How much does commercial solar installation cost?

Commercial solar installation cost runs from about $3.6 per watt for the smallest systems to $1.9 per watt above 1,000 kW, before incentives, using 2025 median prices from Lawrence Berkeley National Laboratory.¹ A 300 kW system at the $2.3 median works out to about $690,000.¹ Maryland’s median above 100 kW is $1.9 per watt.²

Your own price will turn on the roof, the electrical service and the federal credit timeline. The figures below are public market data, each dated and sourced. None is a Soleil Energy price.

Cost per watt by system size

Bigger systems cost less per watt. Berkeley Lab (the national lab that tracks installed prices) reports 2025 medians that fall from $3.6 for systems of 10 kW or less to $1.9 above 1,000 kW, before incentives.¹ The spread inside any one size band is wide, so a median is a midpoint, and your own quote can land well above or below it.¹

Median installed price, 2025 dollars per watt DC

• 10 kW or less$3.6
• 10 to 20 kW$3.1
• 20 to 50 kW$3.0
• 50 to 100 kW$2.8
• 100 to 250 kW$2.6
• 250 to 500 kW$2.3
• 500 to 1,000 kW$2.1
• Above 1,000 kW$1.9

View the data as a table

System size (DC)	Median installed price, 2025 dollars per watt DC
10 kW or less	$3.6
10 to 20 kW	$3.1
20 to 50 kW	$3.0
50 to 100 kW	$2.8
100 to 250 kW	$2.6
250 to 500 kW	$2.3
500 to 1,000 kW	$2.1
Above 1,000 kW	$1.9

These are medians of reported prices for host-owned, stand-alone systems, not quotes.¹ Berkeley Lab’s non-residential group covers any roof-mounted system and ground-mounted systems up to 7,000 kW.¹ Watch the units. Sizes here are direct current (DC), the panel rating; alternating current (AC) is the inverter rating. The two differ, so a quote should state both.

Where does Maryland sit on large-system prices?

On Berkeley Lab’s 2025 chart, Maryland’s median for non-residential systems above 100 kW is $1.9 per watt, the lowest of the eight states shown.² The chart has no Maryland median for systems of 100 kW or less, and a state median can rest on few projects.²

Median, large non-residential systems, 2025 dollars per watt DC

• Maryland$1.9
• Texas$2.0
• Wisconsin$2.0
• Arizona$2.3
• New Jersey$2.4
• New York$2.4
• Massachusetts$2.5
• California$2.6

View the data as a table

State	Median, large non-residential systems, 2025 dollars per watt DC
Maryland	$1.9
Texas	$2.0
Wisconsin	$2.0
Arizona	$2.3
New Jersey	$2.4
New York	$2.4
Massachusetts	$2.5
California	$2.6

Treat the Maryland figure as a low-end reference. The report doesn’t say how many Maryland systems were rooftop and how many were ground-mounted.² Berkeley Lab charts a state only once it has 20 price records for the group, which is why Maryland has no median at 100 kW or less.² A small building should use the national bands above. Nationally, the 2025 medians were $3.1 per watt for small and $2.4 for large non-residential systems, close to 2024.² One quirk: the state chart’s dotted national line sits below those national medians and the report doesn’t say why, so compare Maryland with the other states on that chart.²

What moves the price of a commercial project?

Panels and inverters are the smaller part of the bill. Berkeley Lab puts soft costs and other balance-of-system costs at roughly 80 percent of installed price, using 2025 medians.⁴ It counts customer acquisition, installation labor, permitting and interconnection, taxes and profit as soft costs.⁴

To see how the pieces stack up, the National Laboratory of the Rockies (NLR, formerly the National Renewable Energy Laboratory, or NREL) models one benchmark commercial system. Its 2024 version is a 3 MW ground mount, with costs in 2024 dollars per watt DC:⁵

2024 dollars per watt DC. Segment width is proportional to the value.

• Module$0.35
• Inverter$0.06
• Balance of system (BOS)$0.37
• Labor$0.36
• Soft costs$0.42

Total stated by the report: $1.55

View the data as a table

Cost line (NLR's labels)	2024 dollars per watt DC
Module	$0.35
Inverter	$0.06
Balance of system (BOS)	$0.37
Labor	$0.36
Soft costs	$0.42
Total stated by the report	$1.55

The rows are rounded, so they don’t add exactly to the stated total, and the report doesn’t itemize what sits inside BOS or soft costs.⁵ The two sources also slice costs differently. Berkeley Lab subtracts module and inverter price indices from prices people actually paid, while NLR models a single benchmark system.^4,5 Don’t mix the two sets of numbers in one calculation.

Six things move your own number the most:

• Mounting. NLR switched its commercial benchmark from a rooftop to a ground mount in 2023 and says that raised structural balance-of-system costs.⁵
• Roof condition. If the roof needs work first, that work gets its own line instead of being folded into the solar price.
• Electrical service and interconnection. Your utility decides which studies and equipment upgrades your site needs, and those costs can sit outside a per-watt price. Our guide to commercial solar interconnection walks through the process.
• Permitting time. Berkeley Lab found permits took longer for non-residential projects than residential ones, and longer again above 100 kW.⁶
• Storage. Pairing a battery raised median prices by $2.0 per watt of solar for small non-residential systems and $1.3 for large ones in 2025.⁷ About 80 percent of the paired-system price data comes from California.⁷
• Upkeep. NLR’s 2024 Annual Technology Baseline carries commercial solar upkeep at about $19 per kW DC a year for 2023 (about $21 for the 2022 base year), with a plausible range of $0 to $40.⁸

A lower price per watt can hide a narrower scope. Say two proposals arrive for the same roof. One lists a lower price per watt but leaves out the electrical service upgrade, the roof repair and the utility’s interconnection charges. The other bundles them. Until you put the exclusions side by side, the cheaper-looking number tells you little.

Which federal tax track is your project on?

The federal clean electricity investment credit (Section 48E) still covers commercial solar, but the deadline you face depends on when construction began. As of October 25, 2026, a commercial project is on one of two tracks, and storage follows its own rule.⁹

July 4, 2026 is behind us. If you have no documented start by that date, plan on the later-start track and the December 31, 2027 deadline.

Your tax adviser will handle most of what follows, but it helps to know what’s in it.

Proving a construction start is the open question. On June 6, 2026, a federal district court vacated IRS Notice 2025-42, which had dropped the 5 percent cost test as a way to show construction began, keeping it only for solar of 1.5 MW AC or less.¹⁸ A September 4, 2026 law-firm briefing says developers can now revisit how they document a start, which matters most for projects that met the 5 percent test by July 4, 2026, and that new IRS guidance is still possible.¹⁹ It also says the government’s 60-day appeal window ended August 5, 2026, though it could still ask for an extension.¹⁹ CourtListener’s public mirror of the docket, which may be incomplete, listed no filing after June 6 when read on October 25, 2026.²⁰ Under the law’s effective-date clause, the in-service cutoff applies to a facility whose construction begins after July 4, 2026, so a tax adviser should confirm which side of that line a project sits on.⁹

Size matters too. If your system is under 1 MW AC, the statute’s 30 percent rate applies on size alone, and the statute measures size in alternating current, not the panels’ direct-current rating.¹² At 1 MW AC or more, ask whether the contractor will meet the wage and apprenticeship rules.¹² How the credit and depreciation work together is a job for your tax adviser, so the example in the next section leaves depreciation out. Our guide to the commercial solar tax credit deadline goes deeper on the cutoff.

How long does it take to recover the cost?

Look at the right-hand column. If your demand charges are big and your solar mostly cuts the energy part, the credit can be the difference between a project that recovers its cost and one that doesn’t.

Does solar cut a commercial demand charge?

Not much, unless your output lines up with your peak. Solar lowers the energy charge on a bill. The demand charge is billed on your single highest power draw in a month, and a cloudy afternoon or a late-day peak can leave it untouched.

A Berkeley Lab and NLR modeling study found a median 7 percent cut in billing demand from solar alone under a basic demand charge.²⁵ That assumed a system making half of a building’s annual electricity, and in about 90 percent of cases the cut was under 15 percent.²⁵ Solar paired with storage saved more than the two did separately in almost all cases.²⁵ The study modeled 15 commercial building types in 15 U.S. cities, Baltimore among them, so treat it as a pattern across buildings; your own bill may differ.²⁵ For more, read how demand charges work with solar and batteries.

Before you read any quote, check your own bill:

1. Find the energy charge (per kWh) and the demand charge (per kW) on a recent bill, and see what share each is.
2. Ask your utility for 12 months of interval data.
3. Note when your peak happens. Solar helps only if peaks fall when the sun is up.
4. Ask each installer to model your tariff and interval data, not the average price.

Which Maryland rules change what a system saves?

Maryland net metering, the credit for power your system sends to the grid, covers businesses as well as homes. Maryland law caps a net-metered system at 2 MW, with exceptions, and utilities must offer the tariff first-come, first-served until the earlier of 3,000 MW statewide or July 1, 2027.²⁶

A customer qualifies if it owns and operates, leases and operates, or contracts with a third party that owns and operates a generating facility on its premises or contiguous property, intended mainly to offset its own use.²⁶ So a leased or third-party-owned system can fit the definition, which is why the ownership line in a quote matters.

A successor program is scheduled, and the calendar is short.

1. 1October 13, 2026Latest comments filed in the Maryland Public Service Commission's net metering rulemaking, docket RM 56, which shows no final rule
2. 2October 27, 2026The PSC's net energy metering successor working group is scheduled to file its draft report and framework; check PSC docket PC 78 for the filed version
3. 3December 15, 2026PSC report on the successor proceeding due to the Governor and General Assembly
4. 4February 1, 2027PSC must approve a successor framework
5. 5July 1, 2027Successor program to begin; existing program closes to new entrants if the 3,000 MW cap isn't reached first

Maryland’s 2026 Utility RELIEF Act (House Bill 1532, approved May 12, 2026) sets those dates. It states the legislature’s intent as incentives lower than the existing program’s, and it leaves the export credit to the PSC.²⁶ So ask any installer which program and which credit rate its savings estimate assumes. More detail is in our guide to what replaces Maryland net metering.

The rulemaking shows why not to plan around one rule. The PSC’s proposed regulations in docket RM 56 list three competing versions of what counts as entering the existing program: an interconnection application, an executed interconnection agreement, or permission to operate, each by July 1, 2027.²⁷ They also cap system size at 200 percent of baseline annual usage.²⁷ As of October 25, 2026, the docket shows comments continuing into October and no final rule.

Other local rules also change the savings:

• Utility tariff. Your utility’s tariff sets what solar saves. Pepco’s Maryland tariff, for example, makes Schedule MGT LV II available to customers whose maximum 30-minute demand is 25 kW or more and under 1,000 kW (or whose monthly use passes stated kWh levels).²⁹ It bills a customer charge, a distribution charge per kWh and a charge per kW of monthly demand, with power supply billed separately.²⁹ Pepco revises those rates on a published schedule, so read your current bill and the current tariff. BGE, SMECO and other utilities have their own commercial tariffs.
• Permits. The permit office for your building’s county or city sets the steps, timing and fees.
• Property tax. The Maryland Tax-Property Article says solar energy property, defined as equipment installed to use solar energy to generate electricity for a structure or the grid (or provide hot water for a structure), is not subject to real property tax, except as section 8-240 provides. Section 8-240 sets how a solar or geothermal heating and cooling system is assessed.³⁰ Ask your tax adviser how this applies to your building.
• Storage rebate. The Maryland Energy Administration’s energy storage rebate program is open to commercial and nonprofit applicants. The fiscal year 2027 window runs until 3:00 p.m. Eastern on May 31, 2027, or sooner if funds run out, and a reservation is required before installation. MEA anticipates up to $4 million for the year.³¹ Read the program announcement on that page for amounts and eligibility rules.
• Grants and financing. Grants and property-assessed financing can change the net cost. Our guide to Maryland commercial solar grants and C-PACE covers the options; confirm eligibility with each program’s administrator.

Commercial electricity prices also rose over the past year. EIA’s August 2026 averages were higher than August 2025 in all three places below, though one month is a thin base for a trend.²² An average spreads fixed and demand charges over every kWh, so it overstates what the next kWh of solar saves.

• Commercial average, August 2026 (cents per kWh)
• August 2025 (cents per kWh)

• Maryland17.0015.06
• District of Columbia23.3120.65
• Virginia11.149.85

View the data as a table

State	Commercial average, August 2026 (cents per kWh)	August 2025 (cents per kWh)
Maryland	17.00	15.06
District of Columbia	23.31	20.65
Virginia	11.14	9.85

What should a commercial quote include?

A usable quote states system size in kW DC and kW AC, price per watt, what is excluded, how production was estimated, the tariff used for savings, and the tax assumptions. If you get only a total price or a savings claim, ask for the missing lines before you compare it with another.

1. System size in kW DC and kW AC, and the module and inverter models.
2. Price per watt DC and the total, with exclusions listed: roof repair, electrical service upgrades, utility interconnection fees, permit fees.
3. The production estimate method, labeled as an estimate, with tilt and shading assumptions.
4. Savings built from your tariff and interval data, with energy and demand charges shown separately.
5. The credit assumption: which rate, the construction start date, the placed-in-service date, and foreign-entity sourcing documents.
6. Who owns the system and who claims the tax benefits. With a lease or third-party owner, ask who holds the credit and how savings reach you.
7. Monitoring and maintenance terms.
8. The schedule, including the shutdown windows you can offer for the electrical tie-in. A grid-tied system also shuts down during a utility outage by design.

Working with Soleil Energy

Soleil Energy designs, engineers, sources and builds solar for homes, businesses and utilities. For a commercial project, the work starts with an assessment of your site and your load, and the assessment is free with no obligation.

1. Assess: study the site and the load.
2. Design: engineering, drawings, permits and buying. You see the plan and what it involves before work starts.
3. Build: install, inspect and switch on, working around the outage windows you can give.
4. Support: after handover, monitoring, maintenance and service, including systems other firms installed. See solar monitoring and maintenance.

If a roof needs work before panels go on, Soleil Energy’s construction division also does commercial roofing and exterior work.

Where does commercial solar not fit?

Commercial solar fits poorly when your peak demand comes after sunset, when the roof needs major work first, or when the project can’t be placed in service by December 31, 2027 after a construction start later than July 4, 2026.^9,25

Size and site matter too. Maryland’s 2 MW net-metering cap limits how large a system can be and still earn net-metering credit, with exceptions.²⁶ A ground mount needs open land and a clear run to the electrical service, and a tenant needs the building owner’s agreement before anything goes on the roof.

Where should you start with your own project?

The prices above are national and state medians, so a Maryland quote for your roof can differ. Credit rules and the net metering cutoff are still moving; confirm each with your tax adviser and the PSC before you commit. Start with 12 months of bills, a description of the roof or land, and your interval data.

Tell us the building, the roof or land, and your recent bills. Request a proposal for a commercial solar project or call (301) 953-4140. On the form, choose Rooftop solar or Ground-mount solar as the project type.

Solar savings and incentive eligibility depend on your roof, your usage, your utility, and your tax situation. Incentive programs change and some have limited funding. We are not tax advisors — we will review your bill with you and tell you what you may qualify for. Confirm any tax credit with a qualified tax professional.

Program rules decide who qualifies. Ask any installer whether it is on the program’s contractor list.

Sources (31)

1. Lawrence Berkeley National Laboratory, “U.S. Distributed Solar and Storage 2026 Data Update” (August 2026), slide 36, non-residential installed price by system size, 2025 installs. https://eta-publications.lbl.gov/sites/default/files/2026-08/distributed_solar_storage-2026_data_update_final.pdf (published August 2026; read October 24, 2026) ↩ ↩² ↩³ ↩⁴ ↩⁵ ↩⁶ ↩⁷ ↩⁸ ↩⁹ ↩¹⁰ ↩¹¹ ↩¹² ↩¹³ ↩¹⁴ ↩¹⁵ ↩¹⁶

2. Lawrence Berkeley National Laboratory, same report (August 2026), slides 8 and 37, national and state median non-residential prices, 2025 installs. https://eta-publications.lbl.gov/sites/default/files/2026-08/distributed_solar_storage-2026_data_update_final.pdf (published August 2026; read October 24, 2026) ↩ ↩² ↩³ ↩⁴ ↩⁵ ↩⁶ ↩⁷ ↩⁸ ↩⁹ ↩¹⁰ ↩¹¹ ↩¹² ↩¹³ ↩¹⁴ ↩¹⁵

3. Illustrative calculation, run October 2026, with the inputs sourced at ¹, ¹², ⁸, ²², ²¹, ²⁴ and ²³. ↩ ↩² ↩³

4. Lawrence Berkeley National Laboratory, same report (August 2026), slide 35, underlying cost trends. https://eta-publications.lbl.gov/sites/default/files/2026-08/distributed_solar_storage-2026_data_update_final.pdf (published August 2026; read October 24, 2026) ↩ ↩² ↩³

5. National Laboratory of the Rockies (NLR; formerly NREL), “Documenting 15 Years of Reductions in U.S. Solar PV System Costs,” NREL/TP-7A40-92536 (January 2025), Table A-4 and cost discussion. https://docs.nlr.gov/docs/fy25osti/92536.pdf (published January 2025; read October 24, 2026) ↩ ↩² ↩³ ↩⁴ ↩⁵ ↩⁶ ↩⁷ ↩⁸ ↩⁹ ↩¹⁰

6. Lawrence Berkeley National Laboratory, same report (August 2026), slide 12, permitting timelines. https://eta-publications.lbl.gov/sites/default/files/2026-08/distributed_solar_storage-2026_data_update_final.pdf (published August 2026; read October 24, 2026) ↩

7. Lawrence Berkeley National Laboratory, same report (August 2026), slide 9, paired PV plus storage installed prices. https://eta-publications.lbl.gov/sites/default/files/2026-08/distributed_solar_storage-2026_data_update_final.pdf (published August 2026; read October 24, 2026) ↩ ↩²

8. NLR, Annual Technology Baseline 2024, commercial PV, fixed operations and maintenance (2024 edition). https://atb.nlr.gov/electricity/2024/commercial_pv (read October 24, 2026) ↩ ↩² ↩³

9. Public Law 119-21, section 70513(a) (adding 26 USC 48E(e)(4)) and section 70513(g)(5), enacted July 4, 2025. https://www.govinfo.gov/content/pkg/PLAW-119publ21/pdf/PLAW-119publ21.pdf (enacted July 4, 2025; read October 25, 2026) ↩ ↩² ↩³ ↩⁴ ↩⁵ ↩⁶

10. IRS, Internal Revenue Bulletin 2024-34, preamble to T.D. 9998: taxpayers may rely on the continuity safe harbor for sections 30C, 45V, 45Y and 48E “provided the facility is placed in service no more than four calendar years after the calendar year during which construction began.” IRS Notice 2025-42, which restated the safe harbor, was vacated on June 6, 2026. https://www.irs.gov/irb/2024-34_IRB (published August 19, 2024; read October 25, 2026) ↩

11. IRS, Instructions for Form 3468 (2025), “What’s New” (termination of the credit for wind or solar facilities placed in service after 2027 where the beginning of construction is after July 4, 2026). https://www.irs.gov/instructions/i3468 (page last reviewed August 28, 2026; read October 25, 2026) ↩ ↩²

12. Cornell Law School Legal Information Institute, 26 USC 48E(a)(2) (“less than 1 megawatt (as measured in alternating current)”), and IRS, Clean Electricity Investment Credit (page reviewed January 5, 2026). https://www.law.cornell.edu/uscode/text/26/48E and https://www.irs.gov/credits-deductions/clean-electricity-investment-credit (read October 25, 2026) ↩ ↩² ↩³ ↩⁴ ↩⁵

13. Electronic Code of Federal Regulations, 26 CFR 1.48E-2(b)(2) (placed in service, qualified facility). https://www.ecfr.gov/current/title-26/part-1/section-1.48E-2 (current text; read October 25, 2026) ↩

14. IRS, “Treasury, IRS provide guidance for certain energy tax credits regarding material assistance provided by prohibited foreign entities,” Notice 2026-15, IR-2026-23 (February 12, 2026). https://www.irs.gov/newsroom/treasury-irs-provide-guidance-for-certain-energy-tax-credits-regarding-material-assistance-provided-by-prohibited-foreign-entities-under-the-one-big-beautiful-bill (published February 12, 2026; read October 25, 2026) ↩

15. IRS, Notice 2026-15, sections 1 and 4 (interim guidance on material assistance from a prohibited foreign entity; the IRS intends to issue more comprehensive proposed regulations and guidance). https://www.irs.gov/pub/irs-drop/n-26-15.pdf (issued February 12, 2026; read October 25, 2026) ↩

16. IRS, Instructions for Form 4562 (2025). https://www.irs.gov/instructions/i4562 (page last reviewed April 30, 2026; read October 25, 2026) ↩

17. IRS, Elective pay and transferability (page updated June 27, 2026). https://www.irs.gov/credits-deductions/elective-pay-and-transferability (read October 25, 2026) ↩

18. U.S. District Court for D.C., Oregon Environmental Council v. IRS, Memorandum Opinion (June 6, 2026), describing Notice 2025-42 sections 3.01 and 6.02 (five percent safe harbor limited to solar of 1.5 MW or less). https://storage.courtlistener.com/recap/gov.uscourts.dcd.287847/gov.uscourts.dcd.287847.50.0.pdf (dated June 6, 2026; read October 25, 2026) ↩

19. Clifford Chance, “Wind and solar projects in the US: the vacatur of Notice 2025-42” (law-firm briefing, September 4, 2026), including the government’s appeal-window dates. https://www.cliffordchance.com/content/dam/cliffordchance/briefings/2026/09/IRS%20Notice%202025-42%20Appeal%20Deadline%20Nears.pdf (published September 4, 2026; read October 25, 2026) ↩ ↩²

20. CourtListener, docket for Oregon Environmental Council v. Internal Revenue Service, No. 1:25-cv-04400 (D.D.C.), a public mirror of the court record that may be incomplete; case terminated June 8, 2026, last known filing June 6, 2026. https://www.courtlistener.com/docket/72054098/oregon-environmental-council-v-internal-revenue-service/ (read October 25, 2026) ↩

21. NLR, PVWatts Calculator (version 8.5.0), model estimate for 38.9907, -77.0261 (Silver Spring, Maryland), 1 kW DC, fixed roof mount, 20 degree tilt, south facing, 14 percent losses, run October 2026 (saved model output). https://pvwatts.nlr.gov/ (read October 24, 2026) ↩ ↩²

22. U.S. Energy Information Administration, Electric Power Monthly, Table 5.6.A, data for August 2026 (released October 23, 2026; next release November 24, 2026). https://www.eia.gov/electricity/monthly/epm_table_grapher.php?t=epmt_5_6_a (read October 25, 2026) ↩ ↩² ↩³ ↩⁴ ↩⁵ ↩⁶

23. NREL (now NLR), “Identifying Potential Markets for Behind-the-Meter Battery Energy Storage: A Survey of U.S. Demand Charges,” NREL/BR-6A20-68963 (August 2017), published with Clean Energy Group. https://www.cleanegroup.org/wp-content/uploads/NREL_BatteryStorage_2017.pdf (published August 2017; read October 24, 2026) ↩ ↩²

24. Jordan and Kurtz, “Photovoltaic Degradation Rates: An Analytical Review,” NREL/JA-5200-51664 (2012): median 0.5 percent a year and mean 0.8 percent a year across published rates. https://docs.nlr.gov/docs/fy12osti/51664.pdf (published 2012; read October 24, 2026) ↩ ↩²

25. Darghouth et al., “Demand charge savings from solar PV and energy storage,” Energy Policy 146 (2020) 111766, Lawrence Berkeley National Laboratory and NREL (now NLR). https://docs.nlr.gov/docs/fy20osti/77798.pdf (published August 25, 2020; read October 24, 2026) ↩ ↩² ↩³ ↩⁴ ↩⁵

26. Maryland General Assembly, Public Utilities Article 7-306 (the 2 megawatt limit) and House Bill 1532 (2026, Chapter 353, Utility RELIEF Act; bill status “Approved by the Governor - Chapter 353,” May 12, 2026): section 7-306(d)(1) (earlier of 3,000 megawatts or July 1, 2027), new section 7-306.4(b) and (c) (successor framework by February 1, 2027, to begin July 1, 2027), and Section 9(c) (PSC report due December 15, 2026). https://mgaleg.maryland.gov/mgawebsite/Laws/StatuteText?article=gpu&section=7-306&enactments=false, https://mgaleg.maryland.gov/2026RS/Chapters_noln/CH_353_hb1532e.pdf and https://mgaleg.maryland.gov/mgawebsite/Legislation/Details/hb1532?ys=2026RS (enacted May 12, 2026; read October 25, 2026) ↩ ↩² ↩³ ↩⁴ ↩⁵ ↩⁶ ↩⁷

27. Maryland Public Service Commission, proposed revisions to COMAR 20.50.10 (net energy metering) and 20.62, Administrative Docket RM 56 (proposed regulations posted June 2026; latest docket entry October 13, 2026). The docket is titled for community solar but the proposal text includes the net energy metering sections. https://psc.maryland.gov/wp-content/uploads/2026/06/Proposed-Regulations-RM-56.pdf and https://webpscxb.pscmaryland.com/DMS/rm/rm56 (read October 25, 2026) ↩ ↩² ↩³

28. Maryland Public Service Commission, Notice Convening a Public Conference, Administrative Docket PC 78 (May 14, 2026): NEM Successor Working Group to file a draft report and framework by October 27, 2026. https://psc.maryland.gov/wp-content/uploads/2026/05/Notice_Convening-a-PC-PC-78.pdf (published May 14, 2026; read October 25, 2026) ↩

29. Pepco, Maryland electric tariff, Electric–P.S.C. Md. No. 1, Schedule “MGT LV II” (page issued August 14, 2026; tariff cover shows the current update effective October 1, 2026). https://www.pepco.com/cdn/assets/v3/assets/bltbb7c204688a1a6a8/blte8a580e4cc79e2c4/6abad89015d5b7d18eb100f3/9232_AND_9761_Pepco_MD_CURRENT_CLEAN_Admin_Ch_.pdf?branch=prod_alias (current tariff; read October 25, 2026) ↩ ↩²

30. Maryland General Assembly, Tax-Property Article 7-242 and 8-240. https://mgaleg.maryland.gov/mgawebsite/Laws/StatuteText?article=gtp&section=7-242&enactments=false and https://mgaleg.maryland.gov/mgawebsite/Laws/StatuteText?article=gtp&section=8-240&enactments=false (read October 25, 2026) ↩

31. Maryland Energy Administration, Residential and Commercial Energy Storage Program page, fiscal year 2027 (current page; budget table last updated October 19, 2026). https://energy.maryland.gov/Pages/Energy-Storage-Grant-Program.aspx (read October 25, 2026) ↩