The SMART program is a declining block program in which the incentive levels will decline by prescribed amounts over up to eight blocks per Electric Distribution Company (EDC) territory. There are set-aside amounts for small projects (≤ 25 kW AC) in each block to enable projects of all sizes to participate. SMART also has Adders available that increase the amount of the incentive if features such as Energy Storage, Community Solar, or various location-based installations are proposed.
Developers of solar PV projects of all types and sizes, up to 5 MW per project, are welcome to apply via our online application portal. More information, and instructions to apply are available here.
To apply, register via our secure, online portal, which allows you to manage multiple projects and users through one account. All communication regarding the status of your application will be conducted through this online portal. For more information on how to register and a guide to navigating the portal, follow these steps or view our video tutorials.
Basics for New PowerClerk Interconnect Users
Submitting Multiple Applications
MA DOER held a series of stakeholder meetings across the state from 11/11/19 thru 11/19/18 that were well attended by hundreds of solar developers and other stakeholders. The presentation from those stakeholder meetings can be found in the Program Information section on the Resources tab. On October 24th, DOER hosted a webinar regarding the SMART application and claim process and how to use the PowerClerk application portal. A video of that webinar can be found here: https://www.youtube.com/watch?v=W2po4SKrxfg&feature=youtu.be CLEAResult has also created SMART PowerClerk User Guide to accompany the video which is also located on the Resources tab. Note that potential Applicants can now create their username and password on the SMART PowerClerk portals. The portals will be fully opened to begin accepting SMART applications at noon (ET) on November 26, 2018.
Dear Solar Stakeholder,
This email serves as notice that pursuant to its authority under 225 CMR 14.00 and 225 CMR 20.00, DOER has coordinated with the electric distribution companies to establish November 26, 2018 as the transition date from the SREC II Program to the SMART Program.
This date has been selected to ensure that the distribution companies have sufficient time to comply with all requirements of the Department of Public Utilities DPU-17-140-A order on the model SMART tariff and to ensure an orderly transition between the programs. Specifically, this will give the distribution companies the necessary time to be ready to expeditiously install production meters following the transition date so that they may begin issuing payments to the first customers to enroll under the SMART tariffs.
As of 12:00 PM ET on November 26, 2018, the SMART Statement of Qualification application portal managed by CLEAResult, the Solar Program Administrator, will open to begin accepting Statement of Qualification Applications for prospective Solar Tariff Generation Units (“STGU”) seeking to qualify under SMART. This will mark the start of the Initial Application Period, as described Section 3(a) of DOER’s Statement of Qualification Reservation Period Guideline.
The initial application period will last until 11:59 PM ET on November 30, 2018. All applications received between 12:00 PM ET November 26, 2018 and 11:59 PM ET November 30, 2018 will be considered to have been received at the same time for the purposes of establishing a queue to process applications for placement into Capacity Blocks. All applications received on or after 12:00 AM ET December 1, 2018 will be reviewed on a first come, first served, basis.
On October 24, 2018, CLEAResult, DOER, and the electric distribution companies will host a webinar from 3:00 PM ET – 5:00 PM ET that will provide a demonstration of the application portal and a walkthrough of the steps involved in submitting an application. This webinar will be recorded and posted to www.masmartsolar.com. Click here to register for the webinar and participate in real-time.
Facilities that intend to qualify under SREC II must meet the following deadlines and requirements:
Facilities 25 kW DC and Less
A facility sized 25 kW DC or less must have received its permission to operate or authorization to interconnect on or before November 26, 2018 in order to qualify for SREC II. Applicants will have until February 15, 2019 to submit an SREC II application for facilities that meet this and all other program eligibility criteria.
Facilities Larger than 25 kW DC
A facility larger than 25 kW DC must demonstrate that it was mechanically complete on or before November 26, 2018 in order to qualify for SREC II. Documentation that a facility was mechanically complete by this date must be submitted to DOER by no later than December 10, 2018, and may include one of the following:
Pursuant to 225 CMR 20.05 (2), a STGU that receives a Statement of Qualification under the SMART Program will be eligible to receive payments upon the effective date of the SMART Tariffs as approved by the DPU. In the 17-140-A Order (“17-140-A”), the DPU established the process by which the Electric Distribution Companies (“Distribution Companies” or “Company” individually) will finalize Company-specific SMART Tariffs. The Distribution Companies will be filing a joint model “SMART Provision”, which is the SMART tariff, not later than October 15, 2018. Following DPU review, the DPU will render its decision on the model SMART Provision and direct each Company to file company-specific SMART Provisions, which are further subject to review and approval by the DPU. Consistent with 17-140-A, the Distribution Companies will not begin to issue incentive payments or apply Alternative On Bill Credits until the DPU approves company-specific SMART Provisions. However, if the DPU approval of the company-specific SMART Provisions has not yet occurred prior to November 26, 2018, Statement of Qualification Applications for facilities seeking eligibility under SMART may still be submitted for review and approval by the Solar Program Administrator and DOER, as described above.
All stakeholder questions on the transition process or the SMART application process should be directed to [email protected] or [email protected]. All questions related to SREC II eligibility should be directed to [email protected].Regards, Michael Judge Director, Renewable and Alternative Energy Development Massachusetts Department of Energy Resources
Dear Solar Stakeholder,
On September 26th, the Department of Public Utilities (DPU) issued an order approving the model SMART tariff that was jointly filed by the electric distribution companies, an action that triggers the start of the transition process from the SREC II Program to the SMART Program.
The DPU’s order gives authorization to begin accepting applications for facilities seeking to qualify under the SMART Program. DOER is actively coordinating with the electric distribution companies and SMART Solar Program Administrator, and will soon announce a specific date when the application platform will be available.
To provide more detailed information on SMART Program requirements and the transition process between SREC II and the SMART Program, DOER will be holding a series of stakeholder meetings on the following dates and at the following locations:
Date and Time
Massachusetts Maritime Academy
October 11, 2018
Northern Essex Community College
October 15, 2018
Eversource; National Grid
Bridgewater State University
October 16, 2018
Eversource; National Grid
Mt. Wachusett Community College
October 17, 2018
National Grid; Unitil
October 18, 2018
Eversource; National Grid
Shakespeare and Company
October 19, 2018
Eversource; National Grid
October 19, 2018
Eversource; National Grid
For more details, visit our events calendar.
DOER will provide further guidance on the SMART Program effective date, the expected effective date of each Distribution Company’s tariffs, and the transition between SREC II and the SMART Program as it becomes available.
In the meantime, SREC II remains in effect and DOER will continue to accept applications.
All stakeholder questions on the transition process should be directed to [email protected].
Director, Renewable and Alternative Energy Development
Massachusetts Department of Energy Resources
On June 27th, the Massachusetts DOER, Eversource, National Grid, and CLEAResult presented updates on the MA SMART Program to 200 attendees of the Solar Energy Business Association of New England (SEBANE) at their annual summer solstice meeting in Boston. Attached are copies of these presentations. As noted on slide 14 of the Electric Distribution Company (EDC) presentation, National Grid and Eversource will be holding additional informational seminars around the state in coming months that will cover interconnection and related topics.
Massachusetts Department of Energy Resources (MA DOER) has updated the Behind The Meter (BTM) Value of Energy Workbook as of 5.1.18. The BTM Value of Energy Workbook provides solar developers and owners a tool to estimate the SMART solar program incentives available for various system sizes and types in all the eligible utility territories in Massachusetts. Be sure to use the most up to date version, available at the link above or under Additional Resources.
MA DOER has also finalized the Guidelines for Agricultural, Brownfield, and Low Income Solar Tariff Generation Units in the SMART Program. Those guidelines, along with others for the Statement of Qualification (SQ) Reservation Period, for Land Use and Siting, and for Capacity Blocks, Base Compensation Rates, and Compensation Rate Adders can also be downloaded under Additional Resources.
The SMART Program is not currently accepting applications. The date when the SMART Program reopens has not been finalized. However, it will probably not be earlier than late September or early October 2018. This is because the Program cannot reopen until the SMART tariff proceeding with the Massachusetts Department of Public Utilities (MA DPU) regarding the SMART Program tariff has been finalized. The SMART Program tariff proceeding is docketed as D.P.U. 17-140 and the notice of this docket can be found here: DPU 17-140. Once the MA DPU finalizes the SMART tariff, the program launch date will be announced. When the program reopening is announced, we will post the information on this website and will plan to give applicants several weeks to prepare.
When Block 1 reopens, solar PV developers with projects of virtually all types and sizes are welcome to apply via the SMART Program application portal. Eligible and complete applications with all required supporting documents will be processed on a first come-first served basis. However, there are special requirements in Block 1 for projects between 1 MW up to 5 MW: these can only apply to Block 1 if they are eligible for at least one of the Base Compensation Rate Adders as noted in Section 20.07(3)c. If a 1 MW – 5 MW project is not eligible for one of the Adders, it must wait to apply in Block 2.
As each Electric Distribution Company’s (EDC) Block 1 is filed, we will immediately start accepting applications for Block 2 for that EDC. The timing of each Block 2 opening will vary by EDC and is dependent upon how quickly their Block 1 fills. We will not accept applications for Block 2 in advance of any Block 1 being filled. Note that there are five EDCs/territories and five separate Blocks.
As we get closer to the reopening of Block 1, we will post more information on this website. We also intend to host webinars and/or seminars to assist applicants to prepare for the reopening.
Good news: Compensation levels for Block #1 are now set. For details, please download the Base Compensation Rates PDF.
Congratulations to all the developers whose bids were accepted for Block 1. The first phase of the SMART Program was a competitive Request for Proposals (RFP) for large solar PV projects of 1 MW to 5 MW in size. The purposes of the RFP were to obtain large amounts of solar for the Commonwealth of Massachusetts at competitive costs, and to use those competitive costs as a baseline for establishing the SMART Program incentives going forward. On behalf of the Massachusetts Department of Energy Resources, Eversource Energy, National Grid and Unitil, we are pleased to announce the following successful bidders to the SMART Program Block 1 Competitive RFP:
510 PV Project Development, LLC: 2.000 MW awarded to Washburn Road Solar in Freetown
Altus Power America Inc.: 1.000 MW awarded to BL MA Solar, LLC in Blandford
Long Plain Solar, LLC: 2.000 MW awarded to Long Plain Solar in South Deerﬁeld
Sunpin: 4.700 MW awarded to Otis Stage Rd. Blandford Solar Farm in Blandford
Bowden Solar Farm, LLC: 2.000 MW awarded to Bowden Solar in Monson
New Braintree Renewables, LLC: 1.670 MW awarded to New Braintree Renewables in New Braintree
New Braintree Solar 2, LLC: 1.000 MW awarded to New Braintree Solar 2 in New Braintree
Ameresco: 2.500 MW awarded to Otter River Road Solar LLC in Gardner
Oak Square Partners, LLC: 4.980 MW awarded to West Orange Solar in Orange
Oxford Community Solar LLC: 4.000 MW awarded to Oxford Solar in Oxford
510 PV Project Development, LLC: 3.468 MW awarded to River Street Solar in Palmer
Wachusett Solar, LLC: 2.000 MW awarded to Wachusett Solar in Rutland
510 PV Project Development, LLC: 4.950 MW awarded to West Street Solar in Gardner
Dynamic Energy Solutions, LLC: 3.995 MW awarded to Williamsburg East Street Solar LLC in Goshen
Dynamic Energy Solutions, LLC: 4.970 MW awarded to Winchendon Ash Street Solar 1 LLC in Winchendon
Dynamic Energy Solutions, LLC: 3.150 MW awarded to Winchendon Lincoln Avenue Solar 1 LLC in Winchendon
Dynamic Energy Solutions, LLC: 4.890 MW awarded to Winchendon Lincoln Avenue Solar 2 LLC in Winchendon
The SMART Program is governed by the regulations 225 CMR 20.00. Additionally, the EDCs have filed a model tariff with the Massachusetts Department of Public Utilities (docketed as DPU 17-140) that will allow the SMART Program to go into effect upon DPU review and approval. We encourage you to review the full program regulations but note some key information regarding the program offerings.
Please review the program regulations 225 CMR 20.00 for a full overview of requirements and information.
A full list of program terminology and definitions are available in the program regulations 225 CMR 20.00. Here are some of the top acronyms and definitions.
1. Question: What are the dates when applicants may begin to submit project applications for Block 1?
A: The SMART Program is not currently accepting applications. The date when the SMART Program will open has not yet been finalized because there is an open proceeding with the Massachusetts Department of Public Utilities (MA DPU) regarding the SMART Program tariff.
Once the MA DPU finalizes the tariff, the program launch date will be announced. (It is currently expected that this will be later this year, perhaps in the summer of 2018). At the time of the program launch date announcement, we will also publish a final list of application submission requirements so that potential applicants will have sufficient time to collect and prepare the required materials ahead of the program application submission window opening.
2. Question: When will Block 1 close and the program base incentive levels transition to Block 2?
A: Scheduled reductions in the MA SMART program incentive rates are based on cumulative capacity of applications, not based on elapsed time. Within each EDC’s program allocations, Blocks will close and incentive rates will decline only when prior Block capacity allocations have been filled.
Please note that there are 5 utility areas/territories within the MA SMART program, and that each Block allocation will fill independently, based on applications specifically within that territory. As each EDC’s blocks are filled, the program will immediately start accepting applications for the subsequent block for that utility. The timing of each of these transitions will vary by utility and will be dependent upon the volume of applications received and how quickly each EDC’s Blocks fill. Also note that each Block has a minimum of 20% of the Block capacity carved-out, or set aside, for small systems ≤ 25kW, and a maximum of 35% of each Block allowed for the small systems. As such, the small system portion of each Block will fill independently of the large system portion, and this will also vary by EDC territory.
3. Question: It is my understanding that SRECs are ended March 31st. What is happening in between the SRECs program ending and when the SMART Program will be rolled out?
A: To clarify, SREC II will end when the SMART program begins, without any gap between the two programs. Until that time, systems may continue to apply for SREC II participation and compensation.
SREC Factors for eligible projects over 25kW declined for those that were not mechanically complete by March 31, 2018 as shown in the table below:
|A(<=25 kW DC)||0.8|
|A(>25 kW DC)||0.7||0.65|
|Market Sector||Mechanically Complete by 3/31/2018||Mechanically Complete After 3/31/2018|
4. Question: When the SMART program opens again, will it be another competitive RFP or will applications be evaluated on a first-come, first-served basis? If first-come, first-served, do we have to be ready at midnight the day the program opens to get our application in?
A: We currently anticipate that the Block 1 application portal will open for applications during the East Coast morning business hours of the official program launch date, so applicants will not need to start at midnight. Throughout the program, all applications will be evaluated on a first-come, first-served basis, except for the first five business days (“Week One”), when applications will be processed differently. On Week One of the opening of Block 1, we will not sort applications based on time of submission - every applicant who submits a complete and eligible application on Week One will be considered to have submitted their application at the same time.
Applications for systems larger than 25kW received during the first five business days will then be ordered based on the execution date of the fully executed ISA submitted with the application. Applications for systems 25kW or smaller received on the first five business days will be ordered based on the date of execution of the installer contract that will need to be submitted with the SMART application. Both queues will be established based on this sorting.
On “Week Two” and beyond, every application will be date and time stamped and will be reviewed based on, and in order of, time and date of submission.
5. Question: Will the portal for the SQ from SREC II be used when applying for SMART?
A: No. The link to the application portal for SMART can be found at www.masmartsolar.com. Please note that this portal will be not be live and ready to accept applications until the official program launch date. Also note that each utility will have a unique entry portal to the application.
6. Question: As I understand it, systems greater than 1MW are not eligible to apply for Block 1 of the SMART Program, but rather must wait for Block 2. However, can we submit applications now for Block 2 in the portal? Or must we wait until Block 1 is completely closed first?
A: Systems equal to or greater than 1MW are eligible to receive Block 1 incentive compensation only if they are seeking an Adder. Systems equal to or greater than 1MW that are not seeking an Adder were expected to apply during the competitive RFP process of Block 1. Therefore, systems of this size without any adders will only be eligible for Block 2 and beyond. As noted, we will not approve applications for Block 2 incentive levels within a particular EDC territory until the applicable Block 1 for that territory is filled. If any 1 MW – 5 MW projects without adders are received before the applicable Block 1 is filled, the SPA reserves the option to either reject those applications and return them to the Applicant, or to put them in a holding queue. If any specific Block 1 fills on “Week One” of the program opening, such queued applications will be included in the “Week One” Block 2 filling and ordering process.
7. Question: After a project has been accepted by the SMART Program, how long does that project have to become operational? Is there a reservation period?
A: The Reservation Period is 12 months after the Statement of Qualifications has been issued. The project must be completed within that timeframe, or apply for an extension and pay an additional fee, or the Reservation will be cancelled.
8. Question: In the Block 1 competitive RFP, projects that were selected but withdrew their application are not eligible to reapply under a capacity Block until 800 MW of other STGU have received a statement of qualification. Does that apply to projects that are accepted into capacity blocks going forward?
A: No, this potential restriction would only apply to projects that were selected during the Block 1 competitive solicitation but subsequently withdraw their applications.
9. Question: The November 2017 Block 1 competitive RFP was requesting proposals for 100 MW of solar but less than this capacity was awarded. Does that mean that bids can be submitted for the remaining capacity at any time or at a specific time?
A: On January 11, 2018, 53.273 MW was awarded from the Block 1 competitive RFP. The remaining unawarded capacity that was available during the RFP process remains within Block 1 and will be available on a first come-first served basis when Block 1 re-opens later in 2018.
10. Question: Does a SMART Applicant have to be a Massachusetts based company?
A: No, the Applicant and/or System Owner do not have to be based in Massachusetts. However, the host site does have to be in MA and interconnected to one of the eligible EDC’s distribution system.
11. Question: Does the project have to be in Massachusetts or can it be located anywhere in ISO NE?
A: Yes, the host site must be in MA and interconnected to one of the eligible EDC’s distribution system.
12. Question: If the Blocks fill quickly, will they still decrease by 4%? It was my understanding that the Blocks were to be released year-by-year and the 4% was supposed to reflect the annual decrease in the cost of solar.
A: The SMART Program blocks are not limited to any specific time. The declining block model is designed to lower the overall cost to the ratepayers over time. The reductions are not intended to align with any market forces such as the costs of materials, federal policies, inflation, etc. Per 225 CMR 20.07 (5), the DOER will review Base Compensation Rates and Adders once 400MW have been qualified for the program, but the program will not pause during the review time, and blocks will continue to fill as applications are submitted.
13. Question: Are projects that are in construction right now with signed ISAs that are not part of SREC II eligible for the SMART Program? Is it possible to switch these to the SMART program? What is the process for getting such existing projects into the SMART Program?
A: Yes, projects with executed, valid and in-force ISA’s as of the time of their application, and which are not participating in SREC II, and which were completed on or after January 1, 2018, are eligible for the SMART program. These projects will need to apply for SMART incentives through the same process as any other eligible project once the MA SMART tariff is finalized and that application portal becomes available. Projects larger than 25kW must have a fully executed ISA to apply for and receive a capacity block reservation under the SMART program. Applicants must also have site control and be in possession of all non-ministerial permits.
14. Question: What happens at the end of the 10 and 20 year payment periods?
A: The SMART Program incentive payments will end after 10 years for systems 25 kW and smaller, or after 20 years for systems larger than 25 kW. The systems will no longer have any SMART Program obligations or direct program benefits after their term has been completed. The ownership rights to the Class I RECs will revert to the system owner following the end of the tariff term, and at that time the owner may sell the RECs on their own.
1. Question: Can current projects that are interconnected, generating power and net metering but not in the SREC program, still apply for the SMART Program? Similarly, can a PV project be built now (before the SMART Program opens) and apply for the SMART Program incentive later?
A: All systems interconnected on or after January 1, 2018 in Eversource, National Grid, or Unitil service territory are eligible to apply for SMART Program incentives, so long as they comply with the program terms and conditions and are not already enrolled in an SREC program.
2. Question: If I have a system that is currently qualified under an older incentive program (SREC I, SREC II, Commonwealth Solar), can I expand on that system and qualify it under the SMART program?
A: Projects installed on the same parcel as an existing system that receives incentives are eligible to apply to the SMART program. However, the new SMART system must be separately metered from the originally installed system.
3. Question: Are projects under construction in the SREC II program with existing ISAs able to switch to the SMART program if they cannot be finished by the deadline? If yes, what is the process?
A: A project that is currently qualified under SREC II but is not operational may apply to the SMART program providing that all minimum eligibility requirements are met. A project that is qualified but not operational under SREC II that wishes to switch to SMART must do the following:
4. Question: If a project is registered in the SREC program, does anything need to be formally waived to switch it to SMART?
A: Please see the answer to Question B.3. (above). A project that is currently qualified under SREC II but is not yet operational may apply to the SMART program providing that all of the SMART Program minimum eligibility requirements are met. Please note that these applications / program conversions will not be automatic. Every system wishing to participate in the SMART Program must submit a SMART Program application, and the project evaluation and assignment of capacity block reservations will be handled according to the SMART Program rules – typically on a first-come, first-served basis.
Upon the close of the SREC II Program, DOER will reject all applications that are not operational or have received an extension to their qualifications. However, if a project is still qualified for SREC II at the close of that program, but is not yet operational, the authorized representative must formally revoke the project from its SREC II status if they are planning on submitting the same project to SMART.
Any project that is currently qualified and operational under an existing incentive program, such as the SREC I or SREC II program, is not eligible to apply for SMART. If a system owner is interested in expanding upon an existing project, the expansion must be separately metered and submitted to the SMART Program as a new Solar Tariff Generation Unit.
5. Question: Are system expansions of projects from earlier programs eligible in SMART? For example, if a developer wants to add a 250 kW AC expansion to an existing 100 kW rooftop system that was installed under the Commonwealth Solar Incentive program, would that be allowed as a SMART facility? The existing system is configured as a behind the meter, net metering facility, so we are currently considering reconfiguring the existing system, and combining both systems behind a single (new) net meter. While we would receive net metering credits for the combined system, only the new system (250 kW AC) would apply under SMART. Would this be allowed? If so, how would DOER/SPA confirm the Base Rate for the SMART portion of the project? In other words, how would the SPA verify that the SMART portion is at or below 250 kW, not above?
A: As long as all the requirements of the SMART Program are satisfied, and that sufficient net metering cap space exists in the relevant EDC service territory, such an expansion would be eligible under SMART. However, two separate production meters would be required - one for the new SMART system, and one for the existing system. This would need to be clarified and approved by the applicable utility and clearly stated in the new ISA.
6. Question: How will the move from SREC II to SMART occur? Specifically, for a system that is installed, with an ISA with the utility, but not yet operational at the time that SMART launches, does the system need to be operational and producing prior to the SMART effective date to take service under SREC II, or does it just need the ISA and/or be installed prior to the effective date?
A: Systems sized 25kW and less must be interconnected and operating by the SMART Program Effective Date in order to remain eligible for the SREC II program.
Systems sized over 25kW must be installed and mechanically complete by the SMART Program Effective Date in order to qualify for SREC II. If systems are interconnected and enrolled in SREC II, they cannot enroll in SMART. If they are qualified for SREC II, but not operational, they may choose to retain SREC II Qualification and enroll in SREC II upon becoming operational. Applications should note that the SREC II program will end in 2027, and while installed systems retain eligibility for SREC II, certificates will not be generated beyond 2027.
Alternatively, systems that are installed and qualified for SREC II before the SMART Program Effective Date may choose to apply for SMART qualification. DOER will remove systems that apply for SMART from SREC II Qualification at that time.
1. Question: The SMART regulations 225 CMR 20.06 specify a Customer Disclosure Form for community solar. When will projects applying for the Community Solar Adder need this documentation in place for the off-taker customers? The regulations also state that prospective STGUs with a capacity of 25 kW or less must submit a copy of a Customer Disclosure Form signed by the Owner as part of its Statement of Qualification Application. Has this form been created yet and where can we get a copy?
A: DOER has released three draft customer disclosure forms for public comment. You can find the forms here . The customer disclosure form will provide consumer information including, but not limited to, contract pricing for the length of the agreement, complete system cost information, operation and maintenance responsibilities, disposition of associated RECs and tariff terms, and anticipated production. The signed Customer Disclosure Forms will need to be in executed and submitted to the SPA by the time the project is completed.
2. Question: What are the necessary qualifications that a Solar Tariff Generation Unit (“STGU”) owner must meet?
A: The SMART Program will develop an applicants’ checklist of required documents and will post this information on the MA SMART website prior to opening for new applications. Qualifications and documentation requirements will vary depending upon the size of the STGU applying for the incentive.
For systems less than or equal to 25kW, the following documents (per 225 CMR 20.06) will be required:
For systems over 25kW, the documents referenced above, as applicable, and the following:
To be fully enrolled in the tariff and be eligible to receive the incentives, all systems must provide evidence of authorization to interconnect. For systems larger than 25 kW, this is required at the time of application; for smaller systems of 25 kW or less, this will be required at the project completion.
Finally, additional documentation may be required to claim the incentive at project completion, if applicable. This may include Schedule Z, Payment Credit Transfer Form, Renewable Energy Certificate Assignment and Aggregation Form, Customer Disclosure Forms, W-9, or ACH/EFT payment information.
3. Question: For budgeting purposes, can you provide details on any application fees (upon submission of application) and developer’s security deposits (upon PPA execution).
A: When Block 1 re-opens later this year, an application fee will be required to submit an application. The fee will be payable via credit card through the application portal. The fee structure has not yet been finalized, but we expect it to be a nominal fee as compared to other project costs. There will not be a performance guarantee or security deposit required for the regular SMART Program; that was only required for the competitive RFP process which was completed in January 2018.
4. Question: Does the SMART incentive apply for sites served by a municipal utility? If so, what is the base incentive rate?
A: Projects interconnected to municipally owned utility/light department service territories are not eligible to participate in the SMART Program. Following the close of the SREC II Program, projects interconnected to municipal utility service territories may apply to the DOER for Class I Qualification. All interested projects should contact DOER for this process.
5. Question: Will the Solar Land Use rules only apply to projects that are located in parcels with more than ten (10) contiguous acres of Chapter 61 land or former Chapter 61 land?
A: There is no minimum size or number of acres for these provisions to apply. A straw proposal document from the development phase of SMART may have referenced 10 acres, but that document is outdated and not relevant to the final regulations. Applicants should refer to 225 CMR 20.00 which are the final approved regulations for the SMART Program.
6. Question: How will projects in the SMART program that are multi-family units work in terms of the Schedule Z allocations? Is using a Schedule Z still an option under SMART and if so, how will virtual net metering work under SMART?
A: Net metering rules and regulations are not changed or been impacted by SMART. All projects utilizing virtual net metering must continue to comply with those rules.
7. Question: Do projects above 1 MW need a certification of Qualifying Facility (QF) from FERC, in addition to an Statement of Qualification Application (SQA) for RPS Class I RECs in MA??
A: As part of the application for the SQ, projects larger than or equal to 1 MW must document that they have requested to the Federal Energy Regulatory Commission (FERC) for certification of the proposed STGU as a QF, pursuant to 18 C.F.R. § 292.207. For QF systems less than 1 MW, they are not required to provide certification of QF status. Evidence of FERC registration for projects of 1 MW or larger will be required at the time of application. Self-certification will be accepted for all project sizes. The developers don’t need to pay the extra fee if self-certification is the least costly option.
8. Question: Regarding the contiguous parcels clause, if there are properties that are separated in a way that do not touch or share a common boundary, that are separated by one property, have separate interconnections, and in a legal sense are non-contiguous, how would these be viewed in the tariff? As one unit or separate units? Does it matter if all such parcels are owned by the same owner?
A: Please refer to the SMART regulations 225 CMR 20.05 (5) [(f) & (g)]. If all the requirements stated in the regulations are met, it is possible that these could be considered separate units.
9. Question: Regarding the regulations and requirements for multiple projects owned by the same company, is there a requirement for minimum distance between 2 separate projects or any other restrictions in this regard?
A: Please refer to the SMART regulations 225 CMR 20.05 (5) [(f) & (g)]. These are the sections titled Project Segmentation. There are no restrictions for a company to own multiple projects providing that they do not violate the Project Segmentation rules.
10. Question: If a solar project that would be located on a building in a town that is served by a municipal light department, but which receives electric service/meter from one of the eligible utilities (Eversource, National Grid, or Unitil), would the PV project be eligible for SMART?
A: Yes, if this can be confirmed via a copy of a utility bill and authorization to interconnect from the applicable eligible utility.
11. Question: We have a countersigned ISA with an AC size of 400kW and originally was going to install under SREC. We are now rethinking that we would like to install it under SMART at a size of 250kW AC. When we submit into SMART through PowerClerk, would it be a problem to have the countersigned ISA at 400kW but apply at 250kW AC and want to build at that? Do we need to get a revised countersigned ISA at the size we want to build? We prefer to not have to do anything with the ISA since we have had it for a couple months and want to ensure we are in the queue for an early block.
A: As far as the SMART Program is concerned, this is allowed. We recommend that you include a note or memo of explanation with your application to help prevent it being flagged or slowed down during the review process. However, you should confirm with the utility that the ISA is still valid for the smaller size. Whether or not you need a new ISA is ultimately up to the interconnecting utility.
12. Question: Is the FERC Registration form and certification due from at Application or can it be provided at project completion? Also, would you accept self-certification with FREC for all size projects to eliminate the need to pay the fee to FERC?
A: Evidence of FERC registration for projects of 1 MW or larger will be required at the time of application. Self-certification will be accepted for all project sizes. The developers don’t need to pay the extra fee if self-certification is the least costly option.
13. Question: As the engineer of record for solar PV projects under the SMART program, I understand that I will need to provide a letter certifying the date the project has reached “mechanical completion.” Is there a definition for “mechanical completion” that the SMART program follows?
A: Mechanical completion: A Solar Tariff Generation Unit (STGU) that has been completely installed on the customer side of the meter, has passed the local wiring inspection, and is only waiting on the authorization to interconnect from the Distribution Company. For the purposes of satisfying the requirements of demonstrating mechanical completion, a STGU may provide a Certificate of Completion (COC), signed by the local electrical wiring inspector.
Therefore, we do not need you as the engineer of record to provide a letter, but we do need the COC signed by the local electrical wiring inspector.
14. Question: For the shading calculation done for Agricultural Solar Tariff Generation Units (ASTGU), is the 50% minimum reduction in solar based on time or energy? Is it that each square foot of land can’t be shaded more than 50% of the time or each square foot of land can’t lose more than 50% of the possible solar energy?
A: We recommend that you refer to the Guideline Regarding the Definition of Agricultural STGUs, specifically to page 3 in the System Design Parameters. These provisions are intended to ensure that crops can continue to be grown beneath the ASTGU. The MA Department of Agriculture and the MA DOER will require that applicants demonstrate that the sunlight available for crop production beneath, behind, and adjacent to the PV array is not reduced by more than 50% during the hours between 10AM and 5PM from March through October, and from 9AM to 6 PM from April through September. In other words, there can be no more than 50% more shadows on the field throughout the day, per square foot, because of the solar installation, than before the solar installation.
15. Question: What contract documentation is provided to solar facilities that are awarded a SMART tariff rate? I cannot seem to find any formal documents on the www.masmartsolar.com website that would be customary for a financier to examine before underwriting a solar project, similar to the way one would evaluate a PPA.
A: The official award or notification document for the SMART Program is called the Statement of Qualification (SQ) which will be issued by MA DOER. MA DOER has not yet finalized that document but when they do, we will post a sample on the website. Note that this is not a contract per se. The best description of that documentation and of the process is on the www.MASMARTSolar.com website in the Additional Resources section. Please see the SQ Reservation Period Guideline at the bottom of the webpage. Applicants will receive a preliminary SQ upon application approval, will have a 12 month Reservation Period to build the project, and will receive their final SQ upon completion based on the as-built specifications. The SQ will include the incentive rate that has been approved for the project. The legal or regulatory document for the entire program will be the SMART Tariff itself which will be issued or approved by the MA Dept. of Public Utilities sometime this summer, perhaps in mid-July.
1. Question: Based on 225 CMR 20.00 - Section 20.08, the Solar Incentive Payment is the (Base Compensation Rate + Compensation Rate Adders - Greenfield Subtractors) *kWh generated - value of the energy generated. I have two questions:
A: In the case of behind the meter systems, this energy value is derived from the avoided cost savings accrued by systems interconnected behind the meter. That is, behind the meter systems will serve on-site load first (and be compensated for this production in the form of avoided costs of energy they would otherwise have purchased from their EDC), before any export generation is sent back to the grid and compensated. This value of energy is removed from the SMART incentive calculation to avoid ‘double compensating’ system owners for the energy they produce. The SMART incentive is intended solely to provide incremental compensation to system owners for their STGU’s production. Whether through qualifying facility tariffs or net metering provisions, mechanisms already exist to compensate STGU owners for the value of the energy their systems produce and including these values in the SMART incentive would result in STGU owners being compensated twice for the same energy.
Regarding the second question, yes, standalone solar tariff generation units will receive value for the energy they produce, at the appropriate rate based on how the STGU is interconnected. This value will be conveyed either in the form of a direct payment if the system is interconnected as a Non-Net Metered Facility Qualifying Facility, or as a bill credit if the system is an Alternative Bill Credit Generation Unit or a Net Metered Generation Unit.
2. Question: I am trying to calculate incentive kWh values. I understand how to calculate the base rate and adders, but I'm not sure what to subtract to get the overall incentive.
A: This is defined in the SMART Program regulation (225 CMR 20.00). Specifically, please refer to section 20.08 regarding calculation of incentive payments. As defined in the regulations, the energy value netted out of each STGU’s incentive value will depend on which type of STGU installed.
In the case of standalone units, these value of energy variables will vary by EDC and by whether the standalone system is established as an Net Energy Metered system, an Alternative On-Bill Credit system, or a Qualifying Facility. Applicable values for each of these cases will be set by each EDC once the program is fully up and operating. Those values will vary by utility, rate class/code, and will change periodically over time - our current expectation is that these values will be updated annually.
In the case of behind-the-meter systems, the energy value netted out of the STGU’s incentive level is a three-year average of basic service, plus the current charges for distribution, transmission, and transition based on the utility rate class of the meter the system is interconnected to.Finally, other variables related to calculating incentive payments that are dependent on the outcome of the DPU SMART Tariff proceeding – final decisions here are not expected for at least several months. We will post additional information on http://masmartsolar.com as it becomes available.
3. Question: How will consumers be compensated from the base compensation rates that resulted from the Block 1 competitive solicitation? Assuming there is excess production, will a check be cut from the utilities on a monthly or yearly basis or bill credit? What if they want to cash out?
A: There is an open proceeding with the MA DPU regarding the SMART Program tariff that will finalize this process. It is expected that the utilities will both make payments and provide bill credits, depending upon the nature of the compensation earned. Net metering values and QF energy payments will continue to be applied as under current mechanisms. Dependent upon the outcome of the SMART tariff, it is expected that MA SMART incentive payments will be made in the form of monthly payments from EDC’s to system owners.
Please note that system owners may not be paid up-front for the expected value of any incentive payments. Incentive payments will be calculated over time based on measured system production and will be paid to system owners as earned.
4. Question: If a solar developer were to rent the roof of a commercial building and install a PV system, could that system be considered a standalone Solar Tariff Generation Unit?
A: If the Solar Tariff Generation Unit is not interconnected behind the utility meter of that building, but is interconnected in front of the meter, then yes, the incentives for this system could be calculated based on that STGU being a standalone system. This would need to be approved by the EDC and the building owner, and clearly demonstrated in the ISA and other application documents.
5. Question: How does compensation work for a commercial rooftop facility that is not net-metered (and doesn’t get any alternative credits, either), and which does not have an off-taker for the energy. Under the SMART program, will the facility still receive the full compensation (base rate + adders)? And then there is no subtraction for value of energy received? Does the facility need to do anything to become a QF in this scenario? Are there any special processes to receive compensation as a non-net metered facility?
A: If a commercial rooftop is not interconnected behind the meter at the building, the system will be considered a standalone system, and the SMART incentive will be established at the base rate plus any applicable adders less the value of energy produced by the system. As a non-net-metered system, the system will need to interconnect pursuant to the relevant EDC’s tariff for Qualifying Facilities (QF’s), and will be compensated for exported energy at the tariff’s QF rate. As noted in other questions regarding incentives, that energy value is then subtracted out from the SMART incentive rate (base + adders). The remaining value is what is paid to the generation unit owner by their EDC as the SMART incentive. Total system compensation would be based on both the value of the SMART incentive rate applied to all generated energy, plus the QF rate applied to all exported energy.
6. Question: How does net metering impact the value of solar calculation for behind the meter systems? Can behind the meter projects participate in both programs?
A: The Massachusetts Net Metering program is a not changed by the implementation of the SMART program. Net Metering is regulated by the Department of Public Utilities. The value of energy calculated for behind the meter projects does not change. As a result, a behind the meter project may receive the SMART incentive and may also receive net metering credits. If a STGU is behind the meter, and is not able to receive net metering, then that system will receive wholesale rates, as a Qualifying Facility, for any net exported energy (i.e. system production above and beyond what is consumed on-site).
7. Question: How are behind the meter PPA’s handled under the SMART program? If the two compensation methods utilized to disburse the incentive amount are net metering credits and on-bill credits, how does the program envision Third-Party Ownership? Would all incentives be paid out to the customer directly, or would there be the option for the Third-Party owner to receive these payments instead? Do the credits flow to the customer of record or the owner of the system? If the credits flow to the owner of the system is there still a value of energy adjustment?
A: All SMART incentives are paid to the STGU Owner directly based on the fixed rate established at the STGU’s qualification. The system owner may or may not be the same person or entity as the utility customer. In the case of third party ownership models, the incentive will be paid to the third-party owner, not to the utility customer. The incentive does not consider any amount set forth in a PPA – PPA terms are determined between the system owner and the customer of record. The value of energy calculation for that system will be set based on the three-year average of basic service and current transmission, transition and distribution charges tied to the utility rate of the meter the system is tied to. Any other contracted PPA rate is not considered in the value of energy calculation for behind the meter systems.
8. Question: Where will information be available regarding the 3-year average delivery and service rates needed to determine the ‘Value of Energy’ to subtract from base rates for behind the meter systems to determine the ‘all-in’ MA SMART incentive level for these systems?
A: We are currently working with the EDC’s on developing guidance for program participants on these values - they will be shared well ahead of the SMART Program launch date. Once available, they will be posted HERE, and will be made accessible from the MA SMART application portal website, as well.
9. Question: Can you clarify the difference between behind the meter and standalone systems?Specifically, with the standalone system is the incentive rate established upon interconnection and locked in regardless of any future changes in the utility rate? Conversely, under the behind the meter system, does the incentive rate remain fixed?
A: Standalone STGUs will receive value for the energy they produce, at the appropriate rate based on the nature of the STGU. This value will be conveyed either in the form of a direct payment if the system is interconnected as a Non-Net Metered Facility Qualifying Facility, or as a bill credit if the system is an Alternative Bill Credit Generation Unit or a Net Metered Generation Unit.
Behind the meter systems receive a fixed incentive rate based on the one-time calculation at the time the solar tariff generation unit is qualified.
10. Question: What are the tax implications for the SMART program? Can it be assumed that only the incentive portion beyond the avoided rate would be taxable? For example, in a scenario with total compensation rate of $0.17 and an avoided rate of $0.15, would only $0.02/kWh be subject to tax?
A: Neither DOER nor CLEAResult nor the EDC’s can provide tax guidance - we advise all prospective program participants to consult qualified tax professionals with any questions related to the tax treatment of their STGU’s or the compensation they expect to receive from the output of these systems.
11. Question: For a Behind-the-Meter STGU, can you confirm that the value of the energy subtracted does not include the supplier kWh charge? The Distribution, Transmission, Transition, and Basic Service are only on the utility side, correct? The following is from section 20.08 (2) from 225 CMR 20:
Behind-the-meter Solar Tariff Generation Unit Compensation Rate
= (Compacity Based Rate + Compasation Rate Adders
— Greenfield Subcontractor)
— (distribution kWh charge
+ transmission kWh charge
+ transition kWh charge
+ three year average of basic service kWh charge)
A: The value of energy subtracted from the all-in compensation rate for behind the meter systems does not include supplier charges. The value is derived only from those charges stated in the regulation.
12. Question: Are customers that purchase retail power from a retail energy supplier eligible for the SMART Program? If so, how would the value of energy be calculated for a BTM asset? Would it be the sum of the utility delivery charges (distribution, transmission, and transition) and the commodity price in the retail power contract? Or would you still use the utility basic service charges?
A: Yes, customers of retail electric suppliers are eligible for SMART. For a retail competitive supply customer, the value of energy for a BTMs system would use the applicable basic service rate for the investor owned utility service territory where they are located and interconnected.
13. Question: Is there information available regarding the new rate structure for the SMART program, specifically how new program will payout the incentives. Are there examples of a post-SMART program utility bill, any information on how the incentives will payout, or information that would be easy to understand from a homeowner's perspective?
A: The rate structure is dependent upon the ongoing DPU SMART tariff proceedings. It is likely that the utilities will be making monthly payments to SMART program participants. User guides and manuals that are designed to be easy for homeowners and other program participants to understand will be developed after the tariff is finalized and the program is fully launched.
14. Question: Is there a cap on the size of Behind-The-Meter (BTM) solar projects? If the on-site load doesn’t need all the energy produced, would the system owner receive a cash payment for the energy plus the SMART incentive?
A: The only cap that may apply to BTM systems is the limit of qualifying 5 MW AC per parcel under the SMART program. If a STGU has net energy exported to the grid, they will be compensated for the net export. The rate at which they are compensated will be either the net metering credit rate (if they are able to obtain a net metering cap allocation), or they will be compensated at the rate subject to that utility’s Qualifying Facility (QF) rate. QF rates are based on ISO-NE clearing prices and fluctuate based on either monthly averages for ≤ 60 kW systems without interval metering in place or based on the hourly Locational Marginal Prices (LMPs) for larger systems with interval metering.
15. Question: For a Standalone STGU registered as a State Qualifying Facility (QF), how will a project owner receive all the payments? Could both the incentive payments and QF compensation be paid directly to the project owner at the same monthly interval? Does there need to be any designated, commensurate electric load to take these payments directly?
A: For a Standalone QF, there does not need to be a significant onsite electric load or any behind the meter load in order to receive the payments. However, there does need to be an active account with the applicable EDC. The payment process will vary by EDC:
16. Question: For an Alternative On-Bill Credit (AOBC) STGU, is the on-bill credit value equal to the current default service supply rate? Additionally, is the amount of generation from the STGU that can be allocated to any single account limited to the usage on that account? Does this mean that accounts receiving on-bill credits can only effectively cancel out their supply charges with these credits?
A: The answer to this question depends upon the results of the MA DPU Tariff ruling. The current proposal is that the value of the credit will equal the basic service rate, and the maximum allocation will be limited to the total annual usage of each off-taker customer and/or the annual STGU facility’s output.
17. Question: What happens if a behind the meter system over produces on a (i) monthly schedule or (ii) a yearly schedule. Would the excess production roll over on the monthly schedule? If there is excess credit at the end of a year does the excess kWh get paid for at the SMART tariff base compensation rate or do they have no value?
A: We believe that you are confusing the value of the electricity vs. receiving SMART incentives. For Behind The Meter (BTM) systems, there are two options to be compensated for the electricity generated: Net Metering or as a State Qualifying Facility (QF). What you ask/describe sounds like a Net Metering question. Net Metering is a standalone program that is separate from SMART and for which the rules established by the MA DPU have not been changed by the SMART Program. For the SMART Program, a BTM facility is paid the approved incentive rate for whatever is generated as recorded on the utility grade production meter on the system. Thus, there is no such thing as “excess” production from the SMART Program perspective. These will be payments, not credits, for the entire 10 or 20 year term.
18. Question: Can the owner of a SMART qualifying solar project assign all SMART payments to a 3rd party, and what would be the process for making that assignment? For example, we have donated solar arrays to non-profits but have retained the SREC earnings from these projects to fund future donated arrays. Having an assurance that the owner will not simply redirect SMART payments in the future would be important to this arrangement. Another example is a lender to low income solar projects could have assurance that all SMART payments would be assigned directly to repay the loan with an ACH deposit directly into the loan account, vs. having the payments routed first to the system owner which leaves the door open to the SMART payments not being used for loan repayment.
A: As a condition of receiving final incentive claim validation and SMART tariff enrollment, prospective program participants will be required to submit a Payment Credit Form. Applicants will be able to designate an authorized agent to whom they would like MA SMART incentive payments to be made.
Any bill credits earned as a result of STGU production (for net metering or through the AOBC mechanism) will be required to be assigned to the EDC account of the Customer of Record associated with the STGU in question.
19. Question: How will energy export compensation work for behind the meter systems?
A: As a condition of receiving final incentive claim validation and SMART tariff enrollment, prospective program participants will be required to submit a Payment Credit Form. Applicants will be able to designate an authorized agent to whom they would like MA SMART incentive payments to be made.
The MA SMART program will not fundamentally change how distributed generation export compensation currently works under existing net metering and QF rules. These compensation mechanisms will continue to be a function of two criteria – first, whether or not a customer’s STGU qualifies for a net metering cap allocation, and then, if it does not, whether or not the STGU’s nominal AC capacity is above or below 60 kW.
In the case of behind the meter STGU’s that receive a net metering cap allocation, regardless of system size, all exports will be compensated at retail rate.
Behind the meter STGUs that do not receive a net metering cap allocation will be compensated for system exports per the terms of the relevant qualifying facility tariff with their EDC.
For STGU’s <60kW, the system’s net generation and load will be aggregated over the course of a monthly billing period, and an average QF wholesale price for that period will be multiplied against any summed net exports to determine monthly QF compensation.
For STGU’s >60kW, export volumes will be calculated on an individual interval basis, and net exports during any interval will be compensated at a QF rate (not netted against aggregate net consumption over the course of that billing period). Customers do have the option of electing to receive either a monthly average price or specific hourly pricing for these exports, but this election won’t affect the quantity portion of their retail bill or their QF compensation, just the price received for any net exports during each interval.
1. Question: Can a standalone STGU be paired with storage systems and qualify for the energy storage adder?
A: Yes, however they must both be interconnected to the utility via the same point of common coupling. Please refer to the DRAFT energy storage guideline: DOER draft guideline
2. Question: How does the billing work and how is the storage adder applied to a project? How does this impact the project economics?
A: The Storage Adder rate is calculated using the formula presented in the Energy Storage Guideline. The rate is added to the base compensation rate for the solar tariff generation unit.
3. Question: Regarding the greenfield Subtractor, the definition for “previously developed” was provided in the latest version of the SMART regulations published on 8/11/17: “For the purposes of 225 CMR 20.05(5)(e), previously developed shall mean having pre-existing paving, construction, or altered landscapes, and does not include altered landscapes resulting from current agricultural use, forestry, or use as preserved natural area.” Based on this definition, it’s unclear why a project on a site with a house, driveway, established landscaping, a well, and other alterations to the landscape would not qualify as previously developed Category 1, non-agricultural. Please explain and let us know how if there is a process to request reconsideration of these types of decisions.
A: The final determination of the Land Use category is made by DOER. The intent of the regulation is to provide a smaller incentive to projects that are proposed to be built on open, or greenfield, space. Acreage that is large enough for MW scale systems, but which only has one house is predominately open space. The intent of the previous development designation is for sites such as sand and gravel pits, former industrial sites, parking lots, or similar sites which were extensively developed in the past and have significantly altered landscapes. Lawns, pathways, and wells associated with a single house on a large property in and of themselves do not qualify as previously developed. You can request a reconsideration of the Land Use Category for the project by reaching out to the MA DOER at [email protected]
4. Question: Are there any impacts on the SMART tariff if trees are cut? If there is an impact if trees are cut, can you define whether the trees need to be fully removed/stumped by the landowner prior to engaging in solar development for a property. Specifically, would removing all the lumber for a logging business create newly developed land that would not be subject to the greenfield subtractor? Also, would a subtractor be applied to a project if any of the following occurred?:
Does it matter if the property is or is not commercially zoned property? Finally, what can classify as good cause? Does logging for agriculture use/development of dual use grazing land classify as good cause?
A: Refer to 225 CMR 20.00 Solar Massachusetts Renewable Target Program regulations. These are the regulations that define the program. Section 20.05 (5) (e) Land Use and Siting Criteria, has the information pertinent to these questions. Note that logging operations do not qualify as “previously developed” regardless of when the logging occurs. Sites that are classified as Category 2 or Category 3 will be subject to the greenfield Subtractor. Commercial zoning is the primary differentiator between Category 2 (commercially zoned; not previously developed) and Category 3 (everything that is not Category 1 or 2). There are different greenfield Subtractor rates for Category 2 and 3. As far as stumps, etc. are concerned, all projects must receive permits and approvals from all the applicable agencies. In most cases for these large projects, that includes permits indicating compliance with MA Dept. of Environmental Protection and/or Wetlands Protection Act, as well as from the local Conservation Commission. To obtain such permits, what is typically required are site plans from professional civil engineers that define site development plans including access roads, drainage plans with storm water collection basins, silt fencing, stump removal, replanting with suitable grasses or other groundcovers, safety fencing and signage on the completed project, etc. However, we suggest that you start with the local Conservation Commission to see what they may require or recommend.
5. Question: If we build a canopy-like structure for an organization over an area that doesn't qualify for canopy adder (not parking, pedestrian, or canal), can we qualify it for the building adder since it will serve as a roof for the activities under it? To qualify it as a building, would it need to have a waterproof surface and walls?
A: What you describe does not sound like it would qualify as a building and therefore would not qualify for the Adder. Rather, this sounds like an elaborate mounting system or canopy but one which is in an area not eligible for the canopy adder.
6. Question: Do you have any specific criteria to define areas that will qualify as pedestrian walkways that would qualify for the canopy adder? Would sites that have outdoor vendor events such as farmers markets or flea markets that are interested in a canopy structure over the area qualify as walkways?
A: Please refer to the definition of Canopy Solar Tariff Generation Unit in the 225 CMR 20.00 regulations; specifically, section 20.02. Pedestrian walkways must be regularly utilized by pedestrian traffic. Any application for the Canopy adder that does not clearly meet the intent of the regulations may need to be reviewed and pre-approved by DOER on a case by case basis.
7. Question: In the case of a canopy over a canal, can the solar canopy only cover the water? There are areas that are considered canals, but which do not have running water. Would those areas still qualify?
A: For questions on canal sites that include areas without water, please refer them to the SPA and the DOER on a case by case basis.
8. Question: We have a project where we plan to construct a canopy above a tree nursery where the solar system will provide shading for the plants beneath it. Would this be eligible for the canopy adder?
A: No. See the Definitions in 225 CMR 20.02.
9. Question: Does a canopy have to be over a parking lot to qualify? We have several organizations that are interested in having a canopy installed on their property, where activities other than car parking will take place such as: storage, equine riding, town fair activities like tractor pulls, etc.
A: The sites described do not qualify for the canopy adder. Please refer to the definition of Canopy Solar Tariff Generation Unit in the 225 CMR 20.00 regulations; specifically, section 20.02.
10. Question: If a solar PV system is sited on a closed landfill and the landfill land is owned by the municipality, and that project is selected in a SMART program block, is that project eligible for the landfill adder and public entity adder? Or is the public entity adder only if the municipality will be the off taker of the power?
A: As per 225 CMR 20.02, a Public Entity STGU must be owned or operated by the municipality or government entity, or the owner must assign 100% of the output of the system to the municipality or government entity to qualify for that adder.
11. Question: If a large solar PV project is developed on a parking lot and the site is located on a capped landfill, can the canopy and landfill locational adders be combined for this project?
A: No. Only one adder from each adder category may be used for any given project. You can combine adders from different categories such as Location Based + Off-Taker Based, but not two or more within the same category on the same project.
12. Question: Does each location-based adder have its own independent 80 MW tranche? Or do all of the adders move collectively from tranche to tranche?
A: Yes, each Adder has its own 80 MW tranche and they will fill and move independently.
13. Question: If a potential project with a municipal landfill contains different solar arrays that each fulfill a different location-based adder, how would this be treated in the SMART Program? One portion of the project is on the landfill itself (landfill adder), another portion of the project is on a municipal building (rooftop adder) on the same parcel, and the third portion of the project would be solar carport on an adjacent parking lot, also on the same parcel (canopy adder). It is understood that each array can only use one location-based adder, but for a project like this, different portions satisfy different adders independently, what is the protocol? Would we apply a weighted average based on the portions that of the project that independently qualify for different adders?
A: This may qualify for an exemption from the Project Segmentation Rules. If so and approved this could be submitted as three separate applications for the site. See section 20.05 (5)(g)(2) on page 8 of the SMART program regulations for more details. To apply for an exemption from the Project Segmentation Rules, contact DOER at [email protected].
14. Question: If we have a property and want to build a rooftop solar system and a solar canopy over the parking lot or a ground mounted PV on the property and want to lease out the whole system can we do that as a stand-alone system on a single meter as a new service? If yes, will the adders be applied to the entire project or would the incentive be lessened/based on the lowest rate, or would there be some sort of average applied to the overall production? Finally, will we be OK to file one interconnection application for these types of sites with two or more types of projects?
A: The Project Segmentation rules in 225 CMR DOER regulations [20.05 (5) (f)] include several standard Exceptions in section [20.05 (5) (g)]. Specifically, what is described would be Exception (2) which allows multiple STGUs on the same parcel if they are a building mount and another type such as Canopy or ground mount, providing they are separately metered. So, while each of these sub- systems or configurations would be eligible to participate in MA SMART, each would require its own inverter and metering.
Additionally, in order to reflect the differential incentive rate that would be applied to each sub-system’s output, a separate MA SMART incentive application, which will ultimately result in a unique Statement of Qualifications from DOER, should be submitted for each sub-system.
Questions on how best to apply for and manage the interconnection of these systems to the electrical grid should be directed to the relevant EDC, based on the proposed location of your STGU.
15. Question: My company is contemplating the construction of a 1.5 MW solar PV array on a municipal landfill and considering selling some of the energy to the municipality and the rest to community solar customers. What is the credit that the municipality would receive as a Public Entity and what would the Community Solar customers receive? Would it be a blended rate?
A: First of all, for the Public Entity adder, the STGU must be located on public property and 100% of the energy generated must be provided to a public entity. In this case, the municipal landfill would likely qualify as public property, but you could not provide some of the energy to the municipality and the rest to a community solar project to qualify for that adder. Secondly, only one Adder can be claimed per generation unit category on any given project. Public Entity and Community Solar are both adders in the Off-Take category, so you would have to pick one.
1. Question: Regarding institutional subscribers to community solar projects, under the Alternative On-Bill Credit (AOBC) system, if the anchor off-taker is currently in a 3rd party energy supply contract but still receives delivery from the distribution company in which the project is interconnected, can they use the on-bill credits? If so, does the credit get applied to their payment to the third-party supplier or just the delivery charges (T&D) from the utility? Does this depend upon whether the customer has a 3rd party supply contract with combined billing versus if the 3rd party supplier bills the customer separately?
A: It depends on the type of billing a customer utilizes with a retail supplier. If the allocatee customer’s supplier is using complete billing with Eversource the credits that are allocated are shared with the supplier portion of the bill. If the allocatee’s supplier opted for pass through billing the Company would only be able to apply credits to the distribution portion of the bill.
2. Question: What is the definition of a "sufficient" subscriber base in order for an STGU to qualify for the Community Solar Adder?
A: A STGU seeking a Community Shared Solar adder, or a Low Income Community Shared Solar adder must show they meet the definition to qualify for the adder, and must demonstrate that no individual or distinct legal entity will receive bill credits or electricity in an amount that exceeds the applicable limits. For example, Community Shared Solar must have three or more Customers of Record and no more than two participants may receive bill credits in excess of those produced by 25 kW of nameplate AC capacity and the combined share of said participants capacity cannot exceed 50% of the total capacity of the STGU, except in cases of STGUs smaller than 100 kW AC. For Low Income Community Shared Solar, at least 50% of the energy output must be allocated to Low Income Customers. Documentation provided at the project completion phase must sufficiently demonstrate that these Program requirements have been met.
Upon interconnection and application for final enrollment in the tariff, the Community Solar Project must be at least 90% subscribed to be eligible to qualify for the adder.
3. Question: When in the application process must STGUs demonstrate that they have a sufficient subscriber base to qualify for the Community Solar Adder?
A: There are two phases to the application process: Application and Claim. At the Application phase, the Applicant indicates their intention and plans for a Community Solar. If approved, the Applicant will receive a preliminary Statement of Qualification and will have a 12 month Reservation Period to complete their project. During the Reservation period, in addition to construction the STGU, the Applicant needs to finalize their off-taker subscribers and obtain the necessary signed Customer Disclosure and other forms. During the Claim phase, the Applicant submits copies of all the project completion documentation including the signed Customer Disclosure forms, Off-taker list, and other forms such as Schedule Z or Payment Credit Transfer forms to either the interconnecting utility and/or to the SPA. At the Claim phase, all the required off-taker subscribers should be signed up and documented. If these forms are not provided at Claim, the Applicant will not be eligible for the Adder.
4. Question: For the current awardees from the SMART program, can you tell me if any of the 17 projects awarded from the Block 1 RFP are community solar projects?
A: Projects that qualified under the Block 1 RFP were not eligible to receive any of the compensation rate adders which included not being eligible for the community solar adders.
1. Question: For the Energy Storage Adder, the requirements are that the batteries need to cycle at least 52 times per year. Does the system owner handle the cycling of the battery? If not, who is controlling the storage system? Can the storage be controlled and used by the system owner to provide any additional grid services beyond the SMART Requirements? Or will it be controlled, or owned, by the utility?
A: These questions are still subject to a determination in the SMART Tariff ruling at the DPU.
2. Question: Is Net-Energy Metering from battery storage in allowed in MA with the SMART Program?
A: The question of net metering with battery storage is currently being determined in the DPU docket 17-146. The determination by the DPU in that docket will dictate eligibility in MA.
3. Question: Since the Energy Storage Adder is based on the kWh production, is this based on the total or gross PV production? For example, if a 1MW solar array produces 1,200,000 kWh (AC) per year, and it is coupled with a 548kW/1096 kWh battery that results in net production after battery cycling losses of 1,100,000 kWh, does the system earn incentives based on the total/gross production or the net production? Also, is the Adder applied to the entire amount or only to the battery discharge amounts?
A: The energy storage adder is applied to the total PV production, in addition to whatever base compensation rate the PV portion is eligible for.
4. Question: For a project that was awarded through the Block 1 competitive RFP, is it possible to add energy storage to take advantage of the Energy Storage Adder (even though the award was just for base compensation solar)? If so what is the process and timelines?
A: No, the Block 1 competitive RFP was explicitly for projects not seeking adders. A project granted an award in the Block 1 Competitive RFP may not qualify for any adders under SMART.
5. Question: Once SMART opens and begins issuing Statements of Qualification, is it possible to add energy storage later in the process? If so what needs to be done and does this change their qualification or place in the queue or block?
A: If this is decided during the Reservation Period, the Applicant can submit a new application for the Energy Storage via the online application portal. This will require another application fee, plus all the applicable forms and documentation of the SMART program. If the PV system size, schedule, and other characteristics are not changing, that project will not lose its place in the assigned Block. The Energy Storage however will be assigned a value from the available tranche at the time of the storage application.
6. Question: Is it possible to add energy storage to existing solar projects from SREC II or earlier and apply for the energy storage adder through SMART?
A: No, the Energy Storage Adder is only available when combined with SMART solar projects.
7. Question: If the solar facility is coupled with an Energy Storage System, will the project owner be paid based on the kWhs (AC) produced regardless of whether the energy generated is passed through a battery prior to the inverter? If the Solar Facility and the Energy Storage System use a 1 meter system that is located after the point of common coupling, would the energy storage adder be applied to the net energy of the two systems?
A: Please refer to the Energy Storage Guideline for the details regarding these systems. Every SMART system will be required to have generation production meter that records the net AC output of the system. The SMART incentive will be in the form of a cents/kWh value in AC of the system. So, in the system described above with both the PV and the battery on the DC side of the inverter, the incentive would be based on the net AC coming out of the inverter, not the DC output of the PV panels. Regardless of where the meter is located, providing the PV and the storage system meet the SMART definition of co-located (the Solar Tariff Generation Unit and the Energy Storage System must share a common point of coupling), the Energy Storage Adder is applied to the cents/kWh incentive rate. That rate is applied to net AC energy output of the system.
8. Question: When looking at potential PV Solar systems with energy storage for residential customers the most economical solution we are finding is the pairing of a [specific] battery systems with a [specific] inverter. However, the battery manufacturers and the inverter manufacturers provide conflicting information on whether these system combinations would qualify for the storage adder. Additionally, they have concerns about whether two hours of discharge would be available as required in the SMART regulations. Each manufacturer suggested different interpretations of whether the battery adder can be applied for this reason. Can someone please clarify what numbers can be used to make the correct determination?
A: This issue was discussed by the Energy Storage Working Group and a new Energy Storage Guideline will be published by DOER to provide additional clarity on this topic and guidance for designers.
9. Question: Can a SMART STGU System Owner of a STGU that is already installed add a battery later (post-PV system completion) to that STGU system and qualify in SMART for the battery adder?
A: Yes, providing there is still funding available and all other SMART Program requirements are met. Such a project will need to submit a second application to the Program and obtain a Statement of Qualification for the battery system. The Battery Adder rate will be what is available at the time of the new, battery application and the incentive term of the battery will end concurrent with the original STGU term (after the original 10 or 20 years).
1. Question: How is project segmentation applied on a property/parcel with multiple buildings? For example, if we want a 250 kW AC roof top on one building and a 500 kW AC roof top on a separate building but where both are on the same parcel of land, would this be prohibited by the project segmentation rules? If not, what is the process to apply?
A: The Project Segmentation rules in 225 CMR DOER regulations [20.05 (5) (f)] also have several standard Exceptions in section [20.05 (5) (g)]. Specifically, what is described sounds like it would be Exception (2) which allows multiple units on the same parcel if the buildings are separately metered. If the site or campus is on a master meter and the buildings are not individually metered by the utility, you would need to request an Exception (7) which is for good cause.
Whichever Exception is the case, to apply for the two projects will require separate applications in the online portal and each will receive individual Statement of Qualifications from MA DOER. During the application process you will be asked to identify which Exception applies to your project. Also, each system will need its own generation/production meter for reporting purposes. However, both systems can be on the same utility ISA and/or can be interconnected at the same point.
To apply for two projects such as this will require separate applications in the online portal and each will receive individual Statement of Qualifications from MA DOER. During the application process you will be asked to identify which Exception applies to your project. Also, each system will need its own generation/production meter for reporting purposes. Both systems can be on the same utility ISA.
2. Question: In the scenario of a single parcel of land containing a residence and a working farm with large barn outbuildings that are separately metered and owned by the same people, but the barn roof is the best location for a solar installation for both the residence and the farm, can we interconnect one PV system as a net metered behind the meter project, and a second PV System as a behind the meter qualifying facility? If yes, this appears on paper to violate the project segmentation rules so how would we apply?
A: The situation described does not neatly fit into a one of the established standard Exceptions of the Project Segmentation rules in in 225 CMR section [20.05 (5) (g)]. Such applications should be sent to MA DOER at [email protected] with a request for a good cause exemption explaining the situation. If approved, the two systems described would need to apply for separate Statements of Qualification (SFs).
3. Question: In the Land Use Guideline published by the DOER, the description of the requirements for Category 1 of Land Use, there is a case where the property is participating in the Chapter 61A tax incentive program. The Guideline establishes that if the parcel is part of this Chapter 61A program and had enrolled in it within the last 5 years, there are only specific types of projects that will be allowed to apply for the SMART program. Questions related to this are:
A: In the Land Use Guideline published by the DOER, the description of the requirements for Category 1 of Land Use, there is a case where the property is participating in the Chapter 61A tax incentive program. The Guideline establishes that if the parcel is part of this Chapter 61A program and had enrolled in it within the last 5 years, there are only specific types of projects that will be allowed to apply for the SMART program. Questions related to this are:
4. Question: Does a solar facility itself have to be located in the Commonwealth of Massachusetts, or just interconnected to its grid? For example, if a solar farm is located just on the state line with NY/VT/CT but interconnects with National Grid/Eversource on the MA side of the state line, would that project qualify for SMART?
A: The project has to be physically located in MA to be eligible for the SMART Program. Also, it must be interconnected to the local, Massachusetts distribution system of one of the participating electric utilities (Eversource, National Grid, or Unitil) which is regulated by the Massachusetts Department of Public Utilities. It cannot be directly interconnected to the high voltage transmission grid that is regulated by FERC.
5. Question: We have an operational 1+ MW community site under SREC II. Our meter is at the street, and the site is about 1,500 off the street and connected via a privately-owned power line. We have room at the site to add a 650kW SMART community project, but it would be cost-prohibitive to build a second power line to the street for a separate interconnection. Can we share the same line, and place two meters at the street, or if we can move the utility meter from the street back to the site and install two meters there so that SMART and SREC II are metered separately? I’m assuming the latter is more likely for reporting and data accuracy?
A: You would have to demonstrate the SMART portion of the project was built in a such a way that you could install the generation production meter to only take a reading from that portion of project. Theoretically this could be done, but the Applicant should confirm this with the utility interconnection team to make sure the engineering design proposed makes sense.
6. Question: How would a scenario of multiple carport arrays, each separately metered and on separate but contiguous parcels, be treated? I don’t see a specific exception that is spelled out which these projects might fall under.
A: Canopies are subject to the project segmentation rule. Unless the installation of a canopy meets the current established exemption of allowing a canopy on the same parcel as a building mounted project or a ground mounted project, the applicant must submit a good cause exemption request to the DOER at [email protected] for review and determination.
7. Question: Regarding 225 CMR 20.05 section (5) subsection (f) on project segmentation, how would that apply to five parcels of land that have good adjoining space for solar. Would this regulation allow for a standalone system to be built with 7 sub arrays trenched to the new service?
A: Project Segmentation rules also have some standard exceptions. Exception 20.05 (5) (g) (5) could apply in this case as long as the 7 sub arrays are interconnected behind a single point of interconnection, and you get an approved ISA from the utility for that interconnection.
1. Question: How do I find the service territory separating NSTAR and WMECO (both Eversource)?
A: MassGIS provides a map of electric distribution service territories at the following location: http://www.mass.gov/anf/docs/itd/services/massgis/electricity2015.pdf
2. Question: Are there any webinars or meetings set up anytime soon that we can attend?
A: As we get closer to the program launch date we expect to hold seminars and/or webinars. As these sessions are planned and developed, they will be announced on the SMART Program website at http://masmartsolar.com
3. Question: How does one sign up to receive DOER email updates related to RFP’s and general program information issued by DOER? Put another way, where is the sign-up for DOER’s mailing list?
A: Sign up through this link https://signup.e2ma.net/signup/1374704/1356542/?v=a to get on the DOER email list. You should request to be on the “Solar PV contact list”.
4. Question: Is it possible to be an owner of a system for this program if you have no prior experience with solar? If a building owner wants to have complete ownership of a PV system and participate in the SMART program, could they do so?
A: There are no restrictions on who owns the PV system. That said, the SMART Program is designed for experienced, highly qualified solar developers. It is highly recommended that an owner with little or no solar experience hire or partner with an experienced, highly qualified solar developer.
5. Question: Would DOER consider granting a good cause extension for legal issues that prevent an STGU awarded under the SMART Procurement from meeting the 12-month construction deadline? For example, if the project was appealed by abutters after submission of the project application to the SMART Program, would that qualify as a good cause for an extension?
A: The 12-month construction deadline ‘clock’ doesn’t start until the Statement of Qualifications is issued and/or the official SMART Program Effective Date, whichever comes later. Once the clock starts, awarded bidders may request an extension if there is such a legal challenge ongoing that may delay the project. By that point, we will have a fully established SQA Application Guideline outlining appropriate cause for extensions. The situation described above would appear to meet the legal requirements for such an extension, but DOER can’t officially make a determination and/or extend such an extension until the deadline is established and, an awarded bidder makes a formal extension request.
6. Question: Do you have a list of everyone/all projects who bid in the initial solicitation?
A: The submissions to the Block 1 competitive RFP were confidential. However, the selected bidders have been publicly announced. That information is available at www.masmartsolar.com.
7. Question: What is the procedure for minor changes in DC capacity after a Statement of Qualifications has been issued? Often module availability is different at the construction phase than what was planned during the design phase.
A: Minor or de minimis changes to the DC capacity are allowed as long as the AC output does not increase beyond what was approved for the Statement of Qualifications. A change that would increase the AC output would disqualify the project from the SMART Program and/or would require withdrawal and re-application for the new, larger system size. Reductions in AC size and/or minor changes in the DC capacity of the panels can be recorded in the PowerClerk system upon project completion.
8. Question: Are there any warranty requirements under the SMART Program such as workmanship, inverter and/or PV panel minimum warranties that must be given to customers from their contractor, installer, or developer?
A: There are no warranty requirements to qualify for SMART. However, on the Customer Disclosure forms for third party and direct owned small systems, it is required that the customer be informed of the contact for ongoing system maintenance.
9. Question: Are there any prevailing wage or labor rate requirements for projects awarded an incentive under the SMART program?
A: The SMART Program does not have any such specific requirements. However, if the Applicant or Host site is subject to such requirements, participation in the SMART Program does not necessarily waive or remove those requirements.
10. Question: Under the SMART program final regulations, does it matter what voltage a stand-alone solar facility connects to? For example, could a project connect to a 69kV or 115kV line owned by one of the EDCs and still be eligible to participate in SMART so long as the project is within that EDC service territory? Or is it necessary to connect to a distribution level voltage, and how would that voltage level be defined?
A: SMART Program supported systems must interconnect to distribution lines that are owned and operated by one of the eligible EDCs, are within existing service territories of the EDCs as of January 1, 2018 and serve retail electric loads. Standalone systems may interconnect to a 69kV or less line as long as it is part of the distribution system that is regulated by Massachusetts regulators and serve retail electric loads. However, direct interconnection to transmission lines that are regulated by FERC is not allowed within the SMART Program regardless of the voltage of the transmission line.
11. Question: If our application is approved to construct a large PV system for the SMART program, are there any clauses in the agreement or rules in the program that would prevent investors to obtain Investment Tax Credits (ITC)?
A: We are unable to provide information about qualifying for the federal tax credit. Applicants should speak with a tax professional or directly with the Internal Revenue Service which handles the ITC. That said, there are no references, controls, or rules regarding the ITC in the SMART program rules, nor is the potential qualification for the ITC considered in any way during the application review process for the SMART Program.
12. Question: Does the program require third-party reporters or authorized data providers to submit monthly production reports? If so, are you able to provide information on how to apply? Is there a set of requirements for the type of hardware used in collecting data? Is there an application process for having hardware approved for the SMART program? What data needs to be submitted, and how often?
A: The SMART Program does not require third-party reporters - responsibility for metering, recording and reporting STGU production in the SMART program lies with the utilities. The EDCs will be making the purchasing and specification decisions and will be installing the revenue grade meters themselves or via their own selected sub-contractors. Participation in the SMART program will require that installers provide the necessary wiring and meter sockets necessary to support the utility installation of these utility owned-operated generation meters, however, and applicants whose system configurations require the installation of utility generation meter(s) for MA SMART purposes will be assessed fees by their EDC for the installation of this (these) meter(s).
13. Question: Do you know if SMART projects will appear in the Class-I Qualified Units List? Or will the SMART SQA (or equivalent) be the only place these projects are listed? For entities that track and forecast Class-I Generation, how can they be assured that they won’t be double counting when SMART qualifications start coming in.
A: MA DOER is planning to post a separate SMART qualified units list.