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Bear Valley Solar InitiativeProgram Handbook
FIRST EDITION
Powering the Mountain since 1929.
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Contents
1. Introduction: Bear Valley Solar Initiative Program (BVSI) .............................................................................. 2
1.1. Program Overview .............................................................................................................................................. 21.2. Program Targets, Incentive Levels and Budget .................................................................................................. 4
2. BVSI Rules and Requirements ........................................................................................................................ 4
2.1. Participant Classifications ................................................................................................................................... 5
2.1.1. Applicant ............................................................................................................................................... 5
2.1.2. Host Customer ....................................................................................................................................... 5
2.1.3. System Owner ....................................................................................................................................... 5
2.1.4. Contractor ............................................................................................................................................. 5
2.1.4.1. Suspended License Contractor ............................................................................................................ 6
2.1.5. General Eligibility Guidelines ................................................................................................................. 6
2.2 System Equipment Eligibility ................................................................................................................... 7
2.2.1. New Equipment, Not Pilot or Demonstration Systems ......................................................................... 7
2.2.2. Equipment Must Serve On-Site Electrical Load ..................................................................................... 7
2.2.3. System Size ............................................................................................................................................ 8
2.2.4. System Sizing Based on Future Load Growth ........................................................................................ 8
2.3. Energy-Efficiency (EE) Requirements ........................................................................................................... 8
2.4. Warranty Requirements ..................................................................................................................................... 9
2.4.1. Performance and Permanency Requirements ...................................................................................... 9
2.5. Metering and Monitoring Requirements ......................................................................................................... 10
2.6. Measurement and Evaluation Requirements .................................................................................................. 11
3. BVSI Incentive Structure .............................................................................................................................. 11
3.1. BVSI Incentive Trigger Mechanism ................................................................................................................... 11
3.2. Expected Performance Based Incentive (EPBI) ................................................................................................ 12
3.2.1. EPBI Calculator Modifications ............................................................................................................. 12
3.2.2. Rebate Limitations ............................................................................................................................... 12
3.2.2.1. Total Eligible Project Costs ................................................................................................................ 13
3.2.2.2. Reportable Project Costs ................................................................................................................... 14
3.2.3.3. Other Incentives or Rebates .............................................................................................................. 14
3.2.3.4. Right to Audit Final Project Costs ...................................................................................................... 143.2.3.5. Site and Host Customer Limitations .................................................................................................. 15
4. Application and Payment Processes ............................................................................................................ 15
4.1. Rebate Claim and Payment Processes ............................................................................................................. 16
4.1.1. Submit Rebate Claim Package ............................................................................................................. 16
4.2.Rebate Claim Package ...................................................................................................................................... 16
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4.2.2. Printout of EPBI Tool Calculation ........................................................................................................ 17
4.2.3. Performance Monitoring & Reporting System (PMRS) ....................................................................... 17
4.2.4. Copy of Executed Agreement of Solar Energy System Purchase and Installation or Copy of Executed
Alternative System Ownership Agreement (If System Owner is Different from Host Customer)................. 17
4.3. Circumstances Requiring Additional Documentation ...................................................................................... 19
4.3.1. Owner or Self-Installed System ........................................................................................................... 194.4.1 Rebate Check Payment and Terms ....................................................................................................... 19
5. Field Inspections .......................................................................................................................................... 20
5.1. Key Project Components Reviewed During Onsite Field Inspection ...................................................... 20
5.2. Acceptable Range of Parameters for Key Project Components Reviewed During Inspection ............... 21
5.3. Issuance of Infractions ............................................................................................................................ 22
5.4. Issuance of Failures ................................................................................................................................ 22
6. Notifications, Sanctions and Dispute Resolution ......................................................................................... 22
6.1. Grounds for Immediate Disqualification from the Program .................................................................. 236.2. Notifications and Sanctions .................................................................................................................... 24
7. Process for Removal from Program ............................................................................................................. 24
7.1. Removal from Program for Excessive Failures ....................................................................................... 24
7.2. Removal from Program for Immediate Disqualification ........................................................................ 24
7.3. Dispute Resolution ................................................................................................................................. 24
Technical Section ....................................................................................................................................... 25
8. Metering Requirements............................................................................................................................... 25
8.1. PMRS Service Requirement .............................................................................................................................. 25
8.1.1. Minimum Communication Requirements ........................................................................................... 25
8.1.2. Minimum PMRS requirements ............................................................................................................ 25
8.2. Minimum Metering Equipment Requirements ................................................................................................ 26
8.2.1. Meter Type .......................................................................................................................................... 26
8.2.2. Meter Measurement and Time Granularity of Acquired Data ............................................................ 26
8.2.3. Meter Display ...................................................................................................................................... 26
9. Equipment Certification, Rating Criteria & Design Factor Calculations ........................................................ 27
9.1.Equipment Certifications and Rating Criteria ................................................................................................... 27
Appendices .................................................................................................................................................... 28
Appendix A: Definitions ...................................................................................................................................... 28
Appendix B: Additional Requirements and Terms ............................................................................................... 35
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1.Introduction: Bear Valley Solar Initiative Program
(BVSI)
Bear Valley Electric Services(BVES) Solar Initiative Program (BVSI) provides
financial rebates for the installation of grid-interconnected eligible solar photovoltaic
(PV) systems. This Guidebook describes the requirements to receive incentives for
installations conducted within the BVES territory.
The goal of the Program is to contribute to the growth and sustainability of the
solar industry in California. BVESgoals include the addition of 800 kilowatts (kW)
of new PV generation capacity for residential customers in their service territory. In
addition to the renewable energy generation component, the Program leverages theeffectiveness of energy efficiency measures. Incentives will be available January 1,
2015 through December 31, 2022, or until the BVSI incentive budget has been fully
utilized, whichever comes first.
1.1. Program Overview
The BVSI is available to qualified existing residential homes for solar photovoltaic
systems. For all projects, energy efficiency, the expected performance of the
system, as well as the design and installation of the system, will determine the
incentive amount.1
Pursuant to the California Public Utilities Commission Decision D.14-11-002, the
BVSI will incorporate many elements of the California Solar Initiative (CSI)
program,2but will deviate in certain aspects to provide a cost effective program
suited to the characteristics of BVEScustomer base.
All systems will be paid an upfront rebate calculated by BVSIs Expected
Performance Based Incentive (EPBI) Calculator once the system is installed,
operational and has met all program requirements.
1Expected performance is the anticipated electrical generation over the life of the system and depends onequipment specifications including efficiency.2The California Solar Initiative program pays incentives to solar photovoltaic (PV) projects in the three CaliforniaIOU service territories: Pacific Gas & Electric, Southern CA Edison and San Diego Gas & Electric. The program wasauthorized by the California Public Utilities Commission (CPUC) and Senate Bill 1 (SB 1) with a goal to install 1,940MW of new solar generating capacity in California by 2016.
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To qualify for an incentive, both the building and the installed PV system must meet
the following program requirements included in this Guidebook:
The residence must receive retail electricity distribution service at the site of
installation from BVES.
The solar electric system must be at least 1kW CEC-AC and will be
incentivized up to 50kW CEC-AC.
The solar electric system must be interconnected to the utility distribution
grid and generate electricity to offset the end-use consumers on-site
electrical load.
The solar electric system must be located on the same premises of the end-
use consumer where the consumers own electrical demand is located.
The solar electric system must use new certified components that have not
been previously placed in service and are on the California Energy
Commissions list of eligible equipment3.
The solar electric system must include a 10-year warranty to protect against
defects and undue degradation of electrical output.
The solar electric system must be installed and verified as specified in this
Handbook.
Residential homes must be in existence or considered retrofit and not new
construction. The CEC separately administers the New Solar Homes
Partnership (NSHP) Program for residential new construction, with a separate
program handbook.
Existing residences must also attend to energy efficiency. The minimal
requirements include acknowledgement of energy efficiency cost savings, energy
efficiency audits provided by third parties and programs available through the
BVES.
3See: http://gosolarcalifornia.ca.gov
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1.2. Program Targets, Incentive Levels and Budget
Table 1: Adopted Incentive Structure, Capacity Allocations and Budget per Step4
Total BVSI Budget
StepsIncentive
Rate ($/watt)
Capacity
(kW)Incentive Budget
Administrative
BudgetTotal Budget
1 $1.60 155 $248,000 $105,000 $353,000
2 $1.30 180 $234,000 $70,000 $304,000
3 $1.09 215 $234,350 $80,000 $314,350
4 $0.94 250 $235,000 $80,000 $315,000
TOTALS 800 $951,350 $335,000 $1,286,350
Table 1 shows the kW targets by step. The incentive levels available through the
BVSI are divided into four steps. Each step is for a targeted amount of kW. The
incentive levels available reduce automatically over the duration of the program
based on the kW volume of solar reservations issued. Projects are counted toward
the kW goals once they are deemed eligible upon completion of the installation,
interconnection and approval of rebate claim documentation. The most current
status of applicable incentive levels available in the BVES territory will be available
on the BVSI website, www.BVES-Solar.com.
The total BVSI budget for eight years is $1,286,350 million. 26% of the budget is
earmarked for costs associated with administration of the program.
2.BVSI Rules and Requirements
Any residential retail electric distribution customer of Bear Valley Electric Service
(BVES) is eligible to install a solar energy system and receive incentives from the
BVSI. Eligible participants in the BVSI must be current electric distribution
customers of BVES at the project site where the system will be installed. Within the
nomenclature of the BVSI, the person who applies for an incentive is referred to as
the Applicant. Most often, but not always, the Applicant is either the Host
Customer or the installation Contractor. Other participants and designations
include System Owner, Third-Party Owner, Third-Party Lessor and Equipment
Seller.
4Pursuant to California Public Utilities Commission Decision (D.14-11-002)
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2.1. Participant Classifications
2.1.1. Applicant
The Applicant completes and submits the BVSI Rebate Claim and serves as the
main contact for the Program Administrator. Host Customers may act as the
Applicant or they may designate another party to act as the Applicant on their
behalf such as, but not limited to, engineering firms, solar contractor, equipment
distributors, energy service provider (ESP) and equipment Lessors.
2.1.2. Host Customer
The Host Customer is an individual or entity with 1) legal rights to occupy the site,
2) receives retail level electric service from Bear Valley Electric Service, 3) is the
utility customer of record at the site, 4) is connected to the electric grid, and 5) is
the recipient of the net electricity generated from the solar equipment. The HostCustomer alone will retain sole rights to the incentive and corresponding
incentive number. The Host Customer has the right to designate the Applicant,
energy services provider and/or Solar Contractor to act on their behalf.
2.1.3. System Owner
The System Owner is the owner of the generating equipment at the time the
incentive is paid. For example, when a vendor sells the solar generating equipment
and installation (generally defined as a turnkey system) to a Host Customer, the
Host Customer is also the System Owner. In the case of a third-party-ownedsystem (or leased system, for example), the third party (or Lessor) is the System
Owner.
The System Owner should be designated on the Rebate Claim. The Program
Administrator (PA)will require documentation substantiating equipment
ownership.
2.1.4. Contractor
Except for those systems that are self-installed, all systems must be installed by an
appropriately licensed California contractor in accordance with rules and regulations
adopted by the State of California Contractors State Licensing Board (CSLB). Solar
installation contractors must have an active A, B, C-10, or a C-46 license for
photovoltaic (PV) systems.
Systems must be installed in conformance with the manufacturers specifications
and with all applicable electrical and building codes & standards.
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The PA will verify that the Solar Contractor has an active license with the California
Contractors State Licensing Board (CSLB), in accordance with the above
requirement, during the application review process.
Self-installed systems are allowed to participate in the BVSI.
2.1.4.1. Suspended License Contractor
If it is determined that a contractors CSLB license is suspended when Rebate Claim
funds are requested, no incentive payment will be made. If the Contractor appeals
and submits a written explanation citing reasons for the suspension, the PA will
determine whether the project can be paid incentives or whether the project is
ineligible to be paid incentives. If the project is deemed to be payable, the PA, in
most cases, will only pay the Host Customer for the project.
2.1.5. General Eligibility Guidelines
The following Customer segments and associated Project sizes are generally used to
determine incentive types, application processes and Program eligibility:
Residential: All project sizes 1kW up to 50kW CEC-AC, retrofit only,
designated by a BVES Residential rate schedule.
The following are noteligible for incentives:
Customers who have entered into utility contracts for distributedgeneration (DG) services (e.g., DG installed as a distribution upgrade or
replacement deferral) and who are receiving payment for those services.This does not include third-party ownership arrangements, i.e., powerpurchase agreements, which are allowed.
Customers who have entered into agreements that entail the export andsale of electricity from the Host Customer Site. This does not include netenergy metering agreements, which are allowed.
Customers who have received a final interconnection authorization lettermore than 12 months prior to submitting the Rebate Claim for eligibilityconsideration.
Customers who have received gifted or donated systems, where theBVSI incentive exceeds the total amount paid by the Host Customer are
not eligible.
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2.2 System Equipment Eligibility
Solar PV systems (i.e., systems that cause direct conversion of sunlight to
electricity) are the only technology to receive incentives through BVSI5. Details of
the eligibility requirements for system equipment follow.
2.2.1. New Equipment, Not Pilot or Demonstration Systems
All major system components (panels and inverters) must not have been previously
placed in service in any other location or for any other application. Rebuilt,
refurbished, or relocated equipment is not eligible to receive incentives.
Components that are critical to PV systems must have at least one year of
documented commercial availability to be eligible for BVSI. Commercially available
means that the major solar energy system components are acquired through
conventional procurement channels, installed and operational at a Project Site.System component ratings must be certified by the California Energy Commission.
Ineligible equipment includes field demonstrations or equipment completely paid for
by research and development funds. Pilot and demonstration systems are ineligible
for BVSI.
2.2.2. Equipment Must Serve On-Site Electrical Load
For purposes of the BVSI the system must be sized so that the amount of electricity
produced by the system does not exceed the Host Customers electrical needs at
the Project Site.6System size evaluation will be based on the past 12 month
electricity usage of the Host Customer. If the Host Customer has not acquired at
least 12 months past usage at the residence, or in cases where historical load
cannot be determined due to extensive remodeling, the Load Justification Form
must be submitted for systems 5kW or greater. For systems without 12 month
historical data that are less than 5kW, on-site electrical load may be determined
using the calculation of 2 watts per square foot of the home. While systems 5 kW or
less are exempt from load justification for the purposes of the BVSI, BVES retains
the right to perform a system size analysis to ensure systems are not oversized.
In addition, to further support customer adoption of energy efficiency, the BVSI
incentive for a system greater than 5kW is capped at 90% of the Host Customers
5 Pursuant to California Public Utilities Commission Decision D.14-11-002. Non-PV systems, including solar hotwater systems are not eligible to participate in the BVSI6Section 2827(b)(4) of the California PU Code includes the statement that the system is intended primarily tooffset part or all of the customers own electrical requirements. Systems that are sized largerthan the customerselectrical requirements would not be eligible for BVES NEM.
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calculated energy consumption over 12 months at the Project Site7. For Sites
without a 12 month kWh usage history, the maximum incentive will be 90% of the
estimated annual usage.
2.2.3. System Size
The minimum system size eligible for an incentive is 1kW CEC-AC. The maximum
incentive provided for a Host Customer Site under the BVSI is 50 kW CEC-AC8;
however, a Host Customer Site may elect to install up to 1 MW per BVES Net
Energy Metering rules.
The CEC-AC system size is calculated by using the CEC-AC rating standards,9
including inverter DC-to-AC losses. To calculate the CEC-AC rating, the following
formula should be used:
CEC-AC Rating (kW) = Quantity of Photovoltaic Modules x CEC Rating of
Photovoltaic Modules x CEC Inverter Efficiency Rating/ 1000 (watts/kilowatt)
The BVSI rebate will incorporate the design factor, or system tilt, azimuth,
mounting method and shading into the overall system performance calculation. To
calculate the BVSI rating which will determine the BVSI incentive, the following
formula will be used:
BVSI Rating = CEC-AC system size rating x Design Factor
2.2.4. System Sizing Based on Future Load Growth
In the case of Host Customers with new or expanded sites with no electric bill
history or where the existing electric bill does not reflect the Customers expected
expanded consumption, the Applicant is required to submit a completed Load
Justification Form found on the BVSI website. Sites without a 12 month usage
history will receive a maximum incentive of 90% of the estimated annual usage.
2.3.
Energy-Efficiency (EE) Requirements
The Host Customer is required to complete, sign and submit to the PA the Rebate
Claim Form, which confirms the project details, rebate payee and authorizes the PA
to access Host Customer energy consumption data for review. The online
application will ask the applicant to list any EE measures completed before solar
implementation.
7Pursuant to California Public Utilities Commission Decision D.14-11-0028Pursuant to California Public Utilities Commission Decision D.14-11-0029 CEC- nce, 20Cambient temperature, and 1 meter/second wind speed. The CEC-AC watt rating is lower than the Standard TestConditions (STC), a watt rating used by manufacturers.
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2.4. Warranty Requirements
All solar energy systems that receive an incentive must have a warranty of no less
than 10 years to protect against defects and undue degradation of electrical
generation output.
All solar energy equipment for electricity generation (PV modules, inverters,
solar collectors, tracking mechanisms, heat exchangers, pumps, and heat
driven cooling systems) shall have a minimum 10-year manufacturer
performance warranty to protect against degradation of electrical generation
output of more than 15% from their originally rated electrical output.
All contractors shall provide a minimum 10-year warranty to provide for no-
cost repair and replacement of the system for any expenses not otherwise
covered by the manufacturer.
All contractors shall provide a minimum 10-year warranty to protect the
purchaser against more than a 15% degradation of electrical generation
output that may occur as a result of faulty installation.
For self-installed systems, the warranty need not cover the labor costs
associated with removing or replacing major components because any
repairs would be done by the self-installer or at the self-installers expense.
Meters must have a one-year warranty to ensure against defective
workmanship, system or component breakdown, or degradation in electrical
output of more than fifteen percent from their originally rated electrical
output during the warranty period. For meters that are integrated into the
inverter, the meter warranty period must be 10 years.
2.4.1. Performance and Permanency Requirements
Equipment installed under the BVSI is intended to be in place and interconnected to
the utility grid for the duration of its useful life. Only permanently installed systems
are eligible for incentives. Physical permanence is to be demonstrated in
accordance with industry practice for permanently installed equipment. Equipment
must be secured to a permanent surface. Any indication of portability, including but
not limited to temporary structures, quick disconnects, unsecured equipment,
wheels, carrying handles, dolly, trailer, or platform, will deem the system ineligible.
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The BVSI will allow the installation of approved hinge release technology if required
by local building and permitting agencies to maintain the integrity of the solar
system while also satisfying the program requirement of permanent installations.
In rare occasions, there may be extenuating circumstances that warrant equipment
relocation. System Owners who have received an EPBI and have relocated theirsystem must reinstall in BVES territory and orient their relocated equipment to
produce at least the same generation as their initial EPBI payment was based upon.
The BVSI may seek repayment of incentive funds from the Host Customer or
System Owner if the system is permanently removed from the BVES territory.
2.4.2. Interconnection Requirements
All solar electric generating systems receiving incentives under the BVSI must be
connected to the BVES distribution system. The system interconnection, operation
and metering requirements for solar energy systems shall be in accordance with
BVES utility rules for customer generating facility interconnections. To connect a
solar energy system to the utility distribution system, Host Customers, and/or
System Owners will be required to execute certain documents such as, but not
limited to, an Application for the Interconnection of a Small Solar Electrical
Generating Facility.
Proof of interconnection and parallel operation is required prior to receiving an
incentive payment. BVES will provide proof of interconnection to the PA. Incentive
payments will not be made until the PA confirms valid interconnection.
2.5 Metering and Monitoring Requirements
The Program requires accurate energy production meters for all projects that
receive incentives. Accurate measurement of solar energy output is of paramount
importance to ensure optimum value for both solar owners and ratepayers. All solar
systems are required to have a basic meter with an accuracy of 5 percent to
participate in BVSI program. Inverter integrated meters are acceptable.
For systems greater than 10kW, the Host Customer or System Owner must install a
Performance Monitoring and Reporting System to measure system generation10
in15 minute intervals. The Host Customer or System Owner will be responsible for
sending system production data to the Program Administrator on a biannual basis
for 1 year.
10See Section 8 for more details on PMRS.
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For systems 10kW and below PMRS is not required. BVES will install a meter
capable of measuring interval system generation on all projects and report
production data for a sample of 1 in 15 systems to the Program Administrator.
2.6. Measurement and Evaluation Requirements
To be eligible for incentives, all Applicants, Host Customers, and System Owners
must agree to comply with the terms and requirements of the measurement and
evaluation program. This includes providing access to the PA and/or third parties
contracted by the CPUC and/or PA access to the site and any available data and
information collected on the system.
The Host Customer and System Owner shall agree to allow all information provided
for the rebate to be entered into a database that will permit tracking of applications
for this and other incentive programs. Access to this database will be limited to
BVES, the PA and the California Public Utilities Commission; however, generalsystem equipment, cost information, and performance data may be publicly
reported for research and analysis purposes
3. BVSI Incentive Structure
BVSI provides an Expected Performance-Based Incentive (EPBI) using a specific
dollar per watt amount. The incentive amount for each solar energy system is
determined by analysis using the EPBI Calculator, and is paid when the solar
system has been installed, approved by the local building authority, interconnectedand all program requirements have been met.
3.1. BVSI Incentive Trigger Mechanism
The incentive payment levels will automatically be reduced over the duration of the
Program in 4 steps, based on the volume of kW incentivized. The duration of the
BVSI will be dependent on: (1) whether the incentive budget is depleted or (2) the
end date of the Program (December 2022), whichever comes first.
The PA will count a Projects BVSI size (CEC-AC multiplied by the design factor)
toward the step goals. Residential projects are counted toward the kW trigger once
they have been approved for payment. As the number of kW allocated through
installed systems reaches its maximum within any particular step, the Program will
move to the next step.
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The PA will provide updates to the BVSI website as close as possible to real time
and no less than weekly to indicate the total kWs available for incentives at each
step.
If during a step change, a project that is approved for payment is greater than the
kW amount remaining in the step, the project will receive a splitincentive. The
project will receive the rate for the kW remaining in the original step while the
balance of system kW will receive the lower step incentive rate.
3.2. Expected Performance Based Incentive (EPBI)
BVSI will pay incentives for all projects through an up-front incentive known as
EPBI. The EPBI is based on an estimate of the system's fully operational
performance. EPBI combines the benefits of rewarding productive performance with
the administrative simplicity of a one-time incentive paid at the time of project
completion.
The following formula determines the EPBI incentive:
EPBI Incentive Payment = Confirmed Incentive Rate x Final BVSI Eligible System
Capacity in watts.
3.2.1. EPBI Calculator Modifications
BVES has developed an EPBI calculator to help customers determine the incentive
amount. As it gains experience with the EPBI and the performance of the statewide
solar incentive programs, the PA reserves the right to modify the calculator at anytime without advance notice.
3.2.2. Rebate Limitations
If the Project is installed as described on the Rebate Claim package and all Program
terms and conditions are complied with, the PA will pay a rebate to the entity
designated as the incentive recipient (Payee). The PA reserves the right to modify
or cancel the rebate if the actual installation of the solar energy system differs from
the proposed installation, if the solar energy system fails inspection, and/or if the
documents submitted fail to meet the requirements of the Program Handbook.Rebate amounts and project eligibility for the BVSI are limited by a number of
factors, including:
Total eligible project costs
Other incentives or rebates received
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Project kW system size and Host Customer Site limitations
3.2.2.1. Total Eligible Project Costs
No Project can receive total incentives (incentives from the BVSI combined with
other programs) that exceed total eligible project costs. The Applicant must submitproject cost details to report total eligible project costs and to ensure that total
incentives do not exceed out-of-pocket expenses for the System Owner. Total
eligible project costs cover the solar energy system and its ancillary equipment.
Equipment and other costs outside of the project envelope as listed below are
considered ineligible project costs.
The following costs may be included in total eligible project cost:
1.
Solar equipment capital costs, including tracking systems and other ancillary
equipment associated with the solar energy system.
2.
Engineering and design costs for solar energy systems.
3. Construction and installation costs. For projects in which the generation
equipment is part of a larger project, only the construction and installation
costs directly associated with the installation of the energy generating
equipment are eligible.
4. Engineering feasibility study costs
5. Interconnection costs, if applicable, including:
a. Electric grid interconnection application fees
b.
Metering costs associated with interconnection
6.
Building permitting costs7. Warranty and/or maintenance contract costs associated with eligible project
cost equipment
8. Sales tax and use tax
9. On-site system measurement, monitoring and data acquisition equipment.
10.Customers may claim certain mounting surface costs as eligible project costs.
Costs may include mounting surfaces for the photovoltaic module/solar
collector and/or the materials that provide the primary support for the
modules. Only the percentage of mounting surface directly under the
photovoltaic module/solar collector is eligible.
11.Cost of capital included in the system price by the vendor, contractor orsubcontractor (the entity that sells the system) is eligible if paid by the
System Owner.
In cases in which an installation contract encompasses all costs associated with the
installation of a solar generating system and additional measures such as energy
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efficiency, other renewable generating technologies, etc., the contractor must
delineate the costs for each measure separately in the agreement.
3.2.2.2. Reportable Project Costs
All systems receiving an incentive are required to enter the costs identified below inthe Rebate Claim Form Package:
PV Module the cost for the number of modules installed
Inverter the cost for the number of inverters installed
Permitting Fees only include the cost of the permitting fees charged
by the permitting agency (do not include any costs associated with
time and labor in applying for permits)
Balance of System (BOS) all other eligible costs associated with the
installation of the PV System referenced in 3.2.2.1.
3.2.3.3. Other Incentives or Rebates
For projects that receive other incentives funded from other sources than utility
ratepayers (e.g., federal and state grants, air district grants or tax credits) no
adjustment is made to the BVSI incentive. The Host Customer and System Owner
understand that other program rebates, grants, forgiven loans, financial incentives,
post-installation agreements, Renewable Energy Credits (RECs or Green Credits),
and performance payments are other incentives and must be disclosed as soon as
those agreements or payments are made.
3.2.3.4. Right to Audit Final Project Costs
The PA reserves the right to conduct spot checks to verify that Project-related
payments were made as identified in the final invoices or agreements provided by
equipment sellers and/or Solar Contractors. As part of these spot checks, the PA
will require Applicants to submit copies of cancelled checks, credit card statements,
or equivalent documentation to substantiate payments made to the equipment
seller and/or Solar Contractor. The final amount legally incurred or paid to the
equipment seller and/or the final amount paid to the Solar Contractor for the
purchase and installation of the system must match the cost information identified
in the Rebate Claim package.
To meet this requirement, the System Owner must submit final invoices and/or a
copy of the final agreement, and cost documentation must provide sufficient
information to identify clearly the equipment purchased and the labor paid. If there
is no direct proof of actual payment from the System Owner to an appropriately
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licensed Solar Contractor or seller, the incentive will be cancelled or reduced.
Applicants must explain the difference if the final amount paid by the Applicant is
different from the amount of the purchase or installation shown in any agreement
or invoice.
In addition, the final invoices or agreements should clearly indicate the extent towhich the BVSI incentive lowered the cost of the system to the Host Customer. If
the System Owner has entered into an agreement to pay the equipment seller over
time rather than in lump sum, the final agreement must indicate the terms of
payment and the amount of any deposits or payments paid by Applicant to the
equipment seller to date. The System Owner must pay the cost of any system
installation prior to submitting a payment request to the PA.
3.2.3.5. Site and Host Customer Limitations
There are restrictions on the amount of rebate funding a Host Customer can
receive. Host Customers may only receive an incentive up to a maximum of 50 kW
CEC-AC from the Program for a single Site for the duration of the BVSI.
4.
Application and Payment Processes
To apply for an incentive, visit the BVSI website (www.BVES-Solar.com) to
complete the online rebate application. The supporting documents can be found on
the Apply Here page of the BVES-Solar.com website. Table 2 shows the basic
Rebate Claim package process steps and flow.
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Table 2
Basic Application Process Steps & Flow
4.1. Rebate Claim and Payment Processes
To apply for a BVSI rebate, Applicants must simply submit an online Rebate Claim
package.
4.1.1. Submit Rebate Claim Package
After the solar energy system is purchased, installed, and approved for operation
through the BVES Interconnection process, the Applicant should complete the
online Rebate Claim Package and submit the required supporting documentation.
The following section discusses each of the forms and documentation requirements
listed in subsection 4.2.2. Signatures are acceptable in the following formats for all
submitted documentation:
Original signed documents, or wet signatures
Scanned copies of original signed documents
Faxed copies of original signed documents
Verifiable E-signatures
4.2 Rebate Claim Package
4.2.1. Online Rebate Claim Application
To submit a Rebate Claim Application, please visit www.BVES-Solar.com. The
applicant will be required to complete all the required sections, which will include
the following:
PV System is
Interconnected
Applicant submitsonline BVSI Rebate
Claim PackagePA reviews Rebate
Claim Package
Incomplete Rebate
Claim Package
Suspension (14
days)
Applicant submits
corrections to PA
Host Customerreceives Rebate
Approval letter
PV system is
inspected (sample
1 in 12 )
Rebate payme
sent to Payee
PV System
Inspection Pass
PV System
Inspection Fail
Host Customer
approves change of
incentive
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Site Information Physical address location of the PV system
Applicant Information Individual or Company completing the application
Host Customer Information See Section 2.1.2 for Host Customer definition
System Owner Information See Section 2.1.3 for System Owner definition
Contractor Information See Section 2.1.4 for Contractor definition
Energy Efficiency Disclosure Information
System Information From the EPBI Calculator Printout
Project Cost Information
Document Submittal See Section 4.2.2 -4.2.5 for required documents
4.2.1. Complete Rebate Claim Form with Signatures
A completed Rebate Claim Form must be submitted. It must be read, completed,
initialed and signed by the Host Customer. If the Payee listed on the Rebate Claim
Form is different from the Host Customer, the contract should reflect the incentive
benefit to the Host Customer.
4.2.2. Printout of EPBI Tool Calculation
The EPBI tool calculates the systems expected energy output and rebate amount.
The EPBI tool calculator is found on the BVSI website www.BVES-Solar.com.
4.2.3. Performance Monitoring & Reporting System (PMRS)
For systems less than 10kW, PMRS is not required.
For systems 10kW and above, PMRS is required and the name of the PerformanceMonitoring and Reporting Service (PMRS) installed must be indicated on the Rebate
Claim package. See section 8 for more information on these requirements.
Eligible PMRS providers may be found on the GoSolar Californiawebsite.
4.2.4. Copy of Executed Agreement of Solar Energy System Purchase
and Installation or Copy of Executed Alternative System Ownership
Agreement (If System Owner is Different from Host Customer)
Applicants must submit a copy of their executed contract for purchase and
installation of the system. Agreements must be legally binding and clearly identify,
at a minimum, the scope of work, terms, price, solar energy system components to
be installed. Agreements must be signed by appropriate parties (supplier/Solar
Contractor, Host Customer, and/or System Owner).
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In the case of alternate System Ownership arrangements, the System Owner must
provide a copy of their agreement(s) to purchase and install the system on the Host
Customers site address.
Agreements for the purchase of a system or system equipment must be in writing
and must include, at a minimum, the following information:
The quantity, make and model number (as shown on the California
Energy Commission lists of eligible equipment) for the PV modules,
inverters, and system performance meters
The total purchase price of the system before applying the incentive
Language indicating the purchasers commitment to buy the system
Printed names and signatures of the purchaser and equipment sellers
authorized representative.
Installation contracts must comply with the Contractors State License Board (CSLB)requirements. Please refer to the CSLB website for more information on CSLB
guidelines at www.cslb.ca.gov.
Entities without a valid A, B, C-10 or C-46 contractors license may not offer
installation services or charge for installation in any agreement under the BVSI
Program.
In addition, installation contracts must contain the following information:
Name, address and contractors license number of the company
performing the system installation Site address for the system installation
Description of the work to be performed
Total agreed price to install the system
Payment terms (payment dates, dollar amounts and how the incentive
will be applied)
Printed names and signatures of the purchaser and the companys
authorized representative.
The above requirements are sufficient evidence of an agreement to purchase and
install a system for cases where a contractor sells and installs the system.
If the system is a self-installation, please submit a copy of the purchase order or
invoice for the modules and inverter(s). See section 4.3.1 for more information.
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4.3. Circumstances Requiring Additional Documentation
4.3.1. Owner or Self-Installed System
In situations where the Host Customer installs the Project, the Applicant must
provide the following information during the Rebate Claim process:
An equipment purchase agreement, or
In cases where there is not a signed agreement to purchase equipment the
purchaser may provide invoices or receipts showing the system equipment
purchase price (for modules, inverters, racking) has been paid to the
seller(s).11
The PA will verify interconnection prior to any incentive payment. Customers who
have not been interconnected prior to applying for a BVSI Incentive may have their
claims cancelled and will need to reapply.
The PA reserves the right to withhold incentive payment, pending review and
approval of the rebate claim documentation and field inspection results if that
Project is determined to require a field inspection.
4.4. Incomplete Rebate Claim Packages
If a Rebate Claim package is incomplete or is found to require clarification, the PA
will request the information necessary to process that claim further. Applicants
have 14 calendar days to respond to the requested clarification with the necessary
information.
If after 14 calendar days, the Applicant has not submitted the requested
information, the request for payment may be denied.
4.4.1 Rebate Check Payment and Terms
Upon final approval of the Rebate Claim package documentation and completed
field verification visit (if required), the PA will issue the EPBI payment. Payment will
be made to the Host Customer or a third party as indicated on the RebateClaim
Form, and will be mailed to the address provided.
11An example of this situation is when the purchaser buys new equipment online or by mail order.
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5. Field Inspections
A portion of BVSI projects are subject to onsite field inspections or may be
inspected at the PA's discretion. The PA or qualified third party inspector will
perform onsite field inspection for the first two Rebate Claim packages submitted byeach new Solar Contractor. After the completion of two successful field inspections,
each Contractor will have a minimum of one in twelve projects inspected in the
program overall, but the PA may inspect more projects from any particular
Applicant or Solar Contractor. The PA may determine whether to conduct an onsite
field inspection randomly and/or based on Applicant or Solar Contractors
participation in the Program. Parameters that may affect frequency or incidence of
onsite field inspection include: Solar Contractor being new to the program,
frequency of new applications in the program, and results of prior onsite field
inspections, or results of prior project reviews.
If neither the Applicant nor the Host Customer will be present during the inspection,
the inspector must obtain permission from the Host Customer to perform the
inspection.
5.1. Key Project Components Reviewed During Onsite Field Inspection
The inspectors will verify the system is installed in accordance with information
provided on the Rebate Claim documentation, and in compliance with handbook
rules.
The following are some examples of what will be inspected and verified:
Modules and Inverter(s)
Manufacturer
Model Number (if model nameplate is not visible, invoice may be required for
verification)
Quantity
Installation Parameters
Tilt Azimuth
Standoff Height
Shading of Array(s)
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The PA reserves the right to ask for a shading study from an Applicant. Shading
studies may be requested for projects that do not meet the minimal shading
requirements.
Operation
System is operational, and output is reasonable for conditions at the time of
the inspection
PMRS Meter or Metering Related Equipment
The metering equipment must meet the requirements as outlined in this
Handbook.
5.2. Acceptable Range of Parameters for Key Project Components
Reviewed During Inspection
The onsite field inspector will review and record key project components found at
the installation site. The PA will evaluate and compare the results of the inspection
to the Rebate Claim documentation.
The inspection results must fall within the following tolerances to pass inspection:
Tilt 3
Azimuth 5
Summer Shading (May-October) 5%
A new EPBI Calculator will be run and the project incentive modified accordingly if:
The onsite field inspection results are outside of the above tolerances,
or
The onsite field inspection reveals other discrepancies between key project
components and the project's Rebate Claim documentation.
All project incentives are subject to the results of the onsite field inspection.
The PA will notify the Applicant, Solar Contractor, System Owner, and Host
Customer if an onsite field inspection will result in a change in system size and/or
incentive amount.
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5.3. Issuance of Infractions
An infraction can be issued to the Applicant, Solar Contractor, System Owner,
and/or Host Customer for the following reasons but are not limited to:
The incentive amount submitted in the rebate claim documentation differs
from that of the onsite inspection incentive results between 5-10%
Neglecting to provide required documentation on a consistent basis, such as
Host Customer contact information
Neglecting to respond to requested information within the 14 day time period
on a consistent basis
5.4. Issuance of Failures
A failure can be issued to the Applicant, Solar Contractor, System Owner, and/or
Host Customer for the following reasons but are not limited to:
The incentive amount submitted in the rebate claim documentation differs
from that of the onsite inspection incentive results greater than 10%
3 Infractions as defined in section 5.3.
Re-inspections (due to contested result) found to have adjustments made to
match the original submission following the initial inspection
Re-inspections (due to contested result) found to have the same results as
the original inspection
System is found non-operational at the time of inspection due to equipment
failure Installation of PV modules and inverters not on the CECs list of eligible
equipment or otherwise ineligible for incentives
Failing to disclose the actual contractor performing work on Installation
Contract
6. Notifications, Sanctions and Dispute Resolution
Any Applicant, Solar Contractor, System Owner, Seller, and/or Host Customer that
receives two failures in a rolling 12-month period will be on probation for a periodtwelve months, during which time all of its projects will be inspected.
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For small volume contractors with less than 20 project sites12per rolling 12 month
period:
After being placed on probation, the entity will be removed from probation if no
additional failures occur within 12 months from the second failure. If a third failure
occurs before the end of the probationary period, the entity will be disqualified fromparticipating in the BVSI for a minimum of one year.
For large volume contractors with more than 20 project sites per rolling 12 month
period:
After being placed on probation, the entity will be removed from probation if no
additional failures occur within one calendar year from the third failure. If two
failures occur (the fourth and fifth) before the end of the 12 month probationary
period, the entity will be disqualified from participating in the BVSI for a minimum
of one year.
If the program issues an infraction or failure for a project that is later re-inspected
because the results are contested and the failure was due to inspector error, the
failure will be removed from the records.
6.1. Grounds for Immediate Disqualification from the Program
An Applicant, Solar Contractor, System Owner, Seller, and/or Host Customer may
be immediately disqualified from participating in the BVSI if any of the following
events occur:
A Solar Contractor that operates under a false CSLB license number or
another contractors CSLB license number
An Applicant fails to disclose another funding source that materially affects
the projects qualification for the incentive
The onsite field inspection results in an incentive amount that is 25% below
the original Rebate Claim Form rebate amount, or:
The Solar Contractor installs used or stolen PV modules and/or any other
system components
Forged paperwork
Providing any false information to the PA or any program participant
(Applicant, Solar Contractor, System Owner, Seller and/or Host Customer)
12Contractor volume adjusted from CSI to accommodate BVSI territory.
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6.2. Notifications and Sanctions
The PA will notify the Applicant, Solar Contractor, System Owner, Seller, and Host
Customer if the PA determines that an infraction or failure has occurred.
If a project results in the imposition of an infraction or failure on an Applicant, Solar
Contractor, System Owner, Seller and/or Host Customer, the PA will notify all of the
related entities on the project application of the reasons for the determination.
Once notified of an infraction or failure due to an onsite field inspection or the
application process review, the Applicant, Host Customer, or System Owner will
either accept the results or dispute the results through the dispute resolution.
7. Process for Removal from Program
7.1. Removal from Program for Excessive Failures
If it is determined that an Applicant, Solar Contractor, System Owner, Seller,
and/or Host Customer is immediately disqualified from participating in the program
because of more than the acceptable number of failures based on the companys
size then the PA will:
Notify all parties identified on the Rebate Claim(s) of the disqualification.
List the companys name on the BVSI website as a non-participating
contractor.
7.2. Removal from Program for Immediate Disqualification
If an Applicant, Solar Contractor, System Owner, Seller, and/or Host Customer is
immediately disqualified due to the reasons pursuant to Section 6.1, the following
will occur:
No incentive payment will be made to the entity that has been immediately
disqualified; and
All parties identified on the application or claim will be notified of their status.
7.3. Dispute Resolution
The Applicant, Solar Contractor, System Owner, Seller, and/or Host Customer may
appeal in writing to the PA regarding notification of sanction. To appeal the
notification, the disqualified entity must first contact the PA within 30 days to
discuss the issue. If the disqualified entity has new information to provide the PA,
then it must be provided to the PA within 30 days. If the disqualified entity and
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the PA cannot resolve the dispute, then the disqualified entity can file a complaint
using the California Public Utility Commission's (CPUCs) Formal Complaint process.
Information on the formal Complaint process is available through the Public
Advisor's Office at the CPUC or on CPUCs website.
TECHNICAL SECTION
8. Metering Requirements
This section contains detailed information on the minimum metering and monitoring
requirements for participation in the Program. These minimum metering
requirements were developed to increase owner knowledge of system performance,
foster adequate system maintenance, and thereby ensure ratepayer-funded
incentives result in expected levels of solar generation.
8.1. PMRS Service Requirement
A Performance Monitoring and Reporting System (PMRS) is required for all systems
10kW and larger. The Host Customer or System Owner is responsible for the choice
and installation of the metering hardware. The Host Customer or System Owner will
be responsible for submitting system production data to the Program Administrator
on a biannual basis for 1 year.
The list of eligible PMRS providers may be found on the GoSolar CA website.
For systems less than 10kW, no PMRS is required. However, BVES will install a
meter capable of measuring interval system generation on all projects and report
production data for a sample of 1 in 15 systems to the Program Administrator.
8.1.1. Minimum Communication Requirements
All PMRS systems must be installed with some form of communication capability
that will provide meaningful feedback to Host Customers. The systems should have
remote communicating capability whereby performance data can be collected, and
accessed remotely.
8.1.2. Minimum PMRS requirements
5 % meter
Data as collected and summarized by 15 minute, hour, day, month, and
year.
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Provide System Owner with on-demand access to all reports required by
Section 8.1.1
Notification service alerts to the System Owner indicating a non-functioning
or poorly functioning system
Capable of providing quarterly 15 minute interval kWh energy production
data
A PMRS on the California Energy Commission Eligible PMRS list
8.2. Minimum Metering Equipment Requirements
All systems must be installed with a meter or metering system which allows the
Host Customer to determine the amount of system energy production and allows
the System Owner to support proper system operation and maintenance.
The California Energy Commissions list of qualifying meters may be found on the
Go Solar CA website.
8.2.1. Meter Type
At minimum, 5 % meters are required for all systems. BVES will install a meter
capable of measuring interval system generation on all projects. BVES will bear the
cost of the performance meter and report production data for a sample of 1 in 15
systems to the Program Administrator. All systems 10kW and greater will receive
an output meter installed by BVES, but for these systems, the Host Customer or
System Owner will be responsible for reporting the data to the Program
Administrator biannually for one year.
8.2.2. Meter Measurement and Time Granularity of Acquired Data
Electric meters must measure the gross energy generated (kWh). The PMRS must
log all Required Solar Performance / Output Data points no less frequently than
once every 15 minutes.
8.2.3. Meter Display
All meters must provide a display showing the meters measured net generatedenergy output and measured instantaneous power. This display must be easy to
view and understand. This display must be physically located either on the meter,
inverter, web interface, or remote device.
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9. Equipment Certification, Rating Criteria & Design
Factor Calculations
9.1. Equipment Certifications and Rating Criteria
PV system components (modules, inverters, and system performance meters) must
be certified through the California Energy Commissions PV system certification
program. The CEC provides a list of currently certified eligible equipment on the
GoSolar California websiteor through its Call Center: (800) 555-7794.
The PA will confirm that equipment identified in the Rebate Claim Package meets
eligibility requirements prior to approving the Rebate Claim Package. Equipment is
periodically added and removed from the lists of eligible equipment, so Applicants
should confirm that the components purchased for a system are eligible prior to
installation. Equipment must be certified before any incentive payments will be
made.
Eligibility requirements for components are summarized below:
PV modules must be listed on the California Energy Commissions Eligible
Equipment List
Inverters must be listed on the California Energy Commissions Eligible
Equipment List
Meters:
o
Inverter Integrated: must be listed on the CECs Eligible Inverter List perSB1 Guidelines and indicate approved built-in meter is installed
o External meters must be listed on the CECsEligible Equipment List
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APPENDICES
Appendix A: Definitions
This section provides a list of definitions of key concepts used in this Programhandbook.
Alternating Current (AC):
Electric current that reverses direction, usually many times per second. Opposite of
direct current (DC). Most electrical generators produce alternating current. Under
the Program, PV electric output calculations must always be made using the CEC-
AC rating standards which include inverter DC to AC conversion losses.
Applicant:
The entity, either the Host Customer, System Owner, or third party designated bythe Host Customer, that is responsible for the completion and submittal of the
Rebate Claim Package and serves as the main point of contact for a specific Rebate
Claim Package.
Azimuth:
Azimuth is the horizontal angular distance between the vertical plane containing a
point in the sky and true south. All references to azimuth within the Program,
unless expressly stated otherwise, refer to true, not magnetic, azimuth. For
calculating an EPBI incentive, all proposed PV systems with a true azimuth
orientation between 180 degrees and 270 degrees, facing south, southwest and
west, will be compared to a reference system with the same orientation as the
proposed system.
Calendar Days:
All dates and schedules are measured in calendar days, which include all days of
the week.
California Energy Commission (CEC):
Californias primary energy policy and planning agency. Created in 1974 and
headquartered in Sacramento, the Commission has responsibility for activities that
include forecasting future energy needs, promoting energy efficiency throughappliance and building standards, and supporting renewable energy technologies.
On August 21, 2006, the Governor signed Senate Bill (SB 1) which directs the CPUC
and the CEC to implement the Program consistent with specific requirements and
budget limits set forth in the legislation.
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California Public Utilities Commission (CPUC or Commission):
The CPUC regulates a number of industries including the electric utility industry that
impact public well-being. Among other activities, the CPUC establishes service
standards and safety rules and authorizes rate changes. The CPUC, in conjunction
with Senate Bill 1 (SB 1), has authorized the California Solar Initiative (CSI). In
CPUC Decision (D.14-11-002), the California Public Utilities Commission (CPUC)
established the BVSI and established implementation details for the Program.
California Solar Initiative (CSI):
The California Solar Initiative program pays incentives to solar photovoltaic (PV)
projects in the three California IOU service territories. The program was authorized
by the California Public Utilities Commission (CPUC) and Senate Bill 1 (SB 1).
Responsibility for administration of the CSI Program is shared by Pacific Gas and
Electric Company, Southern California Edison Company, and the Center for
Sustainable Energy for San Diego Gas & Electric customers.
Capacity Factor:
The ratio of the electrical energy produced by the generating system during a
specific period, to the electrical energy the generating system could have produced
if it had operated at full capacity rating during the same period.
Capacity Rating:
The capacity rating is a load that a power generation unit, such as a photovoltaic
system, is rated by the manufacturer to be able to meet or supply. The PA will
verify system capacity rating to confirm the final incentive amount.
CEC-AC Rating:The PA will use the California Energy Commissions CEC-AC method to measure
nominal output power of photovoltaic cells or modules to determine the systems
rating in order to calculate the appropriate incentive level. The CEC-AC rating
standards are based upon 1,000 Watt/m2solar irradiance, 20 degree Celsius
ambient temperature, and 1 meter/second wind speed. The CEC-AC Watt rating is
lower than the Standard Test Conditions (STC).
Contractor:
A person or business entity who contracts to erect buildings, or portions of
buildings, or systems within buildings. Under the Program, all contractors must beappropriately licensed California contractors in accordance with rules and
regulations adopted by the State of California Contractors State Licensing Board.
The Solar Energy System Contractor is responsible for installing for the Host
Customer the photovoltaic system that will be eligible to receive Incentives. A
qualified Solar Contractor should be able to evaluate factors that will affect
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photovoltaic system performance, such as the orientation (tilt and direction) of the
system, wire length and size, shading, module output mismatch, inverter efficiency,
module cleanliness, and other factors.
Contractors State License Board (CSLB):
Installation contracts for photovoltaic systems installed under the Program mustcomply with the Contractors State License Board (CSLB) requirements. Please refer
to the CSLB websitefor more information on CSLB guidelines.
Design Factor:
The Design Factor is a ratio comparing a proposed systems expected generation
output with that of a baseline system. The Design Factor is used in calculating the
EPBI incentive (it is multiplied by the system rating and the incentive rate to
determine EPBI incentives). A Design Factor is also used by PA to allocate kW
towards the capacity targets in each step.
Direct Current (DC):
Direct current (DC or "continuous current") is the continuous flow of electricity
through a conductor such as a wire from high to low potential. In direct current, the
electric charges flow always in the same direction, which distinguishes it from
alternating current (AC). Under the Program, photovoltaic electric output
calculations must always be made using the CEC-AC rating standards which include
inverter DC to AC conversion losses.
Electric Utility:
The Host Customers local electric transmission and distribution service provider for
their Site. In the BVSI, the electric utility is the Bear Valley Electric Service.
Electrical Distribution Grid:
A network of power stations transmission circuits, and substations conducting
electricity. Under the Program, eligible renewable energy systems must be
permanently interconnected and operating parallel to the electrical distribution grid
of the utility serving the customers electrical load.
Energy Service Provider (ESP):
An entity that provides electric power and ancillary services (including but not
limited to aggregators, brokers, and marketers, but excluding utilities) to an end
use customer. Also referred to as an Electric Service Provider.
Expected Performance Based Incentive (EPBI):
The EPBI incentive methodology pays an up-front incentive to participants of BVSI.
EPBI incentives combine the performance benefits of PBI with the administrative
simplicity of a one-time incentive paid at the time of project installation. The EPBI
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Incentive will be calculated by multiplying the incentive rate by the system rating
by the Design Factor.
Host Customer:
The Host Customer is an individual or entity with 1) legal rights to occupy the site,
2) receives retail level electric service from Bear Valley Electric Service, 3) is theutility customer of record at the site, 4) is connected to the electric grid, and 5) is
the recipient of the net electricity generated from the solar equipment. The Host
Customer alone will retain sole rights to the incentive and corresponding incentive
number. The Host Customer has the right to designate the Applicant, energy
services provider and/or Solar Contractor to act on their behalf.
Interconnection Agreement:
A legal document authorizing the flow of electricity between the facilities of two
electric systems. Under the BVSI, eligible renewable energy systems must be
permanently interconnected and operating in parallel to the electrical distribution
grid of the utility serving the customers electrical load. Portable systems are not
eligible. Proof of interconnection and parallel operation will be verified by the PA
prior to receiving an incentive payment.
Interval Data Recorder (IDR):
IDR is a metering device capable of recording minimum data required. Minimum
data requirements include (a) hourly data required for the Direct Access settlement
process; and (b) data required to bill the utilitys distribution tariffs including 15-
minute demand data--also referred to as Hourly Metering.
Inverter:An electric conversion device that converts direct current (DC) electricity into
alternating current (AC) electricity.
Inverter Efficiency:
The AC power output of the inverter divided by the DC power input.
Kilowatt (kW):
A unit of electrical power equal to 1,000 watts, which constitutes the basic unit of
electrical demand. The watt is a metric measurement of power (not energy) and is
the rate (not the duration over which) electricity is used. 1,000 kW is equal to 1
megawatt (MW). Throughout this Program Handbook, the use of kW refers to the
CEC-AC wattage ratings of kW alternating current inverter output.
Kilowatt Hour (kWh):
The use of 1,000 watts of electricity for one full hour. Unlike kW, kWh is a measure
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of energy, not power, and is the unit on which the price of electrical energy is
based. Electricity rates are most commonly expressed in cents per kilowatt hour.
Lessor:
A person or entity who rents property to another under a lease. Under the Program,
in the case of a third-party owned system (or leased system, for example), thelessor is classified as the System Owner.
Load:
Either the device or appliance which consumes electric power, or the amount of
electric power drawn at a specific time from an electrical system, or the total power
drawn from the system. Peak load is the amount of power drawn at the time of
highest demand.
Measurement and Evaluation (M&E):
A process or protocol to evaluate the performance of an energy system. As a
condition of receiving incentive payments under the Program, System Owners and
Host Customers agree to participate in Measurement and Evaluation (M&E)
activities as required by the CPUC. M&E activities will be performed by the PA or the
PAs independent third-party consultant and include but are not limited to, periodic
telephone interviews, on-site visits, development of a M&E Monitoring Plan, access
for installation of metering equipment, collection and transfer of data from installed
system monitoring equipment, whether installed by Host Customer, System Owner,
a third party, or the PA.
Meter:
A device used to measure and record the amount of electricity used or generatedby a consumer. The Program requires accurate solar production meters for all solar
projects that receive incentives.
Metering System:
A metering system should include all distinct components necessary to measure the
energy produced by a solar generating system. This must include equipment that
allows the system to monitor and record 15-minute interval data either internally or
externally through additional equipment such as a data logger. The system must
include a 5% accurate meter either socket based or panel style allowing for a
visual or remote display.
Minimal Shading:
No Solar obstruction is closer than a distance twice the height it extends above the
PV Modules. The measurements shall be made at all the major corners of the array
with no adjacent measurement being more than 40 feet apart. The points of
measurement shall be distributed evenly between two major corners if they are
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more than 40 feet apart such that the linear distance between any sequential points
is no more than 40 feet.
Modules:
Under the Program, a module is the smallest complete environmentally protected
assembly of interconnected photovoltaic cells. Modules are typically rated between50 and 400 W.
Net Energy Metering (NEM) Agreement:
An agreement with the local utility which allows customers to reduce their electric
bill by exchanging surplus electricity generated by certain renewable energy
systems such as PV systems. Under net metering, the electric meter runs
backwards as the customer-generator feeds extra electricity back to the utility. The
Program permits net energy metering agreements.
New Construction:
A building is considered new construction if theentire building structure is subject
to current Title 24 building efficiency standards and does not yet have a Certificate
of Occupancy from the relevant Building Department.
Photovoltaic (PV):
A technology that uses a semiconductor to convert light directly into electricity.
Power Purchase Agreements (PPA):
An agreement for the sale of electricity from one party to another, where the
electricity is generated and consumed on the Host Customer Site. Agreements that
entail the export and sale of electricity from the Host Customer Site do not
constitute on-site use of the generated electricity and therefore are ineligible for the
BVSI.
Program Administrator (PA):
For purposes of the BVSI, Center for Sustainable Energy is the PA.
Program Year (PY):
January 1 through December 31
Project:
For purposes of the BVSI, the Project is the installation and operation of the
proposed eligible PV system, as described by the Rebate Claim.
Residential:
Residential entities are private household establishments that consume energy
primarily for space heating, water heating, air conditioning, lighting, refrigeration,
cooking, and clothes drying. The classification of an individual consumer's account,
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where the use is both residential and commercial, is based on principal use. A
power purchase agreement on a residence is considered a residential application. It
should be noted that the Incentive rate will be determined by the utility rate
schedule of the Host Customer (may require more than one application). If the
requested incentive rate differs from the classification of the Host Customer utility
rate schedule, the PA may, at its discretion, allow the requested incentive rate
given that the Host Customer change its utility rate schedule.
Retrofit:
A retrofit is a modification of an existing building or facility to include new systems
or components.
Seller:
Any person or business entity that transfers property or property rights by sale in
commerce.
Senate Bill 1 (SB 1):
Chapter 132, Statutes of 2006 (SB1, Murray) establishes the goals of installing
3,000 MW of solar generation capacity in the state of California, establishing a self-
sufficient solar industry, and placing photovoltaic systems on 50 percent of new
California homes within 13 years. The bill was signed into law on August 21, 2006,
and it became effective on January 1, 2007.
Site:
For BVSI program purposes, site refers to theservice address for the account
number and meter number listed on the Rebate Claim Package.
System Owner:
The owner of the PV system at the time the incentive is paid. For example, in the
case when a vendor sells a turnkey system to a Host Customer, the Host Customer
is the System Owner. In the case of a leased system, the lessor is the System
Owner.
System Size:
There are three different system sizes, DC, CEC-AC, and BVSI-AC.
The DC system size is based off of the nameplate rating of the solar panelsmultiplied by the number of solar panels in the array(s).
The CEC-AC system size will take into account the CEC rated efficiency of the
solar panels and inverter(s).
The BVSI-AC system size will take into account the CEC rated efficiency of
the solar panels and inverter(s), along with the design factor (azimuth, tilt,
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mounting method, and shading of the solar electric system). The Incentive is
based on the BVSI-AC system size.
Time of Use (TOU) Rates:
Electricity prices that vary depending on the time periods in which the energy is
consumed. In a time-of-use rate structure, higher prices are charged during utilitypeak-load times. Such rates can provide an incentive for consumers to curb power
use during peak time.
Warranty:
A promise, either written or implied, that the material and workmanship of a
product are without defect or will meet a specified level of performance over a
specified period of time. In the BVSI, inverters and modules must each carry a 10
year warranty, and meters a one-year warranty. Meters that are integrated in the
inverter must carry a 10-year warranty. The warranty may be provided in
combination by the manufacturer and Solar Contractor.
For BVSI purposes, Contractors must provide a 10-year warranty to provide for no-
cost repair and replacement of the system for any expenses not otherwise covered
by the manufacturer.
Appendix B: Additional Requirements and Terms
In addition to the Program eligibility criteria and requirements described above in
the Handbook, the following additional items are required of BVSI participants.
No Endorsement by Program Administrator
The Host Customer and System Owner understand that the PAs review of the
Project and authorization for BVSI funding shall not be construed as confirming or
endorsing the qualifications of the Applicant or any person(s) involved with the
Project, including but not limited to the Project Solar Contractor(s), designer(s), or
manufacturer(s); endorsing the Project design; or as warranting the economic
value, safety, durability or reliability of the Project. The Host Customer is solely
responsible for the Project, including selection of any designer(s), manufacturer(s),
contractor(s), or Solar Contractor(s). The Host Customer and System Ownerunderstand that they, and any third parties involved with the Project, are
independent contractors and are not authorized to make any representations on
behalf of the Program Administrator (PA). The Host Customer and System Owner
shall not use the BVES or PAs corporate name, trademark, trade name, logo,
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identity, or affiliation for any reason, without prior written consent of the BVES or
PA.
Dispute Resolution
The parties to the BVSI Program shall attempt in good faith to resolve any dispute
arising out of or relating to it promptly by negotiations between PA and the System
Owner and/or Host Customer. Either party must give the other party or parties
written notice of any dispute. Within 30 calendar days after delivery of the notice,
the appointed representatives shall meet at a mutually acceptable time and place,
and shall attempt to resolve the dispute. If the matter has not been resolved within
30 calendar days of the first meeting, any party may pursue other remedies,
including mediation. All negotiations and any mediation conducted pursuant to this
clause are confidential and shall be treated as compromise and settlementnegotiations, to which Section 1152.5 of the California Evidence Code shall apply,
and Section 1152.5 is incorporated herein by reference.
Limitation of Liability
The PA shall not be liable to the System Owner, Host Customer or to any of their
respective contractors or subcontractors for any special, incidental, indirect or
consequential damages whatsoever, including, without limitation, loss of profits or
commitments, whether in contact, warranty, indemnity, tort (including negligence),
strict liability or otherwise arising for the PAs performance or nonperformance of its
obligations under the BVSI Program.