as many years as the credit remains active under the statute. This mechanism ensures that the value of the incentive is not lost, merely deferred, provided the taxpayer eventually incurs sufficient liability.7
It is important to note the definition of "placed in service." The IRS generally considers a system placed in service when it is installed and capable of producing electricity. In North Carolina, where interconnection delays with Duke Energy can be substantial, this distinction is vital. A system installed in December 2025 but not granted "Permission to Operate" (PTO) until February 2026 generally still qualifies for the 2025 tax year if installation was completed, though conservative tax interpretations often suggest waiting for PTO. However, given the multi‑year stability of the 30% rate, the distinction between a 2025 and 2026 claim is largely cash‑flow timing rather than a loss of value.8
3. State Taxation Frameworks: Exemptions and Gaps
While the federal government provides income tax relief, the State of North Carolina exerts its influence primarily through property tax statutes and the absence of sales tax incentives. The state’s approach reflects a policy of removing barriers (penalties for improvement) rather than offering direct subsidies, a philosophy that has shaped the market since the expiration of the 35% state renewable energy tax credit in 2015.12
3.1 The Property Tax Abatement (G.S. 105‑275(45))
North Carolina General Statute 105‑275(45) establishes a "special class" of property for solar energy electric systems. The statute explicitly states that 80% of the appraised value of a solar energy electric system is excluded from property tax.14
3.1.1 The Residential "100% Exemption" Nuance
On the surface, the "80% exclusion" implies that homeowners would pay taxes on 20% of their system's value. For a $30,000 system, this would mean adding $6,000 to the tax assessment, resulting in an annual tax bill increase of roughly $42 (assuming a $0.70/$100 tax rate).
However, a deeper legal reality exists for residential systems. The North Carolina Department of Revenue and county tax assessors generally classify residential solar systems—those not used for business purposes—as non‑business personal property. In North Carolina, non‑business personal property is exempt from taxation. Consequently, strictly residential systems that are not part of a commercial enterprise or a third‑party lease arrangement effectively enjoy a 100% exemption from property taxes.16
This distinction is crucial for financial modeling. If the 20% were taxable, it would represent an annual operating expense (OPEX) that degrades the system's Net Present Value (NPV). The effective 100% exemption preserves the asset's value purely as a savings generator without the tax drag.18
3.1.2 Commercial Application (80% Exclusion)
For commercial entities, businesses, or industrial applications, the 80% exclusion is applied strictly. A business installing a $100,000 system will see $20,000 added to their taxable property value. This 20% taxable basis is an important consideration for the commercial sector but serves as a massive improvement over full taxation, which would likely render many projects insolvent.19
3.1.3 The Highwater Solar Precedent: Construction in Progress
A significant legal clarification regarding this statute arose from the Highwater Solar case. The North Carolina Court of Appeals addressed whether solar equipment "under construction" on the January 1st tax assessment date qualified for the exclusion. Tax assessors argued that since the system wasn't "generating electricity," it wasn't being "used" for the exempt purpose.
The Court ruled in favor of the solar developers, establishing that construction counts as a qualifying use for the exclusion.21
While this ruling primarily protects large utility‑scale developers from massive tax bills during construction phases, it offers protection to residential projects caught in limbo. If a homeowner has pallets of panels on their roof on January 1st but is waiting for a final inspection, this precedent suggests they should not be taxed on the full value of that equipment as "inventory" or "construction in progress" without the benefit of the exclusion.21
3.2 The Sales Tax Reality
A glaring gap in North Carolina's incentive portfolio is the lack of a sales tax exemption. Unlike states such as Florida, Texas, or Arizona, which waive sales tax on solar equipment, North Carolina imposes its standard state and local sales taxes on PV components.18
- State Rate: 4.75%
- Local Rate: 2.00% – 2.75% (depending on the county)
- Total Impact: ~6.75% to 7.50%
On a $30,000 system, this adds approximately $2,025 to $2,250 to the gross cost. This "tax on a tax credit" (since the sales tax is included in the basis for the federal ITC) increases the upfront capital requirement. While the federal ITC effectively pays back 30% of this sales tax, the homeowner still bears 70% of the sales tax burden, a friction point that lowers the state's comparative competitiveness for solar investment.18
4. The Utility Landscape: Duke Energy's Incentive Ecosystem
The majority of North Carolina's residential solar market operates within the service territories of Duke Energy Carolinas (DEC) and Duke Energy Progress (DEP). In 2025, Duke Energy's relationship with residential solar has transformed from a simple net metering arrangement to a complex ecosystem of rebates, time‑variant pricing, and capacity‑limited pilots. This transition is embodied in the PowerPair program and the new Solar Choice tariffs.
4.1 The PowerPair Pilot Program: Mechanics and Urgency
Authorized by the North Carolina Utilities Commission (NCUC) in January 2024 and launched in May 2024, the PowerPair program is a pilot designed to test the efficacy of incentivizing paired solar‑plus‑storage systems. It represents a shift in utility logic: rather than discouraging solar, the utility is paying to ensure that solar is dispatchable and grid‑friendly.2
4.1.1 Rebate Structure and Value
The PowerPair program offers a one‑time, upfront incentive capable of offsetting a significant portion of the system cost. The rebate is bifurcated into solar and storage components:
- Solar Incentive: $0.36 per watt (AC), up to a maximum of 10 kW.
- Max Value: $3,600.25
- Battery Incentive: $400 per kWh of installed capacity, up to a maximum of 13.5 kWh.
- Max Value: $5,400.25
Total Potential Value: A homeowner installing a 10 kW system with a 13.5 kWh battery (e.g., a Tesla Powerwall 3) can receive $9,000 in direct rebates. This is in addition to the 30% federal tax credit, creating a "stacking" effect that radically improves the economics of hybrid systems.26
4.1.2 Cohort Analysis: Control vs. Autonomy
Participants must enroll in one of two cohorts, which determines the operational relationship between the homeowner and the utility:
- Cohort A (Passive): The homeowner receives the upfront rebate but retains full control over the battery's operation (e.g., reserving it for backup power). There are no ongoing performance requirements or utility control events.
- Cohort B (Active/Grid Services): The homeowner joins the "Battery Control" program. In exchange for the upfront rebate plus ongoing monthly bill credits, the utility (Duke Energy) gains the right to remotely dispatch the battery.
- Winter Control: Up to 18 events (Dec–March).
- Summer Control: Up to 9 events (May–Sept).
- Shoulder Months: Up to 9 events.
- Implication: During a cold winter morning peak, Duke can drain the battery to support the grid. While this enhances grid stability, it reduces the energy available to the homeowner for self‑consumption or backup during those specific windows. However, the added monthly incentive attempts to compensate for this loss of autonomy.25
4.1.3 Capacity Constraints: The "Solar Coaster"
The defining feature of the PowerPair program in 2025 is its scarcity. The NCUC approved a hard cap of 30,000 kW (30 MW) of installed solar capacity for each jurisdiction (DEC and DEP). These caps have triggered a "gold rush" mentality in the market.6
- Duke Energy Progress (DEP): Serving the eastern part of the state (Raleigh, Wilmington) and the Asheville region.
- Status: Capacity Reached. As of October 2025, the DEP allocation is fully subscribed. New applications are being placed on a waitlist. Waitlisted projects only receive funding if a reserved project cancels. For all intents and purposes, the PowerPair window for DEP has closed for 2025.6
- Duke Energy Carolinas (DEC): Serving the central and western piedmont (Charlotte, Greensboro, Durham).
- Status: Critical Urgency. Capacity is rapidly depleting. Projections indicate that DEC will reach 100% capacity by December 2025. Homeowners in this territory are in a race against time to submit interconnection requests and secure their reservation.6
This divergence has created a bifurcated market where solar economics in Charlotte are currently superior to those in Raleigh solely due to rebate availability.
4.2 The Net Metering Transition: Bridge vs. Choice
Concurrent with the PowerPair pilot is the mandatory transition away from "Legacy Net Metering." The era of simple 1:1 retail rate crediting for all exports is over for new customers. The market is now divided into two primary tariff structures: the Net Metering Bridge Rider (NMB) and the Residential Solar Choice Rider (RSC).3
4.2.1 Net Metering Bridge Rider (NMB)
The NMB was negotiated as a compromise between Duke Energy and solar installers to prevent a sudden collapse of the solar market. It serves as a transitional mechanism.
- Mechanism: It largely mimics the economic value of legacy net metering but avoids the mandatory Time‑of‑Use (TOU) complexities of the RSC. It allows homeowners to "bridge" the gap to the new rate era.
- Capacity Caps: Like PowerPair, the NMB is capacity‑limited to prevent indefinite enrollment.
- 2024 Cap: 35,900 kW AC.
- 2025 Cap: 39,500 kW AC.
- 2026 Cap: 43,500 kW AC.30
- Waitlist Dynamics: The NMB operates on a first‑come, first‑served basis. Once the annual cap is reached, new interconnecting customers are forced onto the RSC tariff until the next year's cap opens or indefinitely if the program expires. The 2025 cap is expected to fill, making the timing of interconnection applications a critical financial variable.29
4.2.2 Residential Solar Choice Rider (RSC)
The RSC represents the future default state of solar in North Carolina. It is a mandatory Time‑of‑Use (TOU) rate with Critical Peak Pricing (CPP).
- TOU Structure: Electricity is most expensive during peak demand (e.g., 6 AM–9 AM in winter, 6 PM–9 PM in summer) and cheapest during off‑peak (midday/overnight).
- Export Valuation: Unlike legacy net metering, which credited exports at the retail rate, the RSC credits excess solar generation at a variable "avoided cost" rate, which is significantly lower than the retail price of power.
- CPP Risk: During "Critical Peak" events (extreme weather), prices can skyrocket. A solar customer without a battery who draws power during a CPP event faces severe bill penalties.
- Grid Access Fee: Systems larger than 15 kW (AC) are subject to a Grid Access Fee, a monthly charge per kW of installed capacity, designed to recover infrastructure costs Duke claims are shifted to non‑solar customers.3
Strategic Implication: The RSC tariff is hostile to "solar‑only" systems because solar generates most power during the midday "off‑peak" (when export credits are low) and stops generating during the evening "peak" (when consumption costs are high). However, the RSC tariff is highly favorable for solar‑plus‑storage. A battery allows the homeowner to store the cheap midday solar and discharge it during the expensive evening peak, arbitrating the rate spread. This aligns perfectly with the PowerPair rebate, which subsidizes the battery needed to make the RSC tariff viable.27
5. The Cooperative and Municipal Landscape
While Duke Energy dominates the narrative, a significant minority of North Carolinians are served by Electric Membership Corporations (EMCs) or municipal utilities. These entities are not regulated by the NCUC in the same manner as IOUs and thus offer distinct incentive structures, often focusing on financing rather than rebates.
5.1 On‑Bill Financing and Efficiency Loans
Many cooperatives have adopted "on‑bill financing" mechanisms. This approach addresses the "split incentive" and high upfront cost barriers by allowing members to pay for efficiency and solar upgrades through a line item on their monthly electric bill.
5.1.1 Piedmont Electric Cooperative (PEMC)
Serving the rural areas north and west of the Triangle (Hillsborough, Roxboro), PEMC offers a robust Energy Efficiency and Renewable Energy Loan Program.
- Loan Limits: Increased in recent years to a maximum of $30,000.
- Terms: Repayment over up to 10 years.
- Interest Rates: Typically market‑based but competitive (often citing a floor around 4.9%–7%).
- Scope: Covers solar panels, solar water heaters, and energy efficiency upgrades (HVAC, windows).
- Mechanism: The loan is facilitated through the ElecTel Cooperative Federal Credit Union but integrated into the utility relationship.5
5.1.2 Randolph EMC
Serving the central piedmont (Asheboro area), Randolph EMC provides a similar financing product.
- Loan Limits: Up to $35,000 for standard homes (capped at $5,000 for mobile homes).
- Terms: Flexible terms with rates historically starting as low as 4.9%.
- Accessibility: This low‑interest financing is a critical enabler for rural solar adoption, where cash purchases may be less common than in affluent urban centers.34
5.1.3 Union Power Cooperative
Located in the fast‑growing counties southeast of Charlotte (Union, Cabarrus), Union Power also offers loans up to $35,000 via ElecTel. They heavily emphasize the role of "Energy Advisors" to vet projects before financing, ensuring that members are not oversold by aggressive solar sales teams—a common issue in the residential market.36
5.2 Community Solar: The "Roofless" Alternative
For members of cooperatives who cannot install rooftop solar (due to shading, rental status, or roof age), "Community Solar" offers an alternative.
- Randolph EMC (SunPath): This program allows members to subscribe to the output of a central solar array.
- Subscription Model: Members pay an upfront fee (e.g., ~$491 per panel) or a monthly subscription.
- Credit: They receive a bill credit for the energy producing by "their" panel for 20 years.
- Economics: While the ROI is generally lower than rooftop solar (due to administrative overhead), it provides access to renewable energy benefits without the liability of maintaining equipment.38
6. Market Mechanisms: The Failure of SRECs in NC
In states like New Jersey, Massachusetts, and Washington D.C., the sale of Solar Renewable Energy Certificates (SRECs) constitutes a major revenue stream for homeowners, sometimes rivaling the value of electricity savings. In North Carolina, this market is effectively non‑existent for residential systems.
6.1 The Compliance Market Reality
North Carolina's Renewable Energy and Energy Efficiency Portfolio Standard (REPS), established by Senate Bill 3 in 2007, requires utilities to source 12.5% of their energy from renewables by 2021. This policy included a "solar carve‑out" requiring 0.2% from solar.13
However, the utilities (Duke Energy) met these targets primarily through massive utility‑scale solar farms and large commercial installations. Because the supply of solar RECs from these giant projects is so high, the market price for an SREC in North Carolina has crashed to near‑zero values.
6.2 Closed Borders and Market Isolation
Historically, North Carolina solar owners could register their systems in the lucrative Washington D.C. SREC market (where prices could exceed $400/SREC). However, D.C. closed its market to new out‑of‑state systems several years ago to spur local development. Similarly, Pennsylvania and other open markets have become saturated.
- Current Status: Residential systems in North Carolina generally cannot sell SRECs into high‑value markets.
- Aggregators: While services like SRECTrade still operate, they note that for NC systems, the opportunity is minimal. The "spot price" for a North Carolina SREC is often negligible, and many homeowners simply assign the SREC rights to Duke Energy as part of the PowerPair or Net Metering agreements in exchange for the rebates/tariffs.13
6.3 NC GreenPower: A Strategic Pivot
NC GreenPower, once a program that paid small generators a premium for their power, has pivoted its model. It no longer accepts new residential solar interconnects for production incentives. Instead, it utilizes donations (the $4 block on utility bills) to fund "Solar+ Schools" grants. This shifts the focus from private residential subsidy to public educational infrastructure.41
7. Economic Analysis: ROI and Payback Periods
The convergence of high upfront costs, generous federal credits, and complex utility rebates creates a highly variable Return on Investment (ROI) landscape in 2025.
7.1 System Cost Baselines
- Average Cost: $2.37/Watt to $3.21/Watt (Installed).
- 5 kW System: ~$11,854 to $16,000.
- 10 kW System: ~$23,700 to $32,000.
- Battery Adder: ~$12,000 – $15,000 (installed).9
7.2 Scenario A: The "Ideal" Case (DEC Territory, PowerPair Secured)
Consider a homeowner in Charlotte installing a 10 kW Solar + 13.5 kWh Battery system.
- Gross Cost: $45,000 ($30k solar + $15k battery).
- Sales Tax (7%): +$3,150.
- Total Upfront: $48,150.
- Federal ITC (30%): –$14,445.
- PowerPair Rebate: –$9,000 ($3,600 solar + $5,400 battery).
- Net Cost: $24,705.
Economic Outcome: With the Net Metering Bridge rate (if capacity secured), the system saves ~$2,500/year.
- Payback Period: ~9.8 years.
- Insight: Without PowerPair, the payback would extend significantly. The rebate effectively pays for nearly 60% of the battery cost, making the resilience (backup power) extremely affordable compared to a standalone retrofit.
7.3 Scenario B: The "Late Mover" Case (DEP Territory, No Rebate)
Consider a homeowner in Raleigh installing the same system after PowerPair capacity is full.
- Gross Cost: $48,150.
- Federal ITC: –$14,445.
- Rebate: $0.
- Net Cost: $33,705.
Economic Outcome: Forced onto the RSC tariff (assuming Bridge is full), the savings rely on load shifting.
- Payback Period: ~13–14 years.
- Insight: The loss of the $9,000 rebate drastically alters the investment profile. The system is still viable for resilience and long‑term hedging against rate hikes, but the purely financial "slam dunk" is gone. This highlights the extreme cost of delay in the 2025 market.13
8. Regulatory Protections and Permitting
8.1 The Solar Access Law (G.S. 22B‑20)
While not a financial incentive, North Carolina's "Solar Access Law" is an economic enabler. It limits the ability of Homeowners Associations (HOAs) to ban solar panels.
- Provision: HOAs cannot explicitly prohibit solar panels in covenants.
- Loophole: They can restrict the location (e.g., forcing panels to the rear roof) if the restriction does not have the effect of preventing the reasonable use of the solar collector.
- Economic Impact: If an HOA forces a move from a south‑facing roof to an east‑facing roof, production drops, harming ROI. However, the law generally protects the right to install.17
8.2 Permitting Fee Caps (G.S. 160D‑1110)
To prevent local governments from gouging solar installers with high permit fees, state statute requires that permit reviews be timely.
- Refund Mechanism: If a local government takes longer than 20 days to review a residential permit, they must refund 10% of the permit fee per day of delay. This keeps "soft costs" (which make up a large chunk of solar pricing) in check, indirectly supporting the economics of installation.43
9. Future Outlook: The 2026 Cliff and Beyond
As 2025 draws to a close, the market looks toward 2026 with trepidation.
- Bridge Rate Cliff: The capacity for the Net Metering Bridge Rider increases slightly in 2026 (43.5 MW), but once the "bridge" period ends (statutorily set for 2027), the bridge closes entirely. The market will become 100% defined by the Solar Choice (RSC) tariff.
- PowerPair Uncertainty: Being a pilot, PowerPair is not guaranteed renewal. If the 30 MW caps are not expanded or the program renewed for 2026, the $9,000 incentives will vanish permanently, potentially causing a sharp contraction in the residential storage market.26
- Duke Rate Cases: Both DEC and DEP have filed rate cases requesting revenue increases to fund grid hardening and nuclear relicensing. Rising retail rates generally improve solar ROI (by making grid power more expensive to buy), but the concurrent rise in "Grid Access Fees" or basic facilities charges could offset these gains for solar users.45
Conclusion
For the North Carolina homeowner in 2025, the strategy is clear: Hesitation is expensive. The convergence of the 30% Federal ITC, the precarious availability of Duke Energy's PowerPair rebates, and the dwindling capacity of the Net Metering Bridge rate creates a unique, fleeting "golden era" for solar‑plus‑storage. Those who navigate the interconnection queue successfully in 2025 can lock in superior economics for decades; those who wait risk facing a market defined by mandatory time‑of‑use complexity and unsubsidized storage costs.
Table 2: Summary of Key Incentives and Status (Late 2025)
| Incentive | Value | Status | Urgency |
|---|---|---|---|
| Federal ITC (25D) | 30% of Gross Cost | Active (until 2032) | Low (Stable) |
| NC Property Tax Exclusion | 100% (Residential) | Active | Low (Statutory) |
| Duke PowerPair (DEC) | Up to $9,000 | Filling Fast | Critical |
| Duke PowerPair (DEP) | Up to $9,000 | Waitlisted/Full | High (Closed?) |
| Net Metering Bridge (NMB) | Avoids TOU Rates | Capped Annually | High |
| Co‑op Loans (Piedmont/Randolph) | Low Interest / On‑Bill | Active | Medium |
| SRECs | Negligible | Inactive | N/A |
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