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Commercial solar interconnection: utility approval guide

Written by the Soleil Energy Corp Team Last updated Editorial guidelines

Padmount transformer and metering cabinet beside a parking lot at sunrise.

Commercial solar interconnection starts with the serving utility’s review of the proposed connection, the export controls and the equipment. A commercial label alone doesn’t set the review level. Building permits, utility permission to operate and any wholesale-market participation are separate decisions. Confirm the review track before you commit to equipment or an operating date.123

Written for building owners, this guide focuses on Maryland. Dominion’s Virginia process appears for comparison only, and each utility sets its own requirements for the actual account and connection.

Does a commercial label change the review level?

Not by itself. Output, export arrangement and connection equipment drive the level. Baltimore Gas and Electric Company (BGE) says some small industrial and commercial generator applications may fall under Level 1, so business use alone doesn’t decide it, though larger or exporting systems can still need more engineering review.2

Three things to sort out before the first application:

  • Both ratings. Get the array’s direct-current rating and the inverter’s alternating-current (AC) rating on paper. The utility will tell you which one drives its review threshold. Maryland’s regulations measure nameplate capacity at the point of common coupling, where the generating equipment meets the utility system.4
  • Service voltage. The building’s service voltage and the circuit it connects to can change the review. BGE, for example, studies projects above 1,350 kilowatts AC on 13-kilovolt circuits under Level 4.5 Have the project engineer check the service configuration against the utility’s requirements.
  • The building permit. It lives on its own checklist. Montgomery County’s Department of Permitting Services, for example, publishes separate electrical permit and inspection information.6 The authority that covers your property decides which permits and inspections a commercial project needs.

What are Maryland’s four review levels?

Maryland’s rules sort projects into four review levels by capacity, equipment, circuit type and whether the system exports power. Level 1 is the simplest. Level 3 is for systems that don’t export. Level 4 means detailed utility studies. Get the utility’s level assignment and the rule version it applied in writing.7

The levels below come from the Code of Maryland Regulations (COMAR), section 20.50.09.08, as the State’s regulations library publishes it. The library shows the chapter as last amended effective July 7, 2025.7 The criteria decide which review applies. The utility’s technical screens still decide whether a project passes.

Review Maryland criteria Conditions that matter
Level 1 Inverter-based facility, or combined facilities at one connection, with nameplate capacity of 20 kilowatts or less Technical screens still apply. BGE labels its threshold as AC.72
Level 2 Nameplate capacity of 2 megawatts or less, lab-certified or field-approved equipment, and a radial circuit or a spot network serving one customer The rule also provides a route after an unsuccessful Level 1 review. Meeting the capacity test doesn’t mean every technical screen passes.7
Level 3 Non-exporting facilities. Area-network and radial-circuit routes have different limits The radial route needs capacity and aggregate circuit generation of 10 megawatts or less, export prevention, no shared transformer and no utility construction. The area-network route has a 50-kilowatt facility limit plus further equipment and aggregate limits.7
Level 4 Detailed study when the project can’t qualify for or pass the simpler routes Studies can include feasibility, system impact and facilities studies. The utility identifies required upgrades.78

A rooftop proposal on a radial circuit that can export is a good test case. Check whether the equipment and capacity meet the Level 2 criteria. Don’t pick Level 3 just because the owner expects to use most of the power on site. Maryland’s general requirements separate non-exporting Level 3 systems from the limited-export agreements available to Level 2 or Level 4 customers.9

BGE adds its own rule. Its application page says projects over 1,350 kilowatts AC connecting to 13-kilovolt circuits require Level 4 study.5 Check that condition for your connection alongside the statewide criteria.

Which version of the rule applies right now?

Maryland’s emergency amendments to this chapter took effect May 12, 2026, and the Public Service Commission (PSC) proposed permanent versions on September 18. As of October 25, 2026, the public record shows no adopted permanent text, and the emergency amendments’ listed October 10 expiration date has passed.1011 Here is the sequence.

Date What happened Source
May 12, 2026 Emergency amendments to COMAR 20.50.09 took effect 10
August 3, 2026 PSC considered the permanent versions at a rulemaking meeting (RM 94) 10
September 18, 2026 PSC proposed the permanent versions in the Maryland Register 10
October 10, 2026 Listed expiration date of the emergency amendments 10
October 16, 2026 Register’s table of pending proposals still lists the amendments as proposed, not adopted 11
October 19, 2026 Public comment period closed 1011
COMAR 20.50.09 emergency and permanent amendments, 2026Source: 1011
  1. May 12, 2026Emergency amendments to COMAR 20.50.09 took effect
  2. August 3, 2026PSC considered the permanent versions at a rulemaking meeting
  3. September 18, 2026PSC proposed the permanent versions in the Maryland Register
  4. October 10, 2026Listed expiration date of the emergency amendments
  5. October 16, 2026Register's table of pending proposals still lists the amendments as proposed, not adopted
  6. October 19, 2026Public comment period closed

The PSC’s docket for this rulemaking (RM 94) lists a notice of a final rulemaking session dated October 5 and comments filed October 13 and 19, with no order adopting the amendments.11 Which version a utility applies to a pending application is a question for the utility, and you should get the answer in writing. Check the RM 94 docket for any order filed after October 25.

The PSC says the proposal exists to remove obstacles to connecting utility-scale projects so they can meet federal tax-credit deadlines.10 It leaves the review criteria in this section, the study periods and the 20-business-day permission-to-operate deadline as they are. It adds temporary permission to operate, combined studies and a PSC ombudsman for disputes.10 Until the PSC adopts the amendments, the library text above is the version the State publishes.

How do the utilities’ application workflows differ?

Pepco, BGE and Southern Maryland Electric Cooperative (SMECO) each run their own application workflow inside Maryland’s regulatory framework. Dominion Virginia uses a Net Metering Interconnection Notification form and its own approval sequence. Use the serving utility’s current documents, and keep the application identifier with every design revision and inspection receipt.12131415

Utility Application and completion handoff Owner’s next step
Pepco Maryland Applications are filed online through Pepco’s Connect the Grid portal. The contractor supplies the technical documents and signatures, completes Part 2 after installation, and Pepco emails permission to operate (PTO) after final review.12 Keep the application, invoice, approved design, completion submission and operating email. Don’t substitute a District of Columbia form or fee schedule.
BGE Maryland BGE sends a Certificate of Completion that must come back with proof of local inspection, such as an inspection certificate. Amounts owed to BGE for the interconnection services must reach the company before interconnection.13 Settle who uploads the inspection evidence and when BGE accepts the completion package.
SMECO Maryland Applications go in electronically through PowerClerk. SMECO’s tariff separates the approved interconnection agreement, installation, local inspection, and submission of the inspection certificate and completion form.14 Get the review fee, study scope, export-control conditions and written operating authorization on paper.
Dominion Virginia (comparison) Dominion separates the Net Metering Interconnection Notification form, contingent approval, electrician certification or local inspection, and a PTO email after metering and billing work.15 Contingent approval comes before operating permission. Dominion’s Blue Book lists three-phase, four-wire 208/120-volt and 480/277-volt grounded-wye services as examples.16 Ask Dominion which technical requirements and tariff apply to the account.

Our Pepco interconnection and permission-to-operate guide and BGE interconnection guide cover each utility’s steps in more detail.

Soleil Energy describes its solar engineering, procurement and construction work on its utility-scale solar page. The utility keeps its own review and approval role.

How long do studies and operating permission take?

Each clock covers one task after one starting event, not the whole project. Maryland’s regulations separate application screening, signed study agreements, utility construction, inspection and operating permission. Confirm which rule version applies and that every prerequisite is in before you rely on any of them.17818

The first screen has its own clock. Within 10 business days of a request, the utility determines the interconnection jurisdiction and the level of review.7 The periods below run from the library text described above.18178

Task Period and starting point Limits in the rule text
Level 2 evaluation 20 business days after the utility notifies the applicant it received a completed request The evaluation uses the Level 2 screens. If the utility needs more information, the evaluation can extend by the time it takes to get it. The rule bars restarting the review or changing queue position for that reason (COMAR 20.50.09.10).17
Level 4 feasibility study 30 calendar days after both parties sign the study agreement Covers the study only. Engineering and construction fall outside it (COMAR 20.50.09.12E).8
Level 4 system impact study, if required 45 calendar days after both parties sign the study agreement Identifies impacts and required distribution upgrades. Higher-queued requests can delay when the study starts (COMAR 20.50.09.12C and E).8
Level 4 facilities study 30 calendar days without interconnection upgrades, 45 with upgrades, after the parties sign the agreement Estimates facilities, construction cost and installation time. The period covers the study. Building the upgrade comes later (COMAR 20.50.09.12E).8
PTO notice (Levels 2, 3 and 4) 20 business days after the utility receives acceptable documents Agreed milestones, code approval, the completion certificate, any requested photographs and a successful witness test (if the utility runs one) must be in place (COMAR 20.50.09.10G, .11E and .12F).18
Maryland small-generator review clocks (COMAR 20.50.09)Source: 81718
  1. Level 2 evaluation20 business days after the utility notifies the applicant it received a completed request
  2. Level 4 feasibility study30 calendar days after both parties sign the study agreement
  3. Level 4 system impact study, if required45 calendar days after both parties sign the study agreement
  4. Level 4 facilities study30 calendar days without interconnection upgrades, 45 with upgrades, after the parties sign the agreement
  5. PTO notice (Levels 2, 3 and 4)20 business days after the utility receives acceptable documents

These periods don’t add up to a promised total. The Level 4 text lets the parties waive or combine studies by agreement, and construction follows the milestones in the interconnection agreement.8 Request separate dates from the utility for finishing studies, procuring its equipment, its own construction, inspection acceptance and operating permission.

What can the utility charge?

The application fee is only the first charge. Engineering studies, shared hosting-capacity charges and project-specific equipment are billed on top of it. Ask for an itemized estimate that says what it leaves out and whether the final bill follows actual costs.192021

Charge Amount Applies to Source
Pepco application fee, Level 2 $50 plus $1 per kilowatt of rated generating-facility output Pepco Maryland Pepco tariff, effective May 1, 2026 20
Pepco application fee, Levels 3 and 4 $100 plus $2 per kilowatt Pepco Maryland Pepco tariff, effective May 1, 2026 20
Pepco hosting-capacity fee (Maryland Cost Allocation Method, secondary voltage, or MCAM-S) $151 per kilowatt plus $0.15 per kilowatt administrative charge Eligible small commercial connections at 600 volts or less Pepco tariff, effective May 1, 2026 19
SMECO review fee, Levels 2 and 3 $260 SMECO Maryland SMECO Rider GIS, effective June 1, 2023 22
SMECO review fee, Level 4 $950 SMECO Maryland SMECO Rider GIS, effective June 1, 2023 22
SMECO pre-application report $220 (systems over 20 kilowatts) SMECO Maryland SMECO Rider GIS, effective June 1, 2023 22

Those are tariff rates, not project totals. The MCAM-S charge scales with system size, so ask Pepco for the dollar figure at your kilowatt rating. Upgrade costs for on-site equipment sit apart from them.19 Pepco’s invoice should show which capacity it bills, which rider applies and how it treats your application date.

Pepco’s page says the primary-voltage version (MCAM-P) has no approved implementation date and no determined fees. Requests received before implementation keep the stated pre-implementation upgrade-cost treatment.23 Don’t apply the secondary-voltage rate to a primary-service account.

Two other costs deserve a question. Maryland’s rule has the utility offer a pre-application report for projects over 20 kilowatts of nameplate capacity, due within 20 business days once the utility’s fee is paid.7 And the library text lets a utility collect a study deposit of the lesser of a percentage of its estimate or a fixed cap: 100 percent or $1,000 for a feasibility study, 50 percent or $3,000 for a system impact study, and 50 percent or $10,000 for a facilities study.8 The PSC’s proposed amendments would allow a fee of up to 100 percent of the estimate for each study and strike those fixed dollar caps.10

Dominion shows the same pattern in Virginia. Its February 16, 2026 parameters manual warns that its example distribution and substation improvement estimates cover materials only. Engineering, labor and construction are additional, and customers remain responsible for the actual cost of required improvements.21 A published equipment estimate isn’t an installed-price quote.

When does a project enter the PJM queue?

Usually not at all. PJM Interconnection (PJM), the regional grid and wholesale-market operator, treats physical connection and wholesale participation separately. A project seeking PJM energy or capacity resource status needs PJM’s request and studies alongside the local process. A facility with no wholesale sales follows the state process.1324

The Federal Energy Regulatory Commission (FERC) accepted for filing PJM tariff changes requiring resources that interconnect to local distribution facilities to participate in PJM’s markets to interconnect under state or local procedures and to sign a separate Wholesale Market Participation Agreement (WMPA). The acceptance order is dated December 4, 2025.24 Maryland’s rule points the same way. Small generator facilities interconnect under its chapter or under PJM’s physical interconnection requirements, and a utility may not charge interconnection request fees for requests under PJM jurisdiction.1

PJM Manual 14H, revision 07, effective August 19, 2026, lays out the distinction:3

Intended arrangement Question to answer before choosing a queue
Retail self-supply or utility net metering Confirm the local utility’s interconnection process and retail tariff. Retail export credits aren’t a PJM wholesale sale.
Distribution connection seeking PJM energy or capacity resource status PJM’s manual calls for a Generation New Service Request, relevant system impact studies, a local physical interconnection agreement and a WMPA. Utility approval of the physical connection doesn’t grant wholesale participation.3
Transmission connection or an unusual jurisdictional arrangement Have PJM and the utility determine jurisdiction and the agreements required. A voltage label alone doesn’t resolve every exception.3

Under the manual, the local physical agreement has to be executed by Decision Point III for the project to move on to the WMPA.3 Your project team should be able to name the PJM cycle and the agreements that apply.

If the connection work turns into utility equipment or distribution work, Soleil Energy’s power infrastructure page covers that scope. The connection review decides whether any of it is needed.

Which dates matter besides the utility’s?

Utility operating permission, net-metering admission and tax eligibility are three separate milestones, and the date your contractor finishes installing satisfies none of them. Take the net-metering answer from the utility or the regulator, and the tax answer from a qualified tax professional.252627

Net metering. Maryland’s Utility RELIEF Act (Chapter 353 of the 2026 Acts) says the Public Service Commission must require electric utilities to offer a standard net-metering contract or tariff to eligible customer-generators, first come, first served, until the earlier of the date eligible customer-generators’ rated capacity reaches 3,000 megawatts statewide or July 1, 2027.25 The dates that follow come from the statute and PSC notices.

Date What happens Source
October 27, 2026 Date the PSC’s May notice set for the Net Energy Metering (NEM) Successor Working Group’s draft report and framework; check the PSC’s PC 78 docket for what was filed 28
December 15, 2026 The PSC’s report on the successor proceeding is due to the Governor and General Assembly 25
February 1, 2027 The PSC must approve a successor framework 2528
July 1, 2027 Successor program to begin; existing program closes to new entrants if the 3,000-megawatt cap isn’t reached first 25

The cutoff leaves one question open for an ordinary commercial applicant: which milestone secures a place under the existing tariff. The PSC’s June 2026 draft rule in rulemaking docket RM 56 lists three competing tests: a submitted application, a signed interconnection agreement, or permission to operate. As of October 25, the docket shows comments filed through October 13 and no adopted rule.26 Until the PSC picks one, don’t plan around any single version. Our guide to what replaces Maryland net metering covers the successor program.

Federal tax credit. Public Law 119-21 provides that section 48E does not apply to solar property placed in service after December 31, 2027, and that this change applies to facilities whose construction begins after the date 12 months after enactment, which is July 4, 2026.27 “Placed in service” is a tax term: Treasury’s regulation treats a facility as placed in service in the earlier of the year its depreciation period begins or the year it is in a condition of readiness and availability to produce electricity.29 A utility’s PTO, including a temporary one, is a separate document, so ask a tax professional what counts as the start of construction and whether the PTO matters for your tax date. Our guide to the commercial solar tax credit deadline goes further.

What should you have in writing before you commit?

Get a written connection plan that names the serving utility, the export arrangement, the review level, the studies required and who owns each approval. Keep records of accepted submissions and open utility conditions, and keep the construction schedule separate from utility milestones and from any tax or program determination.1213153

  1. Give the project team the utility account, existing equipment records and authority to pull load data. The engineer prepares the single-line diagram, site plan and equipment specifications.12
  2. Have the utility name the connection point, the review track and the information it needs before it accepts the application.
  3. Get itemized application, study, hosting-capacity and upgrade costs, along with what the estimate excludes and who pays for changes.
  4. Put one person in charge of tracking signed study agreements, information requests, utility construction milestones and inspection acceptance.
  5. Get operating permission in writing, and confirm retail compensation or wholesale-market arrangements before you count on projected revenue.12153

A common stall. Say the contractor has finished the installation and the local inspector has signed off, but the utility hasn’t accepted the completion package. Find out who has to supply the missing documents and when the utility will acknowledge receipt. An inspection pass doesn’t mean the utility has finished its review or issued permission to operate.121315

Out of scope here: transmission connections, community-solar eligibility, expansions of existing systems and storage operating modes. A changed export arrangement or equipment design can trigger a different review, so put those questions in the utility’s written scope.193

Where should a Maryland commercial project start?

Start by pinning down your review level and which rule version the utility applies, and don’t let a contractor’s schedule stand in for the utility’s. For a Maryland commercial solar project, request a proposal or call (301) 953-4140. The commercial inquiry form is on Soleil Energy’s utility-scale solar page.

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.

Sources (29)

  1. Maryland Division of State Documents, COMAR 20.50.09.01 (Scope), Library of Maryland Regulations. https://regs.maryland.gov/us/md/exec/comar/20.50.09/index.full.html (chapter last amended effective July 7, 2025; read October 25, 2026) ↩ ↩2 ↩3 ↩4

  2. BGE, Choosing an Application (current page, undated; read October 25, 2026). https://www.bge.com/smart-energy/my-green-power-connection/developers-contractors/choosing-an-application ↩ ↩2 ↩3

  3. PJM Interconnection, Manual 14H, New Service Requests Cycle Process, sections 2.2, 9.11 and 9.12, revision 07 effective August 19, 2026, read October 25, 2026. https://www.pjm.com/-/media/DotCom/documents/manuals/m14h.pdf ; PJM Open Access Transmission Tariff, Part VIII, Subpart F, section 433, effective April 28, 2026 (docket ER26-5-000), read October 25, 2026. https://www.pjm.com/pjmfiles/directory/merged-tariffs/oatt.pdf ↩ ↩2 ↩3 ↩4 ↩5 ↩6 ↩7 ↩8 ↩9

  4. Maryland Division of State Documents, COMAR 20.50.09.02 (definition of nameplate capacity), Library of Maryland Regulations. https://regs.maryland.gov/us/md/exec/comar/20.50.09/index.full.html (chapter last amended effective July 7, 2025; read October 25, 2026) ↩

  5. BGE, Choosing an Application, Level 2 and Level 4 descriptions (current page, undated; read October 25, 2026). https://www.bge.com/smart-energy/my-green-power-connection/developers-contractors/choosing-an-application ↩ ↩2

  6. Montgomery County Department of Permitting Services, Electrical and Mechanical Codes, Licenses and Permits (current page, undated; read October 25, 2026). https://www.montgomerycountymd.gov/department-permitting-services/codes/electrical-mechanical-codes-licenses-permits ↩

  7. Maryland Division of State Documents, COMAR 20.50.09.06 and .08 (pre-application reports; determination of review level; Level 1 to Level 4 criteria), Library of Maryland Regulations. https://regs.maryland.gov/us/md/exec/comar/20.50.09/index.full.html (chapter last amended effective July 7, 2025; read October 25, 2026) ↩ ↩2 ↩3 ↩4 ↩5 ↩6 ↩7 ↩8

  8. Maryland Division of State Documents, COMAR 20.50.09.12 (Level 4 study review), Library of Maryland Regulations. https://regs.maryland.gov/us/md/exec/comar/20.50.09/index.full.html (chapter last amended effective July 7, 2025; read October 25, 2026) ↩ ↩2 ↩3 ↩4 ↩5 ↩6 ↩7 ↩8

  9. Maryland Division of State Documents, COMAR 20.50.09.06 (General Requirements, including limited export agreements), Library of Maryland Regulations. https://regs.maryland.gov/us/md/exec/comar/20.50.09/index.full.html (chapter last amended effective July 7, 2025; read October 25, 2026) ↩ ↩2

  10. Maryland Register, volume 53, issue 19, Notice of Proposed Action 26-143-P (COMAR 20.50.09), September 18, 2026 (read October 25, 2026). https://dsd.maryland.gov/MDRIssues/5319/Assembled.aspx ; Maryland Division of State Documents, Emergencies table (file dated September 30, 2026; read October 25, 2026). https://dsd.maryland.gov/PDF/Emergencies.pdf ↩ ↩2 ↩3 ↩4 ↩5 ↩6 ↩7 ↩8 ↩9

  11. Maryland Division of State Documents, Table of Pending Proposals (file dated October 15, 2026, listing proposals through the October 16, 2026 Register issue; read October 25, 2026). https://dsd.maryland.gov/PDF/ProposalTable.pdf ; Maryland Public Service Commission, case file for rulemaking RM 94 (COMAR 20.50.09), entries through October 19, 2026 (read October 25, 2026). https://webpscxb.pscmaryland.com/DMS/rm/RM94 ↩ ↩2 ↩3 ↩4

  12. Pepco, Interconnection Application Process (current page, undated; read October 25, 2026). https://www.pepco.com/smart-energy/my-green-power-connection/developers-contractors/applying-for-interconnection/interconnection-application-process ↩ ↩2 ↩3 ↩4 ↩5 ↩6

  13. BGE, Applying for Interconnection (current page, undated; read October 25, 2026). https://www.bge.com/smart-energy/my-green-power-connection/developers-contractors/applying-for-interconnection ↩ ↩2 ↩3 ↩4

  14. SMECO, Solar and Net Metering (current page, undated; read October 25, 2026). https://www.smeco.coop/services/solar-net-metering/ ; SMECO, Retail Electric Service Tariff Rider GIS, issued May 15, 2023, effective June 1, 2023 (read October 25, 2026). https://www.smeco.coop/wp-content/uploads/RiderGIS.pdf ↩ ↩2

  15. Dominion Energy Virginia, Net Metering (current page, undated; read October 25, 2026). https://www.dominionenergy.com/virginia/renewable-energy-programs/net-metering ↩ ↩2 ↩3 ↩4 ↩5

  16. Dominion Energy, Information and Requirements for Electric Service (Blue Book), section 120.1, 2023 edition with March 2024 page footer, read October 25, 2026. https://cdn-dominionenergy-prd-001.azureedge.net/-/media/content/renewable-energy-programs/pdfs/virginia/blue-book.pdf?rev=39002999aa1b40dca038832740469dd0&hash=50461F3AD3398CDC2FB2EA1DF40DA92A ↩

  17. Maryland Division of State Documents, COMAR 20.50.09.10 (Level 2 review), Library of Maryland Regulations. https://regs.maryland.gov/us/md/exec/comar/20.50.09/index.full.html (chapter last amended effective July 7, 2025; read October 25, 2026) ↩ ↩2 ↩3

  18. Maryland Division of State Documents, COMAR 20.50.09.10G, .11E and .12F (permission to operate), Library of Maryland Regulations. https://regs.maryland.gov/us/md/exec/comar/20.50.09/index.full.html (chapter last amended effective July 7, 2025; read October 25, 2026) ↩ ↩2 ↩3

  19. Pepco, Maryland Electric Tariff, Rider MCAM-S (pages 64 to 64.2), issued and effective May 1, 2026; the tariff cover shows the current update effective October 1, 2026 (read October 25, 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 ↩ ↩2 ↩3

  20. Pepco, Maryland Electric Tariff, Small Generator Interconnection Standard (page 65), issued and effective May 1, 2026; the tariff cover shows the current update effective October 1, 2026 (read October 25, 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 ↩ ↩2 ↩3

  21. Dominion Energy, Net Metering Distributed Energy Resources Interconnection Parameters, Appendix C, version 3.0 dated February 16, 2026 and approved March 4, 2026, read October 25, 2026. https://cdn-dominionenergy-prd-001.azureedge.net/-/media/content/renewable-energy-programs/net-metering/pdfs/virginia/nem-der-interconnection-parameters-manual.pdf?rev=74d41001394149d59428d247d22a1e33&hash=89EDB384056795687D77AC85A563861D ↩ ↩2

  22. SMECO, Retail Electric Service Tariff Rider GIS, sheet 159, issued May 15, 2023, effective June 1, 2023 (read October 25, 2026). https://www.smeco.coop/wp-content/uploads/RiderGIS.pdf ↩ ↩2 ↩3

  23. Pepco, Maryland Cost Allocation Method (MCAM) (current page, undated; read October 25, 2026). https://www.pepco.com/smart-energy/my-green-power-connection/developers-contractors/applying-for-interconnection/applying-for-interconnection-in-maryland ↩

  24. Federal Energy Regulatory Commission, order accepting PJM tariff revisions, docket ER26-5-000, December 4, 2025, read October 25, 2026. https://www.pjm.com/pjmfiles/directory/etariff/FercOrders/8528/20251204-er26-5-000.pdf ↩ ↩2

  25. Maryland General Assembly, Chapter 353 of the 2026 Acts (HB 1532, Utility RELIEF Act): Public Utilities Article section 7-306(d), new section 7-306.4(c) (successor framework by February 1, 2027), and Section 9(c) (PSC report due December 15, 2026); enacted May 12, 2026 (read October 25, 2026). https://mgaleg.maryland.gov/2026RS/Chapters_noln/CH_353_hb1532e.pdf ↩ ↩2 ↩3 ↩4 ↩5

  26. Maryland Public Service Commission, Proposed Regulations, rulemaking RM 56 (proposed COMAR 20.50.10.01(D)), June 2026; case file for RM 56, latest entry October 13, 2026 (read October 25, 2026). https://psc.maryland.gov/wp-content/uploads/2026/06/Proposed-Regulations-RM-56.pdf ; https://webpscxb.pscmaryland.com/DMS/rm/RM56 ↩ ↩2

  27. U.S. Congress, Public Law 119-21, section 70513(a) and (g)(5), enacted July 4, 2025 (read October 25, 2026). https://www.congress.gov/119/plaws/publ21/PLAW-119publ21.htm ↩ ↩2

  28. Maryland Public Service Commission, Notice Convening a Public Conference, Administrative Docket PC 78, May 14, 2026: successor framework due February 1, 2027, and NEM Successor Working Group draft report and framework due October 27, 2026 (read October 25, 2026). https://psc.maryland.gov/wp-content/uploads/2026/05/Notice_Convening-a-PC-PC-78.pdf ↩ ↩2

  29. Electronic Code of Federal Regulations, 26 CFR 1.48E-2(b)(2) (placed in service, qualified facility; eCFR page up to date as of October 22, 2026; read October 25, 2026). https://www.ecfr.gov/current/title-26/part-1/section-1.48E-2 ↩

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