Chapter 09. Small Generator Facility Interconnection Standards

The small generator facility is a qualifying facility pursuant to the Public Utility Regulatory Policies Act that intends to make sales at a rate approved by the Maryland Commission;

The small generator facility is not a qualifying facility pursuant to the Public Utility Regulatory Policies Act and does not intend to make sales of wholesale electric energy through the PJM Interconnection, LLC;

The small generator facility intends to make sales of wholesale electric energy through the PJM Interconnection, LLC at an electric distribution interconnection facility where there has been no prior FERC jurisdictional service;

The small generator facility intends to make sales of wholesale electric energy through the PJM Interconnection, LLC only at an electric distribution interconnection facility through participation in a distributed energy resource aggregation; or

The small generator facility will be interconnected to an electric distribution circuit and its energy will not be transmitted across state lines for a wholesale customer other than the electric distribution owner.

“AC EVSE” means supply equipment that passes alternating current to the EV with conversion between AC and DC accomplished onboard the EV.

“Adverse system impact” means a negative effect, due to technical or operational limits on conductors or equipment being exceeded, that may compromise the safety or reliability of the electric distribution system.

“Affected system” means a utility electric system that is affected by the interconnection of a small generator facility to another utility’s electric distribution system.

“Aggregate generation” means the aggregated net system capacities of all small generator facilities across multiple points of common coupling.

“Applicant” means a person who has submitted an interconnection request to interconnect a small generator facility to a utility's electric distribution system.

“Area network” means a type of electric distribution system served by multiple transformers interconnected in an electrical network circuit, often used in large, densely populated metropolitan areas.

“Bidirectional electric vehicle” has the meaning stated in Public Utilities Article, §7-1001(c), Annotated Code of Maryland.

“Certificate of completion” means a certificate provided by a utility to an applicant containing information about the interconnection equipment used, its installation, and local inspections.

“Closed circuit” means an electric distribution system circuit with no available hosting capacity.

“Commissioning test” means one of several tests applied to a small generator facility by the applicant after construction is completed to verify that the small generator facility does not create adverse system impacts, including the test specified in Section 5.4 of IEEE Standard 1547.

“DC EVSE” means supply equipment that passes direct current to or from the EV, with the EVSE accomplishing conversion between AC and DC.

“Default utility required inverter settings profile” means a utility set of default smart inverter settings optimized for use across a utility’s service territory.

“Distributed energy resource” means any geographically dispersed energy resource located on an electric distribution system that produces electricity or offsets electrical demand including small generator facilities, energy storage devices, energy efficiency devices, and demand response devices.

“Distribution upgrade” means a required addition or modification to the utility electric distribution system, excluding the interconnection facilities, necessary to accommodate the interconnection of a small generator facility.

“Draw-out type circuit breaker” means a molded case switching device that:

Electric Distribution System.

“Electric vehicle” or “EV” means a vehicle that employs electrical energy as a primary or secondary mode of propulsion and is capable of charging the onboard battery from an external supply of electricity.

“Electric vehicle supply equipment” or “EVSE” means a device or system designed and used specifically to transfer electrical energy between an electric vehicle and the electric grid.

“Energy Storage Device” means a piece of equipment that captures energy produced at one time, stores that energy for a period of time, and delivers that energy as electricity at a future time.

“Fault current” means the electrical current that flows through a circuit during an electrical fault condition, such as when one or more electrical conductors contact ground or each other.

“Grid support services” means compensated or uncompensated services unrelated to wholesale markets provided by a small generator facility that support the safety, stability, reliability, or economics of the electric grid.

“Hosting capacity” means the amount of aggregate generation that can be accommodated on an electric distribution system or area, or a system component, without requiring infrastructure upgrades.

“Hosting capacity reporting system” means the information available on a utility website providing reports, tabular data, or maps of hosting capacity available on the electric distribution system.

“Hosting capacity upgrade plan” means a utility plan to promote clean energy interconnection for a particular area or a proposal to open multiple restricted and closed circuits or areas on an electric system in the aggregate through proactive distribution system investments that includes a cost allocation and recovery proposal, under conditions that are approved by the Commission.

“IEEE Standard 1547” means the standard incorporated by reference in COMAR 20.50.02.02.

“IEEE Standard 1547.1” means the standard incorporated by reference in COMAR 20.50.02.02.

“Inadvertent export” means the unscheduled export of power from a small generator facility, beyond a specified magnitude and for a limited duration, generally due to fluctuations in load-following behavior.

“Interconnection agreement” means an agreement that contains details regarding the proposed interconnection equipment and its operation to ensure the reliability and safety of the grid, including schedules, rights, obligations, and terms and conditions that become effective on the date the agreement is executed by the utility and the interconnection customer.

“Interconnection customer” means an entity that proposes to interconnect or has interconnected a small generator facility to an electric distribution system.

Interconnection Equipment.

Interconnection Facilities.

“Interconnection facility cost sharing” means the allocation of distribution interconnection facility upgrade costs among multiple small generator facility projects that utilize the hosting capacity created by an interconnection facility upgrade.

“Interconnection request” means an applicant's request for the interconnection of a small generator facility, or to increase the capacity or operating characteristics of a small generator facility that is already interconnected with the utility's electric distribution system.

“Interconnection study” means an interconnection feasibility study, interconnection system impact study, or interconnection facilities study as described in Regulation .12 of this chapter.

“Limited export agreement” means an agreement for energy supplied to the grid by an interconnection customer that may be managed to specified ramp rates and generation levels for operating conditions, as specified in the interconnection agreement or in a separate limited export agreement.

“Line section” means that portion of a utility electric distribution system connected to an interconnection customer, bounded by automatic sectionalizing devices, or the end of the distribution line.

Local Electric Power System.

“Meter collar adapter” means an electronic device that is installed between a residential electric meter and the meter socket, for the purpose of facilitating the deployment of customer-owned or customer-leased technology.

“Minor equipment modification” means a change to the proposed small generator facility that does not have a significant impact on safety or reliability of the electric distribution system.

“Minor system modification” means a change to the distribution system:

“Nameplate capacity” means the maximum rated output of a generator at a point of common coupling of all electric power production equipment or energy storage devices under specific conditions designated by the manufacturer that is usually listed on a nameplate physically attached to the equipment.

“Nationally recognized testing laboratory (NRTL)” means a qualified private organization recognized by the Occupational Safety and Health Administration to perform independent safety testing and product certification.

“Net system capacity” means the total export capacity at a point of common coupling of a small generator facility as measured by the nameplate capacities of all power production units and energy storage devices minus their consumption of electrical power, if applicable, as limited through the use of a control system, power relays, or other similar device settings or adjustments.

“Parallel operation” means the sustained state of operation over 100 milliseconds which occurs when a small generator facility is connected electrically to the electric distribution system, and thus has the ability for electricity to flow from the small generator facility to the electric distribution system.

“Permission to operate notice” means the written permission provided by a utility in the form of an email or letter authorizing an interconnection customer to interconnect and operate its small generator interconnection facility.

“Point of common coupling” means the point of interconnection where the small generator facility is electrically connected to the electric distribution system.

“Point of interconnection” has the same meaning as the term “point of common coupling”.

“Primary line” means a distribution line rated at greater than 600 volts.

“Primary voltage hosting capacity upgrade cost” means the equipment upgrade costs of all interconnection equipment, interconnection facilities, protective devices and associated communications systems, and other upgrades that directly increase hosting capacity for multiple primary voltage and secondary voltage interconnection customers while excluding equipment upgrade costs that solely benefit a single interconnection customer, to the extent practicable and material.

“Primary voltage interconnection customer” means an interconnection customer with a point of interconnection at greater than 600 nominal volts.

Proposed Use.

“Queue position” means the order of a completed interconnection request, relative to all other pending completed interconnection requests, that is established based upon the date and time of receipt of the completed interconnection request by the utility.

“Radial distribution circuit” means a circuit configuration in which independent feeders branch out radially from a common source of supply.

“Reserve hosting capacity” means the amount of hosting capacity reserved for small generator facilities on an electric distribution system circuit.

“Restricted circuit” means an electric system distribution circuit with reserve hosting capacity.

“Rightsizing” means to increase the size, scope, and cost of an electric utility hosting capacity upgrade project, following a distributed energy resource interconnection request, to account for both the immediate interconnection customer’s needs and future hosting capacity needs that are identified by the electric utility through a distributed energy resource forecast.

“Scoping meeting” means a meeting between the applicant and utility conducted for the purpose of discussing alternative interconnection options, exchanging information, including any electric distribution system data and earlier study evaluations that would be reasonably expected to impact interconnection options, analyzing information, and determining the potential feasible points of interconnection.

“Secondary line” means a service line subsequent to the primary line that is rated for 600 volts or less, also referred to as the customer's service line.

“Secondary voltage hosting capacity upgrade cost” means the costs of all primary voltage and secondary voltage interconnection equipment upgrades that directly increase secondary voltage hosting capacity available to multiple secondary voltage interconnection customers while excluding all primary voltage and secondary voltage interconnection equipment upgrade costs that solely benefit a single interconnection customer, to the extent practicable and material.

“Secondary voltage interconnection customer” means an interconnection customer with a point of interconnection at less than or equal to 600 nominal volts.

“Shared transformer" means a transformer that supplies secondary source voltage to more than one customer.

“Site-specific utility required inverter settings profile” means a set of smart inverter settings optimized for use at a specific site on a utility’s electric system.

Small Generator Facility.

“Smart Inverter” means any inverter hardware system certified to be compliant with IEEE 1547-2018 or subsequent revisions to these standards.

Spot Network.

“Statewide utility required inverter settings profile” or “grid code” means a set of smart inverter settings optimized for use Statewide that can be used by utilities and manufacturers in establishing defaults.

“Technical interconnection requirement” or “TIR” means a public-facing document available on an electric company's website that specifies interconnection technical review criteria and distributed energy resource functional settings.

“Utility monitoring and control plan” means a plan to monitor and control, in the aggregate, a set of small generator facilities in multiple locations that includes a cost recovery method, under conditions that are approved by the Commission.

“Utility required inverter settings profile” means smart inverter settings for a small generator facility that are established by a utility.

“V1G or managed charging” means a range of approaches from utility programs and rate design to incentivize ratepayers for varying the time or rate at which an electric vehicle is charged.

“V1G Ready EVSE” is an EVSE that is capable of controlled charging rate operation but is either not certified for or is certified for but not programmed or configured for bidirectional operation.

“V2G or vehicle-to-grid” means the ability for an EVSE connected to a bidirectional electric vehicle to operate in parallel to the grid and both receive and feed power to the point of interconnection between the EVSE and the grid.

“V2G Ready EVSE” is an AC EVSE or DC EVSE, is certified for and programmed or configured for bidirectional operation as part of a V2G system in parallel with the electric grid.

“V2G System” is a combination of hardware and software in or around the EVSE and EV for the purposes of communication with and programmed flow of energy into and out of the vehicle battery in support of electrical loads or systems offboard the EV, including the electric grid.

“Witness test” means, for lab-certified or field-approved equipment, verification either by an on-site observation or review of documents by the utility that the interconnection installation evaluation required by Section 5.3 of IEEE Standard 1547 and the commissioning test required by Section 5.4 of IEEE Standard 1547 have been adequately performed.

Contact information for the interconnection customer;

Existing utility account information;

Location information for the small generator facility;

Contact information for the interconnection customer’s equipment and electrical contractors;

Information on the manner in which the interconnection customer intends to use the small generator facility;

Requested review level for interconnection request;

Technical information regarding the generator and prime mover;

Technical information regarding the interconnection components and system or systems;

Location and other information regarding disconnect switch for small generator facility;

Details regarding any plans to export power to the electric distribution system; and

Any other item specified by the Commission.

Sign and submit an interconnection request electronically on the utility’s website;

Track the status of the interconnection request electronically; and

Conduct electronically any other process that can reasonably occur in that manner.

A utility shall designate a contact person, and provide contact information on its website and for the Commission's website for submission of all interconnection requests, and from whom information on the interconnection request process and the utility's electric distribution system can be obtained.

The information provided by the utility on its website shall include studies and other materials useful to an understanding of the feasibility of interconnecting a small generator facility on the utility electric distribution system, except to the extent providing the materials would violate security requirements or confidentiality agreements, or be contrary to law.

For projects with a nameplate capacity over 20kW, the utility shall:

The pre-application report shall rely largely on pre-existing utility data and shall, at a minimum, include the following items:

In appropriate circumstances, the utility may require an applicant to execute an appropriate confidentiality agreement prior to release or access to confidential or restricted information.

To minimize the cost of interconnecting multiple small generator facilities, the utility or the applicant may propose a single point of interconnection for multiple small generator facilities located at a single site.

If an applicant rejects a utility proposal for a single point of interconnection, the applicant shall pay any additional cost of providing separate points of interconnection for each small generator facility.

If a utility unreasonably rejects a customer proposal for a single point of interconnection without providing a written technical explanation, the utility shall pay any additional cost of providing separate points of interconnection for each small generator facility.

A small generator facility shall be capable of being isolated from the utility electric distribution system.

For a small generator facility interconnecting to a primary or secondary line, the isolation shall be by means of a lockable, visible-break isolation device accessible by the utility.

The isolation device shall be installed, owned, and maintained by the interconnection customer for the small generator facility, and located electrically between the small generator facility and the point of interconnection.

A draw-out type circuit breaker with a provision for padlocking at the draw-out position satisfies the requirement for an isolation device.

An interconnection customer may elect to provide the utility access to an isolation device that is contained in a building or area that may be unoccupied and locked or not otherwise readily accessible to the utility, by installing a lockbox provided by the utility that shall allow ready access to the isolation device.

The lockbox shall be in a location that is readily accessible by the utility, and the interconnection customer shall permit the utility to affix a placard in a location of its choosing that provides clear instructions to utility operating personnel on access to the isolation device.

In the event the interconnection customer fails to comply with the terms of this section and the utility needs to gain access to the isolation device, the utility may not be held liable for any damages resulting from any necessary utility action to isolate the small generator facility.

Any metering necessitated by a small generator facility interconnection shall be installed, operated, and maintained in accordance with the applicable utility tariff.

Any small generator facility metering requirements shall be clearly identified as part of the interconnection agreement executed by the interconnection customer and the utility.

Utility monitoring or control of a small generator facility shall be permitted subject to the conditions in §J of this regulation.

Any utility monitoring or control requirements shall be:

For a small generator facility under a nameplate capacity of 2 MW, utility monitoring or control is not permitted unless:

Equipment certified under the latest published editions of IEEE 1547, IEEE 1547.1, and UL 1741 shall be permitted to be used for monitoring or control upon mutual agreement of the utility and the interconnection customer.

A utility monitoring and control plan submitted to the Commission pursuant to §J(3)(a) of this regulation shall include:

Designed;

Installed;

Maintained; and

Operated to the extent reasonable and practical, in accordance with accepted industry standards and meet utility cybersecurity requirements

The utility shall have the option of performing a witness test after construction of the small generator facility is completed.

The applicant shall provide the utility at least 5 business days notice of the planned commissioning test for the small generator facility.

If the utility elects to perform a witness test, the utility shall contact the applicant to schedule the witness test at a mutually agreeable time within 10 business days of the scheduled commissioning test.

If the utility does not perform the witness test within 10 business days of the commissioning test, the witness test is considered waived unless the utility and applicant agree to extend the time for conducting the witness test.

If the results of the witness test are not acceptable to the utility, the applicant shall address and resolve any deficiencies within 30 calendar days, which may be extended upon the request of the applicant prior to the expiration of the 30-calendar-day period. A request for extension may not be unreasonably denied by the utility.

If the applicant fails to address and resolve the deficiencies to the satisfaction of the utility, the interconnection request shall be considered withdrawn.

If a witness test is not performed by the utility or an entity approved by the utility, the applicant shall satisfy the interconnection test specifications and requirements specified in Section 8 of IEEE Standard 1547.1-2020.

For interconnection equipment that has not been certified or approved under Regulation .07 of this chapter, the witness test may also include the verification by the utility specified in Section 8 of IEEE Standard 1547.1-2020.

All tests verified by the utility shall be performed in accordance with the test procedures specified in Section 8 of IEEE Standard 1547.1-2020.

The applicant shall, if requested by the utility, provide a copy of all documentation in its possession regarding testing conducted under Section 8 of IEEE Standard 1547.1-2020.

The applicant shall demonstrate that it meets the smart inverter requirements of §O of this regulation, if applicable.

If requested by the applicant, the utility shall provide the applicant copies of any interconnection studies performed in analyzing an interconnection request.

An applicant may provide any other prospective applicant copies of interconnection studies to aid in streamlining a future utility review.

Queue position for all small generator facilities shall be prioritized based on the date the interconnection request is submitted.

Each utility shall publicly and electronically provide an interconnection queue, updated monthly, that includes the following information about each interconnection request for any small generator facility with a nameplate capacity greater than 500 kW:

A small generator facility shall remain on the list for at least 3 years after the interconnection request was approved by the utility, unless subsequently cancelled or removed from the interconnection queue pursuant to §N of this regulation.

A utility may provide any additional information to a prospective applicant if the utility determines that doing so would streamline the utility’s review of an interconnection request.

A utility has no obligation to provide any prospective applicant any information regarding prior interconnection requests, including a prior applicant's name, copies of prior interconnection studies performed by the utility, or any other information regarding a prior applicant or request.

A project participating as a community solar energy generating system under COMAR 20.62 is not subject to this section.

The notice of conditional approval shall clearly identify the applicable deadline and the consequences of failing to either deliver the certification of completion or request an extension by the deadline.

Once the utility delivers notice of conditional approval to the applicant, the applicant shall deliver the certification of completion within the following time frames:

A project participating in the Community Solar pilot program under COMAR 20.62 is not subject to this section.

After January 1, 2024, any small generator facility requiring an inverter that submits an interconnection request shall use a smart inverter with either a default or a site-specific utility required inverter settings profile, as determined by a utility.

Any small generator facility may replace an existing inverter with a similar spare inverter that was purchased prior to January 1, 2024, for use at the small generator facility. This requirement does not apply to inverter replacements conducted under manufacturer warranty.

Prior to January 1, 2024, all utilities will establish default utility required inverter settings profiles for smart inverters pursuant to §O(5) of this regulation. A utility with a total number of less than 150,000 customers served in Maryland may use a Statewide utility required inverter settings profile as their default utility required inverter settings profile.

To the extent reasonable, pursuant to any modifications required by §O(5) of this regulation, all utility required inverter setting profiles shall be consistent with applicable smart inverter recommendations from PJM Interconnection, LLC that are applicable.

A default utility required inverter settings profile shall be established by a utility to optimize the safe and reliable operation of the electric distribution system, and shall serve the following objectives:

A site-specific utility required inverter settings profile may be established by a utility as necessary to optimally meet the objectives established in §O(5) of this regulation.

All default and site-specific utility required inverter settings profiles shall be documented in interconnection agreements.

A default utility required inverter settings profile shall be published on the utility’s website.

A utility with a total number of 150,000 or more customers served in Maryland shall:

Commission Staff shall file any changes to the established statewide utility required inverter settings profile with the Commission for approval.

A utility required inverter settings profile or statewide utility required inverter settings profile shall be deemed approved within 90 days upon filing, unless directed otherwise by the Commission.

Utilities shall approve interconnection requests while considering flexible interconnection options under a limited export agreement or, for inadvertent export, net system capacity and a proposed use subject to the requirements of this section.

Inadvertent Export for Energy Storage Devices.

Net System Capacity and Proposed Use.

Limited Export Agreements.

If required by the utility, the small generator facility shall be subject to a verification reporting plan to monitor the small generator facility’s compliance with any flexible interconnection option limits involving net system capacity, inadvertent export, proposed use, and limited export agreement requirements as documented in the interconnection agreement. A verification reporting plan may include periodic reports, online monitoring, or other verification methods, or it may be waived as agreed upon by the utility and interconnection customer.

Utilities may include a recurring administrative fee in utility tariffs as a term in flexible interconnection option agreements to reimburse the utility for estimated additional costs to administer these agreements and the stated limiting conditions.

Failure of a small generator facility to demonstrate compliance with the facility’s verification reporting plan may result in the suspension of utility approvals in this section until the small generator facility agrees and implements an acceptable corrective action plan with the utility within 30 calendar days of notification by the utility.

A small generator facility shall cease to export power if it fails to provide an acceptable corrective action plan to the utility, pursuant to §P(7) of this regulation.

Utilities shall establish hosting capacity policies subject to the following requirements:

A utility may submit for the Commission’s review and approval a hosting capacity upgrade plan or multiple plans to address or otherwise increase the utility’s existing distribution aggregate circuit hosting capacity limits across the system, or in a specific area of an electric utility’s system, that are forecasted to be congested in the future if the utility’s forecast of distributed energy resource growth exceeds existing hosting capacity. These plans may be considered by the Commission if primary voltage hosting capacity upgrade fees, pursuant to §R of this regulation, exceed a threshold of the utility’s average cost per kilowatt for their aggregate customer funded hosting capacity upgrade projects completed in the previous year, unless good cause exists for a utility to request a waiver of this requirement.

Hosting capacity upgrade plans that are submitted by a utility shall include:

A utility shall have a procedure for calculating hosting capacity accounting for either gross peak or gross minimum loading based on good engineering practice.

The utility shall perform a representative sample of hosting capacity calculation validation checks at least annually, or more frequently in areas experiencing significant growth or distributed energy resource penetration. The hosting capacity calculation validation check frequency shall account for the utility's experience, good engineering practices, and judgment.

Within 1 year of the effective date of this regulation, electric utilities shall submit an electric utility service tariff for Commission approval for a primary voltage hosting capacity cost sharing and allocation methodology for interconnection customers, as follows:

Within 1 year of the effective date of this regulation, electric utilities shall submit an electric utility service tariff for Commission approval for a secondary voltage cost sharing and fee for both residential and commercial interconnection customers, as follows:

Hosting capacity fees for primary voltage interconnection customers shall be reset using a cost sharing and allocation methodology approved by the Commission in an electric utility service tariff filing whenever a change in methodology is proposed, unless the fee is zero or the fee change is less than $1 per kilowatt.

Hosting capacity fees for secondary voltage interconnection customers shall be reset annually using a cost sharing and allocation methodology approved by the Commission unless the fee is zero or the fee change is less than $1 per kilowatt from the current fee in the electric utility’s service tariff.

A utility may submit for Commission approval an administrative charge in its service tariff to recover its administrative costs for managing the cost sharing and allocation methodology for primary and secondary voltage interconnection customers.

A utility shall describe all hosting capacity upgrade project rightsizing projects describing their forecasts, inputs, and assumptions in their next rate case to assist stakeholders in a prudency review.

A V2G System shall meet the following requirements:

An electric company may delay interconnection of a V2G system to provide adequate time to ensure electric distribution system safety and reliability in advance of vehicle-to-grid interconnections pursuant to applicable requirements in Regulation .09 of this chapter for Level 1 Review, Regulation .10 of this chapter for a Level 2 Review, Regulation .11 of this chapter for a Level 3 Review, and Regulation .12 of this chapter for a Level 4 Review.

To ensure safety, reliability and V2G functionality for DC EVSE V2G Systems, the interconnection agreement shall require adherence to UL 1741 incorporated by reference in COMAR 20.50.02.02(I).

To ensure safety, reliability and V2G functionality for AC EVSE V2G Systems there are two acceptable certification pathways for which only one certification pathway shall be required in an interconnection agreement:

If applicable, certifications pursuant to Regulation .06S(4) of this chapter are not available or safety, reliability, and V2G functionality cannot be ensured:

A V1G System shall meet the following requirements.

The meter collar adapter model is approved or listed by a nationally recognized testing laboratory;

The meter collar adapter model is approved for use in utility service areas, unless sufficient rational for disapproval is provided by an electric utility;

All meter collar model installations, access, testing, inspections, servicing, and removals shall only be performed by a qualified person as agreed between the utility and the meter collar manufacturer;

The meter collar adapter model design does not impede access to the sealed meter socket compartment, or to the meter itself by a qualified person;

The meter collar adapter model is compatible with the National Electric Code; and

The meter collar adapter model is compatible to the specific meter configurations and customer applications to ensure that the meter collar adapter is capable of being safely and reliably inserted into a meter socket to maintain a secure connection with both the meter socket and the utility meter.

The meter collar adapter is qualified to be connected to the supply side of the service disconnect, pursuant to the applicable provisions of the National Electric Code;

The meter collar adapter is rated for the meter socket into which it is intended to be installed;

The meter collar adapter does not exceed the weight bearing limits of a meter socket;

Multiple meter collar adapters are not stacked in a meter socket; and

The meter collar adapter does not disable this excessive heating detection capability of AMI meters.

The following criteria are met:

Alternatively, the small generator facility was reviewed under Level 1 review procedures but not approved, and the applicant has submitted a new interconnection request for consideration.

For interconnection requests to the load side of an area network:

For interconnection requests to a radial distribution circuit:

The interconnection request cannot be approved under a Level 1, Level 2, or Level 3 review, and the applicant has submitted an interconnection request for consideration under a Level 4 study review; and

The interconnection request does not meet the criteria for qualifying for a review under Level 1, Level 2, or Level 3 review procedures.

For interconnection of a proposed small generator facility:

When a proposed small generator facility is to be interconnected on a single-phase shared secondary line, the aggregate generation on the shared secondary line, including the proposed small generator facility, may not exceed 20 kW;

When a proposed small generator facility is single-phase and is to be interconnected on a center tap neutral of a 240 volt service, its addition may not create an imbalance between the two sides of the 240 volt service of more than 20 percent of the nameplate rating of the service transformer;

As an alternative non-mandatory method to evaluate the adverse system impacts of a proposed Level 1 small generator facility on the distribution system, as described in §A(1)—(3) of this regulation, or as a mandatory next step prior to rejecting an interconnection request, pursuant to §E of this regulation, for Level 1 Review Failure, a utility may use a power-flow based analysis system with modeling of IEEE 1547-2018 inverter capabilities as follows, if its use may change the analysis result as determined by the utility:

Modification or construction of additional interconnection facilities by the utility on its distribution system, except for metering or a minor system modification, is not required to accommodate the small generator facility; and

If the proposed interconnection requires a minor system modification, the utility shall notify the applicant of that requirement when it provides the Level 1 evaluation result, as follows:

Within 5 business days after receipt of the interconnection request, inform the applicant that the interconnection request is:

Within 15 business days after the utility notifies the applicant that the application is complete under §B(1) of this regulation, verify that the small generator facility can be interconnected safely and reliably under §A of this regulation.

The small generator facility has been approved by local or municipal electric code officials with jurisdiction over the interconnection;

A certificate of completion has been returned to the utility;

The witness test has been successfully completed or waived by the utility; and

The applicant has signed an interconnection agreement.

If the small generator facility is not approved under a Level 1 review, the utility shall provide the applicant a letter explaining its reasons for denying the interconnection request.

If a small generator facility fails a Level 1 review, the utility may approve the interconnection request if the small generator facility can be interconnected safely and reliably to the utility’s electric distribution system.

When a small generator facility is not approved under a Level 1 review, the applicant may submit a new interconnection request for consideration under Level 2, Level 3, or Level 4 procedures.

For interconnection of a proposed small generator facility:

For fault current limitations:

The proposed small generator facility's point of interconnection may not be on a transmission line;

When a small generator facility is to be connected to 3-phase, 3-wire primary utility distribution lines, a 3-phase or single-phase generator shall be connected phase-to-phase;

When a small generator facility is to be connected to 3-phase, 4-wire primary utility distribution lines, a 3-phase or single-phase generator will be connected line-to-neutral and will be effectively grounded;

When the proposed small generator facility is to be interconnected on single-phase shared secondary line, the aggregate generation on the shared secondary line, including the proposed small generator facility, may not exceed 20 kW;

When a proposed small generator facility is single-phase and is to be interconnected on a center tap neutral of a 240 volt service, its addition may not create an imbalance between the two sides of the 240 volt service of more than 20 percent of the nameplate rating of the service transformer;

A small generator facility, in aggregate with other generation and energy storage devices interconnected to the distribution side of a substation transformer feeding the circuit where the small generator facility proposes to interconnect, the aggregate generation may not exceed 10 MW in an area where there are known or posted transient stability limitations to generating units located in the general electrical vicinity;

As an alternative non-mandatory method to evaluate the adverse system impacts of a proposed Level 2 small generator facility on the distribution system, as described in §A(1)—(8) of this regulation, or as a mandatory next step prior to rejecting an interconnection request, pursuant to §F of this regulation, for Level 2 Review Failure, a utility may use a power-flow based analysis system with modeling of IEEE 1547-2018 inverter capabilities as follows, if its use may change the analysis result as determined by the utility:

Except as permitted by an additional review in §G of this regulation, no modification or construction of additional facilities by a utility of its distribution system, with the exception of metering or a minor system modification, shall be required to accommodate the small generator facility; and

If the proposed interconnection facility requires a site-specific utility required inverter settings profile review or a minor system modification without further study review needed, the utility shall notify the applicant of that requirement when it provides the Level 2 evaluation result, as follows:

Complete; or

Incomplete and what materials are missing;

When an interconnection request is complete, the utility shall assign a queue position.

The queue position of the interconnection request shall be used to determine the potential adverse system impact of the small generator facility based on the relevant screening criteria.

The utility shall notify the applicant of any other higher queue position applicants on the same line section or spot network for which interconnection is sought.

Queue position may not be forfeited or otherwise impacted by the submission of a dispute under the provisions of Regulation .13 of this chapter.

The utility shall request the information;

The time necessary to complete the evaluation may be extended, but only to the extent of the delay required for receipt of the additional information; and

When additional information is required, the utility may not revert to the start of the review process or alter the applicant's queue position.

Evaluate the interconnection request using the Level 2 screening criteria;

Review the applicant's analysis, if provided by applicant, using the same criteria;

Provide the applicant with the utility's evaluation, including a comparison of the results of its own analyses with those of applicant, if applicable; and

When a utility does not have a record of receipt of the interconnection request and the applicant can demonstrate that the original interconnection request was delivered, expedite its review to complete the evaluation of the interconnection request within 20 business days.

Additional review may be appropriate when a small generator facility has failed to meet one or more of the Level 2 criteria of §A of this regulation.

A utility shall:

The utility shall undertake the additional review only if the applicant agrees within 10 business days to pay for the cost of the review, which may be extended at the request of the applicant. A request for extension may not be unreasonably denied by the utility.

If the review identifies the need for modifications to the distribution system, the utility shall make the necessary modifications only if the interconnection customer agrees to pay for the cost of the modifications.

When a utility determines that the interconnection request passes the Level 2 screening criteria, or fails one or more of the Level 2 screening criteria but determines that the small generator facility can be interconnected safely and reliably, the utility shall provide the applicant an interconnection agreement within 5 business days after the determination.

The applicant shall have either 30 calendar days, or another mutually agreeable time frame after receipt of the interconnection agreement, to sign and return the interconnection agreement.

If the applicant does not sign the interconnection agreement within 30 calendar days, the request shall be considered withdrawn unless the applicant and utility mutually agree to extend the time period for executing the interconnection agreement prior to the expiration of the 30-calendar-day calendar period. A request for extension may not be unreasonably denied by the utility.

After the interconnection agreement is signed by the applicant and utility, interconnection of the small generator facility shall proceed according to any milestones agreed to by the applicant and utility in the interconnection agreement.

The utility shall approve the interconnection request and provide a permission to operate notice within 20 business days of receipt of acceptable documents, subject to the following conditions:

If the small generator facility is not approved under a Level 2 review, the utility shall provide the applicant written notification explaining its reasons for denying the interconnection request.

The applicant may submit a new interconnection request for consideration under a Level 3 or Level 4 interconnection review; however, the queue position assigned to the Level 2 interconnection request shall be retained provided the request is made within 15 business days of notification that the current Level 2 interconnection request is denied.

Once the interconnection request is considered complete by the utility, the utility shall assign a queue position based upon the date and time the interconnection request is determined to be complete.

The queue position of each interconnection request shall be used to determine the potential adverse system impact of the small generator facility based on the relevant screening criteria.

The utility shall notify the applicant of any other higher queue position applicants on the same radial line or area network that the applicant is seeking to interconnect to.

Queue position may not be forfeited or otherwise impacted by any pending dispute submitted under the provisions of Regulation .13 of this chapter.

The utility shall evaluate the interconnection request under Level 2 interconnection review procedures as set forth in Regulation .10 of this chapter, except that the utility shall have 25 business days to conduct an area network impact study to determine any potential adverse system impact of interconnecting to the utility's area network;

If the area network impact study identifies potential adverse system impacts, the utility may determine at its sole discretion that it is inappropriate for the small generator facility to interconnect to the area network, in which case the interconnection request shall be denied; however, the applicant may elect to submit a new interconnection request for consideration under Level 4 procedures, in which case the queue position assigned to the Level 3 interconnection request will be retained provided the request is made within 15 business days of notification that the current application is denied;

The utility shall conduct the area network impact study at its own expense; and

In the event the utility denies the interconnection request, the utility shall provide the applicant with a copy of its area network impact study and written justification for denying the interconnection request.

Evaluate the interconnection request using the Level 2 review in Regulation .10 of this chapter; and

Approve the interconnection request if all of the applicable Level 2 screens are satisfied, except that the peak line section value indicated in Regulation .10A(1)(a) shall be 25 percent instead of 15 percent.

If a small generator facility satisfies the criteria in §C or D of this regulation, the utility shall approve the interconnection request and provide an interconnection agreement for the applicant to sign.

The applicant shall have 30 calendar days, or other mutually agreeable time frame after receipt of the interconnection agreement, to sign and return the interconnection agreement.

If the applicant does not sign the interconnection agreement within 30 calendar days, the interconnection request shall be considered withdrawn unless the applicant and utility mutually agree to extend the time period for executing the interconnection agreement prior to the expiration of the 30-calendar-day period. A request for extension may not be unreasonably denied by the utility.

After the interconnection agreement is signed by the applicant and utility, interconnection of the small generator facility shall proceed according to any milestones agreed to by the applicant and utility in the interconnection agreement.

The utility shall approve the interconnection request and provide a permission to operate notice within 20 business days of receipt of acceptable documents, subject to the following conditions:

If the small generator facility is not approved under a Level 3 review, the utility shall provide the applicant written notification explaining its reasons for denying the interconnection request.

If the small generator facility is not approved under a Level 3 review, the applicant may submit a new interconnection request for consideration under the Level 4 procedures; however, the queue position assigned to the Level 3 interconnection request shall be retained provided the request is submitted within 15 business days of the notice that the current Level 3 request was not approved.

Within 5 business days from receipt of an interconnection request, the utility shall notify the applicant whether the request is

If the interconnection request is not complete:

When an interconnection request is complete, the utility shall assign a queue position.

The utility shall use the queue position of an interconnection request to determine the cost responsibility necessary for the facilities to accommodate the interconnection.

The utility shall notify the applicant of other higher-queued applicants on the same line section of the new interconnection request.

Any required interconnection studies may not begin until the utility has completed its review of all other interconnection requests that have a higher queue position.

Queue position is not forfeited or otherwise impacted by any pending dispute submitted under the provisions of Regulation .13 of this chapter.

By mutual agreement of the utility and applicant, the scoping meeting may be waived and the interconnection feasibility study, interconnection impact study, or interconnection facilities studies provided for in a Level 4 review and discussed in this section may be waived or combined.

If agreed to by the utility and applicant, a scoping meeting shall be held within 10 business days, or other mutually agreed to time, after the utility has notified the applicant that the interconnection request is considered complete, or the applicant has requested that its interconnection request proceed after failing the requirements of a Level 2 review or Level 3 review.

The purpose of the meeting is to review the interconnection request, existing studies relevant to the interconnection request, and the results of the Level 1, Level 2, or Level 3 screening criteria.

If the utility and applicant agree at a scoping meeting that an interconnection feasibility study shall be performed, the utility shall provide to the applicant, not later than 5 business days after the scoping meeting:

If the applicant and utility agree at a scoping meeting that an interconnection feasibility study is not required, the utility shall provide to the applicant, not later than 5 business days after the scoping meeting:

If the utility and applicant agree at the scoping meeting that an interconnection feasibility study and system impact study are not required, the utility shall provide to the applicant, not later than 5 business days after the scoping meeting:

Interconnection Feasibility Study.

Interconnection System Impact Study.

Interconnection Facilities Study.

When a utility determines, as a result of the interconnection studies conducted under a Level 4 review, that it is appropriate to interconnect the small generator facility, the utility shall provide the applicant with an interconnection agreement.

The applicant shall have either 30 calendar days, or another mutually agreeable time frame after receipt of the interconnection agreement, to sign and return the interconnection agreement.

If the applicant does not sign the interconnection agreement within 30 calendar days, the request shall be considered withdrawn unless the applicant and utility mutually agree to extend the time period for executing the interconnection agreement prior to the expiration of the 30-calendar-day period. A request for extension may not be unreasonably denied by the utility.

After the interconnection agreement is signed by the applicant and utility, interconnection of the small generator facility shall proceed according to any milestones agreed to by the applicant and utility in the interconnection agreement.

The utility shall approve the interconnection request and provide a permission to operate notice within 20 business days of receipt of acceptable documents, subject to the following conditions:

If a dispute arises, the applicant or utility may seek immediate resolution through the procedures of COMAR 20.32.01.

Dispute resolution shall be conducted in an informal, expeditious manner to reach resolution with minimal costs and delay.

If a dispute arises involving technical matters regarding the interconnection process, dispute resolution shall be delegated to the Commission’s Engineering Division.

The total number nameplate capacity and total fees charged for the interconnection requests received, approved, and denied under Level 1, Level 2, Level 3, and Level 4 reviews;

The number of evaluations of interconnections requests approved and denied using any alternate process under Level 1, Level 2, Level 3, and Level 4 reviews;

The fuel type, if appropriate, total number, and nameplate capacity of small generator facilities approved in each of the following categories:

The number of interconnection requests that were not processed within the deadlines established for Level 1, Level 2, Level 3, and Level 4 reviews in this chapter;

The number of scoping meetings held, the number of feasibility studies, impact studies, and facility studies performed, and the fees charged for these studies;

The justifications for the actions taken to deny interconnection requests;

The number of interconnection requests that were not processed within the deadlines established for Level 1, Level 2, Level 3, and Level 4 reviews in this chapter due to a PJM Interconnection, LLC market process study; and

Any special operating requirements required in interconnection agreements, which are permitted only for generating facilities with a nameplate capacity greater than 2 MW, that are not part of the utility's standard operating procedures applicable to small generator facilities.

The total number of interconnection requests received, approved, and denied under Level 1, Level 2, Level 3, and Level 4 reviews;

The fuel type, or energy storage type, total number, and total nameplate capacity of small generator facilities approved in each of the following categories:

The number of interconnection requests that were not processed within the deadlines established for Level 1, Level 2, Level 3, and Level 4 reviews and permission to operate notices in this chapter;

The total number of interconnection requests denied and the reason for each denial;

Each interconnection request for a proposed small generator facility that received a cost estimate or incurred an actual cost of at least $10,000 for interconnection facilities or distribution upgrades and was completed during the reporting year, which shall include:

The number of scoping meetings held, the number of feasibility studies, impact studies, facility studies, and combined studies performed and the total fees charged for these studies;

For each interconnection request for a proposed small generator facility that failed to meet Level 2 criteria according to Regulation .10F of this chapter, a list of the queue number, reason for failure to meet Level 2 criteria, if the applicant requested additional review, whether the additional review was completed within 30 calendar days, or if the applicant decided to request interconnection under Level 4 criteria;

The current utility status and future plans and schedule for implementation of hosting capacity reporting systems or improvements to existing hosting capacity reporting systems;

Beginning April 1, 2021, a utility shall also report annually for the previous year:

Beginning April 1, 2024, if Volt-Watt control is implemented in a utility’s default utility required inverter settings profile, a utility shall also report for the electric distribution system annually for the previous year:

Beginning April 1, 2025, an electric utility shall report exemptions to Regulation .06R of this chapter annually for the previous year, including: