CHAPTER
Puc 900 NET
METERING FOR CUSTOMER-OWNED RENEWABLE ENERGY GENERATION RESOURCES OF 1,000
KILOWATTS OR LESS
PART Puc 901 PURPOSE
Puc
901.01 Purpose. The purpose of Puc
900, pursuant to the mandate of RSA 362-A:9, is to establish reasonable interconnection
requirements for safety, reliability, and power quality for net energy metering
as the public interest requires, and consistent with the legislative
declaration of purpose set forth in RSA 362-A:1, in which the legislature
found:
(a) “It to be in the public interest to provide
for small scale and diversified sources of supplemental electrical power to
lessen the state's dependence upon other sources which may, from time to time,
be uncertain;”
(b) “It to be in the public interest to encourage
and support diversified electrical production that uses indigenous and
renewable fuels and has beneficial impacts on the environment and public
health;” and
(c) “That net energy metering for eligible
customer-generators may be one way to provide a reasonable opportunity for
small customers to choose interconnected self-generation, encourage private
investment in renewable energy resources, stimulate in-state commercialization
of innovative and beneficial new technology, enhance the future diversification
of the state's energy resource mix, and reduce interconnection and
administrative costs.”
Source. #2050, eff 6-13-82; ss by #2912, eff
11-26-84; EXPIRED 11-26-90
New. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09; ss by #9998, eff 9-20-11;
ss by #13080, eff 9-14-20
Puc 901.02 Applicability.
(a) Puc 904 through Puc 908 shall be applicable only to small net-metering
customers.
(b) Puc 903.02(l)
through (p) shall only apply to net surplus electricity exported to the
distribution system that accumulates during the 12 monthly billing cycles
preceding the March 2012 billing cycle and in subsequent billing cycles.
(c) Where expressly noted, the provisions of Puc 900 shall apply only to customer-generators subject to
the standard net metering tariff or only to customer-generators subject to the
alternative net metering tariff.
(d) Interconnection of large net-metering
customer-generators shall be governed by each utility’s interconnection
practices as set forth in its tariff filed with the commission.
(e) With the exception of Puc
903.02(u) and Puc 905.07, and unless otherwise noted,
Puc 900 shall be applicable to rural electric
cooperatives for which a certificate of deregulation is on file with the
commission with respect to customer-generator subject to the standard net
metering tariff up to the applicable cap set forth in Puc
903.02(b).
Source.
#9998, eff 9-20-11; ss by #13080, eff 9-14-20
PART Puc 902 DEFINITIONS
Puc 902.01 “Affordable Housing Project” means any multi-family residential
housing project that is:
(1) Funded through a federal, state, or local
program requiring that the real estate remains subject to land use restriction or
rental housing affordability covenants that limit allowable rents charged to
individuals or families, consistent with RSA 674:58, IV pertaining to workforce
housing, or as otherwise required under the applicable federal, state, or local
program;
(2) A federal low-income housing tax credit project, as
defined in Section 42 of the Internal Revenue Code of 1986, as amended;
(3) A project funded with federal grants made to states
for low-income housing projects in lieu of low-income housing tax credits under
Section 1602 of the American Recovery and Reinvestment Act of 2009; or
(4) A limited equity cooperative, including, but not
limited to, a manufactured housing park or apartment building, in which the majority of members are of low or moderate income.
Source. #2050, eff 6-13-82; ss by #2912, eff
11-26-84; EXPIRED 11-26-90
New. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09; ss by #9998, eff 9-20-11;
ss by #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15; ss by #13080, eff 9-14-20
Puc 902.02 “Agreement” means
the written agreement signed by the host and by each group member as required
by RSA 362-A:9, XIV for the purpose of controlling energy costs of the group.
Source. #2050, eff 6-13-82; ss by #2912, eff
11-26-84; EXPIRED 11-26-90
New. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09;
New. #9515, eff 7-18-09
(from Puc 902.01); ss by #9998, eff 9-20-11 (from Puc 902.01); ss by #10502, INTERIM, eff 1-3-14, EXPIRED:
7-2-14 (from Puc 902.01)
New. #10757, eff 1-8-15;
ss by #13080, eff 9-14-20 (formerly Puc 902.01)
Puc 902.03
“Alternative Net Metering Tariff” means
the alternative net energy metering tariff provisions adopted by the commission
pursuant to RSA 362-A:9, XVI in Order No. 26,029 issued in Docket DE 16-576 on
June 23, 2017, which tariff provisions are applicable to customer-generators
receiving a utility net metering capacity allocation on or after September 1, 2017 once the utility is capable of implementing such new
tariff provisions.
Source.
#13080, eff 9-14-20
Puc 902.04 “Combined Heat and Power
System” means a “combined heat and power system” as defined in RSA 362-A:1-a,
I-d, namely “a new system installed after July 1, 2011, that produces heat and
electricity from one fuel input using an eligible fuel, without restriction to
generating technology, has an electric generating capacity rating of at least
one kilowatt and not more than 30 kilowatts and a fuel system efficiency of not
less than 80 percent in the production of heat and electricity, or has an electric
generating capacity greater than 30 kilowatts and not more than one megawatt
and a fuel system efficiency of not less than 65 percent in the production of
heat and electricity. Fuel system
efficiency shall be measured as usable thermal and electrical output in BTUs
divided by fuel input in BTUs.”
Source. #2050, eff 6-13-82; ss by #2912, eff
11-26-84; EXPIRED 11-26-90
New. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09
(from Puc 902.03); ss by #9998, eff 9-20-11 (from Puc 902.04); ss by #10502, INTERIM, eff 1-3-14, EXPIRED:
7-2-14 (from Puc 902.03)
New. #10757, eff 1-8-15; ss by #13080, eff 9-14-20 (formerly Puc 902.02)
Puc 902.05 “Customer-Generator”
means “eligible customer-generator” as defined in RSA 362-A:1-a, II-b, namely
“an electric utility customer who owns, operates, or purchases power from an
electrical generating facility either powered by renewable energy or which
employs a heat led combined heat and power system, with a total peak generating
capacity of up to and including one megawatt, that is located behind a retail
meter on the customer's premises, is interconnected and operates in parallel
with the electric grid, and is used to
offset the customer's own electricity requirements. Incremental generation added to an existing
generation facility, that does not itself qualify for net metering, shall
qualify if such incremental generation meets the qualifications of this
paragraph and is metered separately from the non-qualifying facility.”
Source. #2050, eff 6-13-82; ss by #2912, eff
11-26-84; EXPIRED 11-26-90
New. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09;
ss by #9998, eff 9-20-11 (from Puc 902.03); ss by
#10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14 (from Puc
902.04)
New. #10757, eff 1-8-15;
ss by #13080, eff 9-14-20 (formerly Puc 902.03)
Puc
902.06 “Customer’s Own Electricity Requirements”
shall include the electricity consumed in conjunction with or to operate the
facility.
Source. #13080, eff 9-14-20
Puc 902.07 “Default Service”
means energy supply services provided by a distribution utility which includes
a rural electric cooperative for which a certificate of deregulation is on file
with the commission, but does not include alternative default service provided
by a municipal or county aggregator under RSA 53-E.
Source. #2050, eff 6-13-82; ss by #2912, eff
11-26-84; EXPIRED 11-26-90
New. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09;
ss by #9998, eff 9-20-11; ss by #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
(from Puc 902.06)
New. #10757, eff 1-8-15;
ss by #13080, eff 9-14-20 (formerly Puc 902.07)
Puc 902.08 “Distribution Utility”
means the company that owns and/or operates the distribution facilities
delivering electricity to the customer-generator’s premises,
and includes a rural electric cooperative for which a certificate of
deregulation is on file with the commission.
Source. #9515, eff 7-18-09;
ss by #9998, eff 9-20-11 (from Puc 902.05); ss by
#10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14 (from Puc
902.07)
New. #10757, eff 1-8-15; ss by #13080, eff 9-14-20 (formerly Puc 902.05)
Puc 902.09
“Electric Utility Customer” as used in
the definition of “customer-generator” means any retail ratepayer of a
distribution utility.
Source. #9515, eff 7-18-09;
ss by #9998, eff 9-20-11; ss by #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
(from Puc 902.08)
New. #10757, eff 1-8-15;
ss by #13080, eff 9-14-20 (formerly Puc 902.06)
Puc 902.10 “Electricity Suppliers”
means “electricity suppliers” as defined in RSA 374-F:2, II, namely “suppliers
of electricity generation services and includes actual
electricity generators and brokers, aggregators, and pools that arrange for the
supply of electricity generation to meet retail customer demand, which may be
municipal or county entities.”
Source. #9998, eff 9-20-11 (from Puc
902.06); ss by #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15
(from Puc 902.09) ; ss by #13080, eff 9-14-20 (formerly
Puc 902.07)
Puc 902.11 “Eligible Fuel”
means “eligible fuel” as defined in RSA 362-A:1-a, II-c, namely, “natural gas,
propane, wood pellets, hydrogen, or heating oil when combusted with a burner,
including air emission standards for the device using the approved fuel.”
Source. #9998, eff 9-20-11;
ss by #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14 (from Puc
902.09)
New. #10757, eff 1-8-15
(from Puc 902.10); ss by #13080, eff 9-14-20 (formerly
Puc 902.08)
Puc 902.12 “End-User Customer”
means any person or entity that purchases
electricity supply at retail in New Hampshire from another person or entity, with the exception of a generating facility taking station
service at wholesale from the regional markets administered by ISO New England,
Inc. or its successor independent system operator or regional market administrator.
Source.
#13080, eff 9-14-20
Puc 902.13 “Facility” means
the electricity generating equipment, powered by renewable energy or that
employs a heat led combined heat and power system, interconnected with the
electric distribution system through any one retail meter or more than one
retail meter, installed or to be installed in accordance with Puc 903.03.
Source. #9998, eff 9-20-11
(from Puc 902.08); ss by #10502, INTERIM, eff 1-3-14,
EXPIRED: 7-2-14 (from Puc 902.10)
New. #10757, eff 1-8-15
(from Puc 902.12); ss by #13080, eff 9-14-20 (formerly
Puc 902.09)
Puc 902.14
“Federal Poverty Guidelines” means the federal poverty guidelines
updated periodically in the federal register by the U.S. Department of Health
and Human Services under the authority of 42 U.S.C. §9909(2).
Source. #13080, eff 9-14-20
Puc 902.15 “Generating Capacity”
means, for inverter-based units, the maximum generating capacity alternating
current kilowatt rating of the inverters, and for other interconnections, the
nameplate capacity kilowatt rating of the generating facility.
Source. #9998, eff 9-20-11 (from Puc
902.09); ss by #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15
(from Puc 902.14); ss by #13080, eff 9-14-20 (formerly
Puc 902.10)
Puc 902.16 “Group” means one
or more members who are customers of the same distribution utility who have
signed an agreement with a host as required by RSA 362-A:9, XIV. A group can include a host and a member that
are the same entity or person.
Source. #10502, INTERIM, eff
1-3-14, EXPIRED: 7-2-14 (from Puc 902.12)
New. #10757, eff 1-8-15
(from Puc 902.15); ss by #13080, eff 9-14-20 (formerly
Puc 902.11)
Puc 902.17 “Heat Led” means “heat led” as defined in RSA
362-A:1-a, II-d, namely, “that the combined heat and power system is operated
in a manner to satisfy the heat usage needs of the customer-generator.”
Source. #10502, INTERIM, eff
1-3-14, EXPIRED: 7-2-14 (from Puc 902.13)
New. #10757, eff 1-8-15
(from Puc 902.16); ss by #13080, eff 9-14-20 (formerly
Puc 902.12)
Puc 902.18 “Host” means a customer-generator
that elects to assume the duties and obligations of RSA 362-A:9, XIV, who is,
and who remains during the term of the agreement, a customer of the same
distribution utility as the group.
Source. #10502, INTERIM, eff
1-3-14, EXPIRED: 7-2-14 (from Puc 902.14)
New. #10757, eff 1-8-15
(from Puc 902.17); ss by #13080, eff 9-14-20 (formerly
Puc 902.13)
Puc 902.19 “Islanding” means a
condition in which a portion of the utility system that contains both load and
dispersed generation is isolated from the remainder of the utility system.
Source. #10502, INTERIM, eff
1-3-14, EXPIRED: 7-2-14 (from Puc 902.15)
New. #10757, eff 1-8-15; ss
by #13080, eff 9-14-20 (formerly Puc 902.14)
Puc 902.20 “Large Customer-Generator”
means a customer-generator whose facility has a total maximum generating capacity
greater than 100 kilowatts alternating current up to and including one
megawatt.
Source. #10757, eff 1-8-15
(from Puc 902.19); ss by#13080, eff 9-14-20 (formerly
Puc 902.15)
Puc 902.21 “Low-Moderate Income Community Solar Project”
means “low-moderate income community solar project,” as defined in RSA 362-F:2,
X-a, namely, “ground-mounted or rooftop solar arrays that directly benefit a
group of at least 5 residential end-user customers, where at least a majority
of the residential end-user customers are at or below 300 percent of the
federal poverty guidelines.”
Source. #13080, eff 9-14-20
Puc 902.22 “Member” means a
customer of the same distribution utility as the host, who signs an agreement
to be a member of a group under RSA 362-A:9, XIV, who remains a customer of the
same distribution utility as the host during its membership in the group, and,
except as provided in Puc 902.16, who is not a
customer-generator.
Source. #10502, INTERIM, eff
1-3-14, EXPIRED: 7-2-14 (from Puc 902.12)
New. #10757, eff 1-8-15
(from Puc 902.15); ss by, eff 9-14-20 (formerly Puc 902.16)
Puc 902.23 “Net Energy Metering”
means “net energy metering” as defined in RSA 362-A:1-a, III-a, namely,
“measuring the difference between the electricity supplied over the electric
distribution system and the electricity generated by an eligible
customer-generator which is fed back into the electric distribution system over
a billing period.”
Source. #10502, INTERIM, eff
1-3-14, EXPIRED: 7-2-14 (from Puc 902.13)
New. #10757, eff 1-8-15
(from Puc 902.16); ss by #13080, eff 9-14-20 (formerly
Puc 902.17)
Puc 902.24 “Non-Bypassable Charges” means charges assessed on the full
amount of electricity imports without any netting during the applicable billing
period, including such charges as the system benefits charge, stranded cost
recovery charge, and storm recovery surcharge.
Source. #13030, eff 9-14-20
Puc 902.25 “Renewable Energy”
means electricity produced by renewable resources including geothermal, tidal
or wave, wind, solar, landfill gas, hydro, biomass, bio-oil, bio-synthetic gas,
and biodiesel resources.
Source. #10502, INTERIM, eff
1-3-14, EXPIRED: 7-2-14 (from Puc 902.14)
New. #10757, eff 1-8-15
(from Puc 902.17); ss by #13080, eff 9-14 20
(formerly Puc 902.18)
Puc 902.26 “Small Customer-Generator”
means a customer-generator whose facility has a total maximum generating
capacity of not more than 100 kilowatts alternating current.
Source. #10502, INTERIM, eff
1-3-14, EXPIRED: 7-2-14 (from Puc 902.15)
New. #10757, eff 1-8-15;
ss by #13080, eff 9-14-20 (formerly Puc 902.19)
Puc 902.27 “Standard Net Metering
Tariff ” means the net energy metering tariff provisions as specified in RSA
362-A:9, as applicable to customer-generators receiving a utility net metering
capacity allocation prior to September 1, 2017 and not
in excess of the net metering cap applicable prior to commission adoption of
the alternative net metering tariff.
Source. #13080,
eff 9-14-20
Puc 902.28 “Witness Test”
means the process used by the electric distribution utility following the
interconnection of a customer-generator’s facility to determine whether the
interconnection affects the safety, reliability, or power quality of the
utility’s distribution system.
Source. #10757, eff 1-8-15
(from Puc 902.19); ss by #13080, eff 9-14-20
(formerly Puc 902.28)
PART Puc 903 CONDITIONS TO INTERCONNECTION
Puc
903.01 General Rules, Rights, and
Obligations.
(a) Any
distribution utility and any electricity supplier operating within the state of
New Hampshire shall, upon request, provide net energy metering to
customer-generators pursuant to Puc 900 and RSA 362-A:9.
(b) A distribution utility shall comply with Puc 900 in a non-discriminatory manner and shall not
unreasonably withhold its permission to interconnect a customer-generator’s
facility.
(c) Any electricity supplier operating within New
Hampshire that is not the default service provider shall offer net metering
pursuant to Puc 900, but may
provide for rates and terms as provided in RSA 362-A:9, II and Puc 903.02(g).
(d) Any customer-generator who engages in net
energy metering in New Hampshire shall comply with Puc
900.
(e) A customer-generator shall comply with:
(1) Applicable
commission-approved rules, tariffs, and terms and conditions of the
distribution utility not in conflict with Puc 900;
(2) Any local, state, or
federal law, statute, rule, or regulation which applies to the design, siting,
construction, installation, operation, or any other aspect of the customer-generator’s
facility and associated interconnection; and
(3) Interconnection
requirements of the distribution utility as set forth in its tariff on file
with the commission.
(f) Interconnection
with the distribution utility under Puc 900 shall not
authorize a customer-generator to utilize the distribution utility’s electric
distribution system for the transmission or distribution of electric power.
(g) The distribution utility shall have the right
to review the design of a customer-generator’s facility and associated
interconnection and to inspect such facility and interconnection prior to the
commencement of facility operations.
(h) The distribution utility shall require a
customer-generator to make modifications to its facility as necessary to comply
with the requirements of Puc 900.
(i) The distribution
utility’s review and authorization for operation shall not be construed as
confirming or endorsing the customer-generator’s design or as warranting the
safety, durability, or reliability of the facility or associated
interconnection.
(j) The distribution utility shall not, by reason
of such review or lack of review, be responsible for the strength, adequacy, or
capacity of the facility’s equipment.
(k) A customer-generator’s facility and associated
interconnection shall be reasonably accessible to the distribution utility’s
personnel as necessary for the utility to perform its duties and exercise its
rights under its tariffs and terms and conditions filed with and approved by
the commission and under Puc 900.
(l) Any information pertaining to a facility and
associated interconnection that is provided to a distribution utility by a
customer-generator shall be treated by the utility in a confidential manner.
(m) A customer-generator shall operate and
maintain its facility and associated interconnection in a manner that is safe
and reliable.
(n) A customer-generator shall be responsible for
all costs associated with interconnection of the customer-generator’s facility
to the distribution system, as provided under RSA 362-A:9, XIII.
Source. #2050, eff 6-13-82; ss by #2912, eff 11-26-84;
EXPIRED 11-26-90
New. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
Puc
903.02 Statutory and Other
Requirements.
(a) Electric distribution utilities shall make
net energy metering available to customer-generators, pursuant to RSA 362-A:9
and Puc 900.
(b) Eligibility for net energy metering shall be
available on a first-come, first-served basis within each distribution utility
service area under the jurisdiction of the commission, provided that the
standard net metering tariff provisions are available only until the total
rated generating capacity owned and operated by customer-generators within the
respective utility service area exceeds the following amounts:
(1) Liberty Utilities (Granite
State Electric) Corp. d/b/a Liberty Utilities, 8.74 MW;
(2) New Hampshire Electric
Cooperative, Inc., 3.16 MW;
(3) Public Service Company
of New Hampshire d/b/a Eversource Energy, 75.38 MW; and
(4) Unitil
Energy Systems, Inc., 12.72 MW.
(c) No more than 4 MW of such total rated
generating capacity eligible for the standard net metering tariff throughout
New Hampshire shall be from combined heat and power systems.
(d) A large customer-generator subject to the
alternative net metering tariff shall be eligible for net energy metering only
if at least 20 percent of the actual or estimated annual electricity generation
from its facility is consumed behind-the-meter, unless it has registered as a
group host under RSA 362-A:9, XIV and Puc 909.
(e) Customer-generators subject to the standard
net metering tariff may switch to the alternative net metering tariff upon
written notice to the distribution utility, but any such customer-generators shall not return to the standard net metering
tariff terms once they have switched.
Any such customer-generators that switch to the alternative net metering
tariff shall be grandfathered pursuant to RSA 362-A:9, XVI and commission order
26,029.
(f) Metering shall be done in accordance with
normal metering practices as follows:
(1) Except as provided for
in (3) and (5) below, small customer-generators subject to the standard net
metering tariff shall have a
single net meter that internally measures the inflow and outflow of electricity
such that the net electricity usage or production can be periodically read, and
the small customer-generators shall not be required to pay for the installation
of that meter;
(2) Large
customer-generators shall have a bi-directional metering system that records
the total amount of electricity that the customer receives from the
distribution utility and the total amount of electricity exported. Such meter shall record measurements instantaneously
or over intervals of an hour or less. Large
customer-generators shall pay for the installation of the bidirectional
metering system;
(3) A distribution utility
may install an additional meter or meters to monitor the flow of electricity in
each direction for a small customer-generator subject to the standard net
metering tariff, provided that it is not at the expense of the small
customer-generator, unless the additional metering is requested by the small
customer-generator;
(4) A distribution utility
may install a net meter that measures energy usage or production at intervals
of an hour or less, provided that it is not at the expense of the small
customer-generator unless the interval meter is requested by the small
customer-generator;
(5) If the output of the
customer-generator’s facility will be measured for the purposes of recording
renewable energy output under RSA 362-F, a second meter measuring the production
of electricity from the facility may be installed at the customer-generator’s
expense, except as otherwise provided in (8) below;
(6) If an additional meter
or meters are installed, as described in (3) or (5) above, or (8) below, the
net energy metering calculation shall yield the same result as when a single
meter is used, pursuant to RSA 362-A:9;
(7) Small customer-generators subject to the
alternative net metering tariff shall have bi-directional meters installed to record in
separate channels the quantities of electricity imports from the distribution
utility system and electricity exports to the distribution utility system over
a billing cycle; and
(8) If, at the time of
interconnection, a small customer-generator subject to the alternative net
metering tariff requests that
the distribution utility install a second utility-owned meter measuring the production
of electricity from the facility, the utility shall install such a production
meter at no cost to the customer-generator.
The small customer-generator shall provide and install a meter socket in
a physical location acceptable to the utility.
(g) A customer-generator shall be billed for
electricity under the same rate schedule that such customer-generator would be
billed if it had no generation.
(h) Competitive electricity suppliers registered
under RSA 374-F:7 and Puc 2000 may voluntarily
determine the terms, conditions, and prices under which they shall agree to
provide electric energy supply to, and purchase net electric energy output from,
customer-generators.
(i) Pursuant to RSA
362-A:9, the following shall apply to net energy metering for small
customer-generators subject to the standard net metering tariff and billed on a
rate schedule that is not time-based:
(1) The net electricity
received or exported over a billing period shall be measured in accordance with
normal metering practices;
(2) Charges that are not
based on kilowatt-hours, including the customer charge and demand-based
charges, shall be billed in accordance with the applicable rate schedule;
(3) If the electricity received
by the customer-generator from the distribution system exceeds the electricity exported
to the distribution system by the customer-generator during the billing period,
the customer-generator shall be billed based on the net energy received in
accordance with the applicable rate schedule, net of any credits pursuant to
(5) a. below;
(4) If the electricity exported
to the distribution system by the customer-generator exceeds the electricity received
from the distribution system over the billing period:
a. The surplus electricity exported
to the distribution system shall be calculated by subtracting the kilowatt-hours
received from the distribution system from the kilowatt-hours exported to the
distribution system over the billing period; and
b. The distribution utility
shall use zero kilowatt-hours when calculating all charges that are based on kilowatt-hour
usage;
(5) If the electricity exported
to the distribution system by the customer-generator exceeds the electricity received
from the distribution system over any billing period, the customer-generator
shall be:
a. Credited over subsequent
billing periods for the surplus electricity exported to the distribution system
and all associated kilowatt-hour-based charges; or
b. For default service
customers, if the surplus electricity production exceeds 600 kilowatt-hours,
the customer-generator may elect, on an annual basis, to receive a payment from
the distribution utility equal in amount to the economic value of accumulated
surplus as calculated pursuant to (n) below; and
(6) Customer-generators subject to the standard net metering tariff shall
be grandfathered pursuant to RSA 362-A:9, XV and commission order 26,029.
(j) The following shall apply to small
customer-generators subject to the alternative net metering tariff:
(1) The net electricity
received or exported over a billing period shall be measured in accordance with
normal metering practices;
(2) Charges that are not
based on kilowatt-hours, including the customer charge and demand-based
charges, shall be billed in accordance with the applicable rate schedule;
(3) Non-bypassable charges shall be assessed
based on the full amount of electricity received from the distribution system
without any netting of electricity exports over the billing period;
(4) If the electricity exported
to the distribution system by the customer-generator exceeds the electricity received
from the distribution system over the billing period:
a. The surplus electricity exported to the
distribution system shall be calculated by subtracting the kilowatt-hours
received from the distribution system from the kilowatt-hours exported to the
distribution system over the billing period; and
b. The distribution utility shall use zero kilowatt-hours
when calculating all charges, except non-bypassable
charges, that are based on kilowatt-hour usage;
(5) If the electricity
exported to the distribution system by the customer-generator exceeds the
electricity received from the distribution system over any billing period, the
customer-generator shall:
a. Receive a monetary bill
credit for net electricity exports over the billing period calculated at 25
percent of any distribution charges assessed on a per-kilowatt-hour basis, any transmission
charges assessed on a per kilowatt-hour basis, and, for default service
customers, the default service rate assessed on a per kilowatt-hour basis;
b. Carry
forward the monetary credits to subsequent billing periods until used; and
c. Elect to receive a payment
from the distribution utility, on an annual basis, equal to the amount of the
accrued monetary bill credit balance which exceeds $100 as of the end of the
March billing period; and
(6) Customer-generators subject to the alternative net metering tariff shall be grandfathered
pursuant to RSA 362-A:9, XVI and commission order 26,029.
(k) Pursuant to RSA 362-A:9, the following shall
apply to net energy measurements for large customer-generators subject to the
standard net metering tariff:
(1) The net electricity
received or exported over a billing period shall be measured in accordance with
normal metering practices;
(2) All charges that are
not based on kilowatt-hours, including the customer charge and demand-based
charges, shall be billed in accordance with the applicable rate schedule;
(3) If the electricity received
by the customer-generator from the distribution system exceeds the electricity exported
to the distribution system by the customer-generator over the billing period,
the customer-generator shall be billed all applicable charges on all kilowatt
hours received by the customer from the
distribution system, less a credit on default service charges, for those
customer-generators on utility default service, equal to the metered electricity
exported to the distribution system over the billing period;
(4) If electricity exported
to the distribution system by the customer-generator exceeds the electricity received
from the distribution system over the billing period:
a. The surplus electricity exported to the
distribution system shall be calculated by subtracting the kilowatt-hours
received from the distribution system from the kilowatt-hours exported to the
distribution system over the billing period; and
b. The distribution utility shall use zero kilowatt-hours
when calculating all default service charges. The customer-generator shall be
billed for all other applicable charges on all kilowatt-hours received by the
customer from the electric distribution system;
(5) If
the electricity exported to the distribution system by the customer-generator
exceeds the electricity received by the customer-generator from the
distribution system over any billing period, the customer-generator shall be:
a. Credited for surplus electricity exported to
the distribution system over subsequent billing periods for default service
charges only, for those customer-generators on utility default service; or
b. For default service customers, the
customer-generator may elect on an annual basis to receive a payment from the
distribution utility equal in amount to the economic value of the accumulated
surplus as calculated pursuant to (n) below; and
(6) Large customer-generators
subject to the standard net metering tariff shall be grandfathered pursuant to RSA 362-A:9, XV.
(l) The following shall apply to net energy
measurements for large customer-generators subject to the alternative net
metering tariff:
(1) The net electricity
exported or received over a billing period shall be measured in accordance with
normal metering practices;
(2) All charges that are
not based on kilowatt-hours, including the customer charge and demand-based
charges, shall be billed in accordance with the applicable rate schedule;
(3) If the electricity received
by the customer-generator from the distribution system exceeds the electricity exported
to the distribution system by the customer-generator over the billing period,
the customer-generator shall be billed for all applicable charges on all
kilowatt-hours received by the customer from the distribution system, less a
credit on default service charges, for those customer-generators on utility
default service, equal to the metered electricity exported to the distribution
system over the billing period;
(4) If the electricity
exported to the distribution system by a customer-generator on utility default
service exceeds the electricity received from the distribution system over the
billing period:
a. The surplus electricity exported to the
distribution system shall be calculated by subtracting the kilowatt-hours received
from the distribution system from the kilowatt-hours exported to the
distribution system over the billing period; and
b. The distribution utility shall use zero
kilowatt-hours when calculating all default service charges. The
customer-generator shall be billed for all other applicable charges on all
kilowatt-hours supplied to the customer from the electric distribution system;
c. Customers who receive default service shall
receive a monetary bill credit for surplus electricity exported, calculated at
the default service rate assessed on a per kilowatt-hour basis;
d The
monetary credits shall carry forward to subsequent
billing periods until used; and
e. If the monetary credit
balance exceeds $100 as of the end of the March billing period, on an annual basis,
the customer-generator may elect to receive a payment from the
distribution utility; and
(5) Large customer-generators subject to the
alternative net metering tariff shall be grandfathered pursuant
to RSA 362-A:9, XVI and commission order 26,029.
(m) For customer-generators subject to the
standard net metering tariff, on or before June 1 of each year, each
distribution utility shall provide to customer-generators taking default
service that have accumulated a surplus in excess of
600 kilowatt-hours at the end of their March billing cycle written notice that
provides:
(1) The number of accumulated surplus kilowatt-hours;
(2) A statement that the
customer-generator will continue to accumulate any net surplus unless it elects
one of the following 2 options:
a. Receive a bill credit equal to the economic
value of the applicable surplus; or
b. Elect payment by check of the economic value
of the surplus;
(3) The capacity in kilowatts,
if any, associated with such surplus generation, whether actual, pursuant to (n)(5)
below, or estimated, pursuant to (n)(6) or (7) below, as applicable; and
(4) The average rate,
expressed in dollars or cents per kilowatt-hour, that the energy component of
such surplus will be valued at, the rate for the capacity value of such
surplus, expressed in dollars or cents per kilowatt, and the total economic
value of such surplus, expressed in dollar and cents.
(n) For customer-generators subject to the
alternative net metering tariff, on or before June 1 of each year, each
distribution utility shall provide to customer-generators that have accumulated
monetary bill credits of $100 or more at the end of their March billing cycle
written notice that provides:
(1) The total accumulated monetary bill credits;
(2) A statement that the
customer-generator will continue to carry forward any net monetary bill credits
unless it elects to receive payment by check; and
(3) A description of the
process through which the customer-generator may elect to receive payment by check
of the balance of such accumulated monetary bill credits.
(o) Unless an
electric distribution utility elects otherwise as provided in (p) below, and
except as may be provided otherwise pursuant to (v) below, the commission shall
annually determine the rates for utility avoided costs for energy and capacity
consistent with the requirements of the Public Utilities Regulatory Policy Act
of 1978 (PURPA) (16 USC § 824a-3 and 18 CFR § 292.304) and as set forth below:
(1) On or before May 15 of
each year, the commission shall publish on its website its calculation of the
rates for avoided costs of energy and capacity for the previous year ending
March 31, to be used by utilities to calculate the economic value of surplus
net-metered generation for the previous year, which may be paid or credited to
customer-generators subject to the standard net metering tariff, starting in
the June billing cycle, along with supporting calculations, an explanation of
assumptions and data sources, and estimated portions of annual surplus
generated during the hour or hours used to calculate avoided capacity costs
pursuant to (6) and (7) below, capacity factors, if actual hourly surplus
generation data is not used for such calculation pursuant to (5) below;
(2) The rates for avoided
energy costs shall be based on the short-term avoided energy costs for the New
Hampshire load zone in the wholesale electricity market administered by ISO New
England, Inc., consisting of the hourly real time locational marginal price
(LMP) of electricity plus generation-related ancillary service charges, all
adjusted for the average line loss in New Hampshire between the wholesale
metering point and the retail metering point;
(3) The rate for the
avoided generation related capacity costs shall be based on the applicable ISO
New England, Inc. Forward Capacity Market (FCM) price for the power year most
closely matching the 12 months ending in the March billing cycle. The avoided FCM price shall be adjusted to
account for any peak energy rent payments made from the energy market that
reduce direct capacity costs charged to load and for average line loss in New
Hampshire between the wholesale metering point and the retail metering point. Such adjusted price shall be used to determine
the rate for avoided capacity costs in dollars per kilowatt to be used by
utilities to calculate the value of generation capacity associated with surplus
generation on a customer-by-customer basis. If there is more than one hour in
each power year on which ISO New England, Inc. allocates FCM costs to load, the
commission shall structure the rate proportionally to ISO New England, Inc.’s
allocation of such costs;
(4) In determining the
customer-specific value of avoided capacity costs, each utility shall multiply
the quantity (in kilowatts) of each customer-generator’s surplus generation exported
to the distribution system at the hour or hours of capacity peak with respect
to which FCM costs are allocated to load, whether actual, pursuant to (5)
below, or estimated, pursuant to (6) or (7) below, as applicable, by the rate
or rates determined by the commission pursuant to (1) and (3) above;
(5) If hourly meter data is available for a customer-generator’s net meter
and the utility has the technical capability to utilize that data for avoided
cost calculations, the utility, at its election by written notice to the
commission on or before June 1 of each year, shall calculate the value of
avoided capacity costs or avoided energy costs, or both, for each such
customer-generator using actual hourly surplus generation data. The value of
avoided energy costs shall be individually calculated by weighting the actual
avoided energy costs for each hour of the 12 months ending the immediately
preceding March 31, as determined by the commission pursuant to (1) and (2)
above, by the actual hourly surplus electricity exported to the distribution
system in each hour for the same period to determine a customer-specific
average rate for the energy value of net surplus generation;
(6) For all types of net-metered
systems other than solar photovoltaic (PV) systems, and for which actual hourly
data is not utilized pursuant to (5) above:
a. The rate for avoided energy
costs shall be calculated by using a simple average of hourly cost data from
ISO New England, Inc. for the 12 months ending the immediately preceding March
31, assuming that surplus generation is, on average, equally distributed over
all hours of the year; and
b. The portion of surplus
generation estimated to be produced during the hour or hours of capacity peak
on which FCM costs are allocated to load shall be equal to the number of such
hours divided by 8,760;
(7) For net-metered PV
systems for which actual hourly data is not utilized pursuant to (5) above, the
rate for avoided energy costs shall be calculated as a weighted average annual
rate by weighting the actual avoided costs for each hour of the 12 months
ending the immediately preceding March 31 by the hourly generation output
profile for PV systems in New Hampshire determined as follows:
a. If verifiable hourly generation output data
is available and on file at the commission by April 5 for the applicable year
from at least 25 kilowatts of PV system capacity operating within New Hampshire,
then the output profile for PV systems shall be the hourly average of all such data; or
b. If such data is not available, the hourly
generation output profile shall be the modeled hourly PV performance data
output produced by the U.S. Department of Energy, National Renewable Energy
Laboratory, PVWatts software, version 6.1.2,
(available at https://pvwatts.nrel.gov/ ) with
the default settings for Concord, New Hampshire; and
c. The portion of surplus generation estimated
to be produced during the hour or hours of capacity peak on which FCM costs are
allocated to load shall be in the same proportion as the output profile
utilized pursuant to (7) a. or b. above.
(p) To correct an error in its determination of
avoided costs, the commission shall, on its own motion, the motion of a
utility, or the motion of a third party, revise its determination of rates for
avoided costs and capacity factors as necessary. Any amounts paid or credited
at the originally published rates and capacity factors shall be subject to
reconciliation by the revised rates and factors.
(q) Annually, by
written notice to the commission on or before June 1 of each year, each
electric distribution utility may elect, by filing notice with the commission,
to purchase or value surplus generation from customer-generators subject to the
standard net metering tariff for the preceding year ending in the March billing
cycle at a rate that is equal to the energy supply component of the applicable
default service rate, instead of the avoided cost rates determined by the
commission pursuant to paragraph (n) above, provided that payment is issued to such
customer-generators at least as often as whenever the value of such credit, in
excess of amounts owned by the customer-generator, is greater than $50.
(r) Upon termination of net energy metering,
there shall be no payment or credit to a customer-generator subject to the
standard net metering tariff for any remaining excess generation.
(s) For customer-generators subject to the alternative
net metering tariff, upon termination of net energy metering the utility shall
pay to such customer-generators an amount equal to the accumulated balance of
any monetary bill credits.
(t) The commission shall waive any provision of Puc 900 or RSA 362-A, by order after notice and an
opportunity for a hearing, if it determines that waiver of the applicable
statute or rule section is a targeted net energy metering arrangement that is part of a utility strategy to minimize
distribution costs, pursuant to RSA 362-A:9.
(u) The commission shall consider any request for
a waiver, whether filed pursuant to (s) above or otherwise, pursuant to Puc 201.05.
(v) A distribution utility may perform an annual
calculation to determine the net effect of net metering on its default service
and distribution revenues and expenses in the prior calendar year. Pursuant to Puc 203,
the commission shall determine by order, after notice and hearing, the
utility-specific method of performing the calculation and applying the results,
as well as a reconciliation mechanism to collect or credit any such net effects
with appropriate carrying charges and credits applied.
(w) Pursuant to Puc
203, upon petition by a utility or on its own motion, the commission shall, by
order, after notice and hearing, establish on a utility-specific basis a
methodology by which customer-generators shall be provided service under
time-based net energy metering tariffs, provided that
it determines the resulting rates are just and reasonable and in accordance
with RSA 362-A:9, VIII.
(x) Renewable energy certificates associated with
the customer-generator’s facility shall remain the property of the customer-generator
until such certificates are sold or transferred.
(y) The following
grandfathering provisions shall apply to customer-generators subject to either
the standard net metering tariff or the alternative net metering tariff:
(1) Subsequent sales or other transfers of
ownership of a net-metered facility or the property upon which the facility is
located shall not affect the terms and conditions under which the
customer-generator is rendered net metering service. New owners may continue to take service under
the same terms and conditions in effect at the time of such sale or transfer and grandfathered pursuant to RSA 362-A:9, XV,
RSA 362-A:9, XVI, and commission order 26,029.
Following that date, the new owners shall transition to tariffs that are
in effect at the time, provided that the facility is not moved to
a different location by the purchaser, transferee, or otherwise;
(2) Residential small customer-generators may
expand the capacity of their facilities without limitation, provided that the
expansion does not result in total facility capacity in excess of 100 kilowatts,
and remain subject to the same applicable net metering tariff;
(3) A non-residential small customer-generator may
expand the capacity of its facility by an amount up to the greater of either 20
kilowatts or 50 percent of the system capacity allocated into the standard net
metering tariff program prior to September 1, 2017, or 50 percent of the
original capacity of a facility installed under the alternative net metering
tariff, as applicable, provided that in neither case shall such expansion have
the effect of increasing the facility’s capacity to an amount in excess of 100 kilowatts;
(4) A non-residential large customer-generator may
expand the capacity of its facility by an amount up to the greater of either:
a. 50 kilowatts,
or
b. a capacity
amount such that the expanded facility is sized to produce 110 percent of the
customer-generator’s annual kilowatt-hour on-site usage, as clearly
demonstrated through the customer-generator’s documentation of any consecutive
12 months within the previous 2 years;
(5) No such expansion under (3) or (4) shall have
the effect of increasing the facility’s capacity to a level in
excess of one megawatt. Expansion of a net-metered facility by or for a non-residential
customer-generator smaller than the applicable limitation shall allow the
customer-generator to continue to be grandfathered under the applicable net
metering tariff, while any such expansion in excess of
the applicable limitation hall result in the entire net-metered facility losing
its net metering grandfathered status under the applicable net metering tariff;
and
(6) Any facility expansion or other modification shall
be reported to the distribution utility within 30 days of expansion or modification,
or earlier if so required under the utility’s
distributed generation interconnection procedures.
Source. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
Puc 903.03 Where Multiple Projects Are Deemed a Single Facility.
(a) Except as otherwise provided in (c) below,
projects consisting of electricity generating equipment powered by an eligible
renewable energy source or that employ a heat led combined heat and power system,
and located behind separate retail meters, shall be deemed to be one facility
for purposes of net metering eligibility if the projects are owned by the same
person or entity or an affiliate of said person or entity and are located on
the same parcel of land or adjacent and contiguous parcels of land, unless each
of the following conditions applies:
(1) Each project is located on
a separate parcel of land;
(2) The property boundaries of
each parcel of land have not been subdivided, modified, or otherwise altered
within the 10 years immediately preceding the submission of a project interconnection
request to the distribution utility;
(3) Each project is owned by a
separate individual or by a separate corporation, limited liability company, or
other legal entity; and
(4) Each project is
interconnected with the utility distribution system through a separate
interconnection point and with a separate meter.
(b)
The restrictions set forth in (a) above shall apply to two or more
projects notwithstanding any phased approach to development or different
construction schedules for such projects.
(c) Multiple projects located on
the same or adjacent and contiguous parcels of land, when such projects are
owned by the same person or entity or an affiliate of said person or entity and
are interconnected behind separate retail electricity meters, shall be
considered separate facilities if each such project is being or has been
developed:
(1) Such that not less than 50
percent of the annual generation output is to serve the on-site load of
existing or new retail electric customers;
(2) To participate in a
different electric generation program, such as net metering, direct
producer-to-consumer retail sales of electric power, or wholesale sales of electric
power;
(3) Using a solar photovoltaic
system that is limited in size to that which will fit on the roof and exterior
envelope of the building or buildings served by the retail electricity meter
through which the system is interconnected to the electric distribution system;
or
(4)
Using distinct and different electricity generating technologies and
equipment that can be operated independently.
(d) As used in this section, “affiliate” means
any of the following:
(1) Any person or entity that directly or
indirectly owns, controls, or holds with power to vote a majority of the outstanding voting
securities or such minority thereof as to give such person substantial control
of another person or entity;
(2) Any person or entity that is directly or
indirectly owned, controlled, or held by any person or entity described in (1)
above through either power to vote a majority of the outstanding voting
securities or such a minority so as to maintain substantial control of such
person or entity;
(3) Any person or entity with which another person
or entity has a management or service contract or arrangement that provides
such person or entity with effective control over the management, supervision,
or operation of the other person or entity; or
(4) Any person or entity who or which actually exercises effective control over the management,
supervision, or operation of another person or entity.
Source.
#13080, eff 9-14-20
PART Puc 904 INTERCONNECTION APPLICATION PROCESS
Puc
904.01 Pre-Application Review.
(a) Before purchasing or installing net energy
metering equipment, a customer-generator may request that the distribution
utility informally review the proposed project and provide information on:
(1) Whether the
customer-generator’s facility and electric distribution system interface, in
the opinion of the distribution utility, is likely to comply with the
requirements of Puc 900; and
(2) Whether the
customer-generator is in an area or service location which is likely to require
any upgrade or study.
(b) At the pre-application stage, the distribution
utility shall provide the customer-generator its best evaluation, given the
information it has available, but shall not be required to conduct a study or extensive
review of the proposed project.
Source. #2050, eff 6-13-82; ss by #2404, eff 6-28-83;
ss by #2912, eff 11-26-84; EXPIRED 11-26-90
New. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09; ss by #9998, eff 9-20-11;
ss by #13080, eff 9-14-20
`Puc 904.02 Interconnection
Application.
(a) To initiate the process to engage in net
energy metering, a customer-generator shall file with its distribution utility
and, if applicable, its electricity supplier, an interconnection application.
(b) When filing an application with the
distribution utility, to obtain evidence of the filing and the date of filing,
the applicant shall:
(1) File the application by
certified mail;
(2) Obtain a dated acknowledgment
of receipt from the distribution utility; or
(3) Obtain written or
electronic verification of receipt from the distribution utility by other means
consistent with (1) and (2) above.
(c) The interconnection application shall include
the following:
(1) Applicant
information which shall include:
a. The
customer-generator’s name;
b. The customer-generator’s full mailing address;
c. The facility location, if different from the
address listed pursuant to b. above;
d. The customer-generator’s daytime and evening
telephone numbers;
e. The information provided in a., b., and d.
above for an alternative contact person when the customer-generator is unavailable;
f. The name of the local distribution utility
and the customer-generator’s account number; and
g. If different than the distribution utility,
the name of the customer-generator’s electricity supplier and the
customer-generator’s account number with that supplier;
(2) Generating
facility information, including:
a. The generator type, whether solar, wind,
hydroelectric, or other renewable energy source used to generate electricity, as
listed in RSA 362-F:4, I (a) through (k);
b. The generator
manufacturer, model name, and model number;
c. The number of phases of the unit, whether
single or 3-phase;
d. The power rating of the generation output of
the system in kilowatts;
e. If applicable, the inverter manufacturer,
model name, and model number;
f. Whether or not a storage system will be used in
connection with the facility; and
g. Whether an exterior manual disconnect switch
for utility use shall be installed, if the capacity size of the facility is
less than or equal to 10 kilowatts; and
(3) Installation
information and certification, which shall include:
a. Whether the
generator will be installed by the owner;
b. The
installation date;
c. The anticipated interconnection date;
d. The name,
complete address, telephone number, and license number of the installing
electrician, if applicable;
e. The name and company
affiliation of the vendor selling the generator to the customer-generator;
f. The signature,
with the date of signature, of the vendor, certifying that the facility
hardware is in compliance with Puc 900;
g. Certification,
if applicable, that the facility has been installed in compliance with the
local municipal building and electrical codes in the form of:
1. A signed and
dated certificate by the applicable local code official; or
2. A copy of a
signed and dated final inspection certificate from the municipality;
h. A signed and
dated certification by the customer-generator that:
1. The
customer-generator has installed and shall operate the generation system in
compliance with applicable electrical standards;
2.
The initial start-up test required by Puc
905.04 has been successfully completed; and
3. To the best of
the customer-generator’s knowledge, all of the
information contained in the interconnection notice is true and correct; and
i. Any information provided
under Puc 904.01.
(d) A customer-generator may submit an
interconnection application to its distribution utility when the
customer-generator’s facility has not been fully installed and tested, but
shall:
(1) Provide in writing in
connection with the interconnection application, a description of any manner in
which the facility is not fully connected and tested, or is not yet otherwise
in compliance;
(2) Fulfill any unmet
requirements prior to interconnection of the facility; and
(3) Upon completion of any
unmet interconnection requirements, provide the distribution utility with any
necessary updated written certifications required by this part.
(e) The distribution utility shall not
interconnect the facility until all requirements pursuant to (c) and (d) above have
been met.
(f) Upon request, the distribution utility shall
provide to the customer-generator written confirmation that the interconnection
application has been received and the date of receipt as follows:
(1) If the application is
filed in person, immediately; or
(2) If the application is
filed by mail or other means, within 10 business days of receipt, with written
acknowledgement that states that:
a. The application is
complete; or
b. That the application is
incomplete and specifying the information necessary to complete the application
requirements.
(g) When the distribution utility provides a
receipt for an application, it may clarify that the receipt acknowledges the
date and fact of a filing, but not approval of the filing.
Source. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
Puc 904.03 Mutual Indemnity
Provision.
(a) Unless both parties to the agreement have
agreed, pursuant to (g) below, to not enter into or
maintain the mutual indemnity agreement, prior to interconnection, the
customer-generator, his or her distribution utility, and, if applicable, the
customer-generator’s electricity supplier, shall:
(1) Execute the mutual
indemnity agreement described in (b) below; and
(2) Maintain the terms of
the agreement while the net energy metered unit is interconnected.
(b) With regard to
the mutual indemnity agreement, each party to the agreement shall provide as
follows:
(1) Each party shall hold
harmless and indemnify the other party, and its directors, officers, agents and
employees, from and against any and all loss, liability, damage, or expense,
including any direct, indirect or consequential loss, liability, damage, or
expense, but not including attorneys’ fees unless awarded by a court of
competent jurisdiction, for injury or death to persons, including employees of
either party, and damage to property, including property of either party,
arising out of or in connection with intentional, willful, wanton, reckless, or
negligent conduct regarding:
a. The engineering, design, construction,
maintenance, repair, operation, supervision, inspection, testing, protection,
or ownership of the party’s facilities; or
b. Any replacements, additions, or improvements
to, or reconstruction of, the party’s facilities;
(2) Neither party shall be
indemnified by the agreement for any loss, liability, damage, or expense
resulting from its sole negligence or willful misconduct; and
(3) Notwithstanding the
indemnity provisions contained in the agreement, except for a party’s willful
misconduct or sole negligence, each party shall be responsible for damage to its
own facilities resulting from electrical disturbances or faults.
(c) The mutual indemnity agreement shall become
effective, as between the respective parties executing and exchanging the
document, upon interconnection of the customer-generator’s facility to the
electric distribution system and mutual execution and exchange of the document
by the distribution utility, the customer-generator, and, if applicable, the
electricity supplier.
(d) The
distribution utility shall also execute the mutual indemnity agreement
described in this section.
(e) The customer-generator, distribution utility,
and, if applicable, the electricity supplier, shall each execute duplicate
originals of the mutual indemnity agreement described in (b) above and each
party to the agreement shall retain one executed original of the agreement.
(f) If an electricity supplier sells electric
power to the customer-generator, it may require that the customer-generator
enter into a mutual indemnity agreement with it, as described in this section.
(g) Notwithstanding (c) through (f) above, the
customer-generator and the distribution utility with which the customer-generator
interconnects, and the electricity supplier of the customer-generator,
separately or together, may at any time, by mutual agreement, elect not to enter into or to void the indemnity agreement described in
(b) above.
(h) The provisions of the
indemnity agreement described in this section shall not be construed to relieve
any insurer of its obligation to pay any insurance claims in accordance with
the provisions of any valid insurance policy.
Source. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09; ss by #9998, eff 9-20-11; ss by #13080, eff 9-14-20
Puc 904.04 Application Completeness Review.
(a) The interconnection process shall be deemed to
have commenced when the customer-generator submits a complete application
pursuant to this part.
(b) The distribution utility shall evaluate the
application for completeness and notify the customer-generator in writing
within 10 business days of the application’s receipt whether the application is
or is not complete and, if the application is not complete, inform the
customer-generator in writing of any information required to be provided to
complete the application.
(c) The distribution utility shall verify that
the customer-generator’s facility equipment meets the requirements of Puc 905.
(d) If the distribution utility approves the
application, the distribution utility shall sign the application and return the
approved application to the customer-generator.
(e) If the distribution utility determines that
interconnection of the customer-generator’s facility would jeopardize the
safety, reliability, or power quality of the local distribution system, the
distribution utility shall require the customer-generator to pay for necessary
modifications to the distribution system before the application is approved.
(f) In the event that the distribution utility requires
the customer-generator to pay for system modifications pursuant to (e) above, the
distribution utility shall provide to the customer-generator a description of
work and an estimate of the cost to complete that work.
(g) If the customer-generator agrees to pay for the
system modifications, the customer-generator shall sign the description of the
work and submit a signed copy and the payment of the estimated costs to the
distribution utility.
(h) Upon receipt of the customer-generator’s
approval and payment, the distribution utility shall perform the system
modifications.
(i) Upon completion
of the system modifications, the distribution utility shall sign the
application approval and provide a copy of the signed approval to the
customer-generator.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09; ss by #9998, eff 9-20-11;
ss by #13080, eff 9-14-20
Puc
904.05 Installation and
Interconnection of Facility.
(a) Upon receipt of an application signed by the
distribution utility, the customer-generator may install the generating
facility.
(b) Following installation of the facility, the
customer-generator shall arrange for inspection of the completed installation
by the local building inspector or, if one is not available, a New Hampshire
licensed electrician.
(c) The person who inspects the installation
pursuant to (b) above shall sign a certificate of completion.
(d) If the facility was installed by an
electrical contractor, the customer-generator shall also have the contractor
complete a certificate of completion.
(e) When the customer-generator has obtained the certifications
required pursuant to (c) and (d) above, the customer-generator shall provide to
the distribution utility a copy of the certificate(s) of completion.
(f) Following receipt of the certificate(s) of
completion, the distribution utility may inspect the customer-generator’s
facility for compliance with interconnection standards by arranging for a witness
test.
(g) Until a witness test has been performed, the
customer-generator shall not operate in parallel with the electric distribution
system, unless a witness test has been previously waived by the distribution
utility on the application form.
(h) If the distribution utility elects to conduct
a witness test, the distribution utility shall attempt to conduct it within 10
business days of the receipt of the certificate(s) of completion.
(i) All projects
larger than 10 kilowatts shall be subject to a witness test, unless the
distribution utility has waived the witness test on the application form.
(j) If the witness test shows that the facility has
been correctly installed and is functioning without jeopardizing the safety,
reliability, or power quality of the distribution system, the distribution
utility shall notify the customer-generator in writing that the interconnection
is authorized.
(k) If the witness test results indicate that the
facility installation jeopardizes the safety, reliability, or power quality of
the distribution system, the distribution utility shall disconnect the facility,
provided that the distribution utility informs the customer-generator in
writing of the specific actions are required to address the safety, reliability,
or power quality issues as necessary to permit approval of the facility
interconnection.
(l) If the customer-generator does not
substantially complete construction of the facility within 12 months after receiving
application approval from the distribution utility, the distribution utility
shall require the customer-generator to reapply for interconnection.
(m) With respect to any facility with a capacity
size up to 25 kilowatts that does not interface with the electric distribution system
by means of an inverter, the distribution utility shall have a period of 75
days from the initial filing of the interconnection application to:
(1) Assess the proposed facility
and the customer-generator’s site characteristics;
(2) Communicate with the
customer-generator regarding adequate protective interface devices; and
(3) Allow the applicant to
interconnect or provide to the customer-generator specific written reasons for
objecting to interconnection of the facility.
(n) If the customer-generator and the distribution
utility agree that the application reasonably requires more time before the
distribution utility responds as provided in (m) above, as applicable, they may
agree to extend the deadline for response.
(o) Except as provided in (n) above, if the
distribution utility is not able to respond to the applicant within the 10-day
review period for inverter-based systems or the 75-day review period for
non-inverter-based facilities, and the customer-generator does not agree to an
extension of the response time, the distribution utility shall:
(1) Notify the commission
and the customer-generator in writing no later than the expiration of the
relevant period;
(2) Petition the commission
for an extension of a specified time period; and
(3) Cite the specific
reasons why the deadline was not met and the basis for the length of the
requested extension.
(p) The commission
shall grant an extension for review of the application for the shortest time
reasonable, if any, if it determines that it is necessary to provide the distribution
utility additional time to assess the effect of the proposal on safety,
reliability, or power quality of the electric distribution system in light of:
(1) The complexity of the
characteristics of the site;
(2) The complexity of the
proposed generation and interconnection facilities; or
(3) Delay occasioned by:
a. Failure of the customer-generator to timely
provide to the distribution utility information necessary to assess the
potential impact of the system on safety, reliability or power quality of the
electric distribution system;
b. Untimely response by the customer-generator
to the distribution utility in response to a distribution utility request for
information; or
c. Circumstances beyond the control of the
distribution utility that prevent the utility from responding within the time
limits established by this section.
(q) The distribution utility shall notify the customer-generator
as soon as reasonably possible, but not later than 30 days following the filing
of an application for interconnection of a facility, of any required
information not included in the customer-generator’s interconnection
application that the customer-generator has indicated is complete.
(r) If the distribution utility has not met the
applicable deadline for responding to a completed application pursuant to (m)
above and has not petitioned for an extension pursuant to (o) and (p) above,
the customer-generator may:
(1) Contact the distribution
utility and the commission and request resolution; or
(2) File a complaint with
the commission.
(s) Prior to operation,
during normal business hours, the customer-generator shall:
(1) Provide the
distribution utility the opportunity to inspect the facility; and
(2) Upon request,
demonstrate to the distribution utility the operation of the facility.
(t) The distribution utility shall interconnect
with any customer-generator which:
(1) Receives electric
service from the distribution utility;
(2) Has completed the
application process required by this section; and
(3) Has installed a net
energy metering facility that complies with the interconnection and technical
specification requirements of Puc 900.
(u) Facilities that meet the interconnection
requirements of Puc 900 shall not be required by the
distribution utility to meet additional requirements, perform
or pay for additional tests, or pay additional interconnection-related charges,
except as otherwise provided.
(v) Nothing in (u) above shall prohibit a party
from requesting that the commission grant a rule waiver, pursuant to Puc 201.05, with respect to any net-metered facility, to
require additional interconnection requirements, performance of or payment for
additional tests, or payment of additional interconnection-related charges.
(w) A customer-generator, distribution company, or
electricity supplier may install additional controls or meters or conduct
additional tests, in addition to those required by Puc
900, but if entry to the customer-generator’s premises is necessary, it shall
first obtain consent to access the premises pursuant to Puc
908.03.
(x) The expenses associated with any additional
tests, meters, or equipment described in (w) above, shall be borne by the party
requiring the additional tests, meters, or equipment.
(y) For facilities larger than 25 kilowatts, the
distribution utility shall require a site-specific interconnection review that
may require additional protective equipment and may exceed the 75-day time frame
by up to an additional 60 days.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
Puc 904.06 Upgrades or
Changes in the Net Metering Facility.
(a) The customer-generator shall provide to the
distribution utility a written update regarding any of the information required
to be provided in the interconnection application as any such changes occur.
(b) The customer-generator shall re-certify to
the distribution utility the applicable certifications required by Puc 904.05(c) and (d), if any of the following occurs:
(1) The generation capacity
of the facility is increased or its source is changed;
(2) Any key component of
the facility, such as the inverter, is replaced or upgraded; or
(3) The relays for a
non-inverter facility are replaced, rewired, or upgraded.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09 (from Puc 904.05); ss by #9998, eff 9-20-11; ss by #13080, eff 9-14-20
Puc 904.07 Insurance. The customer-generator shall not be required
by the distribution utility or any electricity supplier to purchase or maintain
property insurance or comprehensive personal liability insurance to protect
against potential liability resulting from the installation, operation, or
ownership of the generation and interconnection facility.
Source. #9515, eff 7-18-09 (from Puc
904.06); ss by #9998, eff 9-20-11; ss by #13080, eff 9-14-20
PART Puc 905 TECHNICAL
REQUIREMENTS FOR INTERCONNECTION OF FACILITIES
Puc
905.01 Requirements for Disconnect
Switches.
(a) No facility which connects to the electric distribution
system by means of a single-phase or 3-phase inverter that complies with Puc 906.01 shall be required to install and maintain a
manual disconnect switch for utility use, unless:
(1) The
customer-generator’s revenue meter is not routinely accessible to the utility;
(2) The facility uses
multiple inverters connected in series; or
(3) The utility connection
is through a transformer rated meter.
(b) For purposes of this section, a “transformer
rated meter” means a meter panel or switchboard employing the use of potential
and current transformers.
(c) If the
distribution utility finds it necessary for scheduled maintenance of which the
customer-generator has received reasonable notice, or in an
emergency situation, to disconnect from the electric distribution system
a customer-generator that does not maintain a manual disconnect switch for
utility use, the utility may do so by:
(1) Pulling
the customer-generator’s meter;
(2) Disconnecting the
customer-generator’s service at the site transformer; or
(3) Executing any other
reasonable method of disconnection.
(d) If the customer-generator has been notified of
a scheduled maintenance or other event requiring disruption of service, as an
alternative to having service disconnected, and upon agreement of the
distribution utility, the customer-generator or its representative may be present
at the scheduled time of disruption of service and demonstrate to the utility
representative that generation has been isolated from the utility distribution
system and remains isolated for the duration of the required period.
(e) If the customer-generator schedules a meeting
with the distribution utility for disconnection of the facility, as described
in (d) above, and the customer-generator does not meet at the scheduled time,
the distribution utility may disconnect the service as provided in (c) above.
(f) If the customer-generator does not install a
manual disconnect device accessible to the utility, the customer-generator:
(1) Shall assume all risks
and consequences associated with the loss of power to the customer-generator’s
premises during any period when the distribution utility is required to
disconnect the customer-generator’s electric service; and
(2) Acknowledges that the
service disconnection shall interrupt all electric service to the
customer-generator’s facility site.
(g) Any customer-generator may agree to install a
manual disconnect device accessible to the distribution utility.
(h) If the customer-generator elects not to
install a disconnect switch for use by the distribution utility, the
customer-generator shall install a warning label, to be provided by the
distribution utility, on or near the service meter location.
Source. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
Puc 905.02 Disconnect
Switch.
(a) For purposes of this section, a
“gang-operated” switch means a switch in which the separate switches for each
phase are operated as a group from a single control.
(b) A facility that elects to install a manual
disconnect switch for utility use shall meet the following requirements:
(1) The disconnect switch
shall be an external, manual, visible, gang-operated, load break disconnecting switch;
(2) The customer-generator
shall purchase, install, own, and maintain the disconnect switch;
(3) The disconnect switch
shall be located between the power-producing equipment and the interconnection
point with the distribution utility system;
(4) The disconnect switch
shall meet applicable standards established by Underwriters Laboratories,
American National Standards Institute, the National Electrical Code, and the
Institute of Electrical and Electronic Engineers;
(5) The disconnect switch
shall be clearly marked, “Generator Disconnect Switch”, with permanent letters
3/8 inch or larger;
(6) The disconnect switch
shall be located on the facility site at a location that is mutually agreeable
to the customer-generator and the distribution utility;
(7) The disconnect switch
shall be readily accessible for operation and locking by distribution utility
personnel; and
(8) The disconnect switch shall
be lockable in the open position with a standard padlock with a 3/8 inch shank.
Source. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09; ss by #9998, eff 9-20-11;
ss by #13080, eff 9-14-20
Puc 905.03 Configuration of
the Transformer Serving the Customer-Generator’s Facility Site.
(a) The existing site transformer serving the customer-generator
load may be used if its use will not significantly degrade the power quality or
voltage regulation on the secondary distribution system and if such usage will
not create problems for distribution utility system relaying.
(b) For single-phase distributed generation
facilities connected to 4-wire multi-grounded neutral systems, the high side of
the step-up transformer shall be connected phase-to-neutral.
(c) A phase-to-phase high side connection shall
be allowed if it does not degrade power quality or voltage regulation on the
distribution system.
(d) For single-phase distributed generation
facilities connected to 3-wire or 4-wire impedance grounded systems, the
step-up transformer high-side winding shall be connected phase-to-phase.
(e) For 3-phase distributed generation facilities
connected to 4-wire multi-grounded distribution systems, the step-up
transformer may be an existing grounded-wye to grounded-wye transformer. The
term “wye,” as used in this paragraph, means the configuration in which one end
of each transformer winding is connected to a common point and the other to its
appropriate line terminal, resembling the letter "Y."
(f) In cases as described in (e) above, the
generator shall be impedance grounded as necessary to achieve effective
grounding but limit the desensitization of the distribution utility system
ground fault relaying.
(g) The net-metered facility site shall be
impedance grounded, as described in (f) above, if necessary, in a manner
adequate to assure that the facility does not:
(1) Significantly degrade
the power quality or voltage regulation on the distribution system;
(2) Create
significant safety problems; or
(3) Create problems for
distribution utility system relaying.
(h) To guard against over-voltages on the unfaulted phases of a 3-phase utility primary, if the
transformer serving the customer-generator site is ungrounded, over-voltage
protection shall be used to:
(1) Detect a situation in
which the utility has tripped due to a phase-to-ground fault, and the connected
ungrounded generator might not yet have tripped; and
(2) Trip the generator at
high speed.
(i) The cost of any improvements necessary to the
site transformer serving the net-metered facility shall be borne according to
the distribution utility’s approved tariff on file with the commission.
Source. INTERIM #5921, eff 11-7-94, EXPIRED 3-7-95
New. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09; ss by #9998, eff 9-20-11;
ss by #13080, eff 9-14-20
Puc 905.04 Initial
Testing.
(a) After installation of the net-metered
facility, and before final approval and interconnection to the electric distribution
system, the customer-generator shall, in addition to the certification(s) required
in connection with the interconnection application, conduct a load-break test
on the facility, as described in (b) below, to confirm that the anti-islanding
controls are functioning.
(b) When conducting a load-break test, the
customer-generator shall demonstrate that, after the main disconnect switch or
circuit breaker of the residence or building is opened, the net-metered
facility shuts down within 2 seconds.
(c) If the generation unit fails to shut down
within 2 seconds after conducting the test, as provided in (b) above, the
customer-generator shall inform the distribution utility.
(d) The customer-generator shall provide an
initial test on a non-inverter interfaced facility, by demonstrating that:
(1) The relays function as designed;
(2) The relays have been
calibrated to settings as provided by the distribution utility pursuant to Puc 907.01(f);
(3) All key components of
the facility function as designed; and
(4) The anti-islanding function
of the facility works properly.
(e) The testing of
the relays of a non-inverter interfaced facility shall be conducted by an
individual who:
(1) Uses
test equipment:
a. Necessary to adequately test the key
components of the facility;
b. That is calibrated within tolerances sufficient
to assure accurate testing; and
c. That is calibrated with a frequency
consistent with industry standards;
(2) Has received the
education and training necessary to conduct the sophisticated testing of relays
and other components of a non-inverter based facility;
and
(3) Maintains any professional accreditation or
certification required to conduct such testing.
(f) The individual conducting the testing of a
non-inverter-based facility required by this section shall, upon request,
provide to the distribution utility information regarding his or her background
and credentials, and equipment, maintenance, and calibration of the equipment
sufficient to allow the utility to assess the individual’s competence to undertake
the required testing.
(g) Upon request, the customer-generator shall
allow the distribution utility to have a representative present for the initial
or periodic testing required by this part.
Source. #7424, eff 1-12-01; ss by, INTERIM, eff 1-12-09,
EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
Puc 905.05 Periodic Testing.
(a) With respect to a net-metered facility which
interfaces with the electric distribution system by an inverter, the
customer-generator shall, if requested to do so by the distribution utility,
conduct a load-break test, as described in Puc
905.04(b), once per year after installation.
(b) With respect
to a net-metered facility that does not interface with the electric distribution
system by an inverter, the customer-generator shall:
(1) Conduct a load-break
test, as described in Puc 905.04, once per year after
installation; and
(2) Verify the proper
calibration and protective function of the components and systems of the facility,
which shall include the testing prescribed by each facility component
manufacturer:
a. Once every 4 years or according to the
schedule recommended by the manufacturer, whichever is more frequent, for
facilities rated greater than 25 kilowatts; or
b. Once every 4 years for facilities rated 25 kilowatts
or less.
(c) The testing of the calibration and protective
function of the components and systems of a non-inverter interfaced system
shall be conducted by an individual qualified as provided in Puc 905.04(e) and (f).
(d) The customer-generator shall:
(1) Create a written record
of the dates and procedures for tests conducted pursuant to this section; and
(2) Maintain the written
record of verification testing for inspection by the distribution utility for a
period of 4 years from the date of each respective test.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
Puc 905.06 Studies
and Analysis.
(a) A distribution
utility may conduct detailed load flow, voltage regulation, or short circuit
coordination studies of the primary feeder if it determines that the addition
of a net-metered facility will push the aggregate capacity of distributed
generation on the feeder to the threshold level described in (b) and (c) below.
(b) The distribution utility may determine that
the threshold of concern for aggregate distributed generation has been reached
if:
(1) The lower of 7.5 percent
of the peak feeder demand as measured at the substation or 20 percent of the
peak feeder demand downstream of the point of interconnection is reached;
(2) More than one net-metered
facility is proposed to be installed on the same secondary shared by many customers; or
(3) Any other reasonable means,
consistent with (1) or (2) above, of determining that a study is necessary.
(c) The distribution utility shall determine that
the threshold of concern for aggregate distributed generation has been reached,
if it determines that the addition of the proposed net-metered facility poses a
reasonable threat to the continued safety, reliability, or power quality to any
significant portion of the electric distribution system.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
Puc 905.07 Payment for
Upgrades or Improvements to the Electric Distribution System. If an upgrade or an improvement to the
electric distribution system up to the customer-generator’s meter is necessary
for the distribution utility to interconnect to the customer-generator’s net-metered
facility, the expense shall be borne according to the utility’s approved tariff
on file with the commission.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
PART Puc 906 COMPLIANCE PROCESS FOR INVERTER-BASED
FACILITIES
Puc
906.01 Inverter Requirements.
(a) A net-metered facility that interconnects to
the electric distribution system by means of a single-phase or 3-phase inverter
shall be deemed to be compliant with the technical specifications for the facility
itself, as established by Puc 900, if the facility
complies with the minimum requirements set forth in the following national
standards:
(1) The “IEEE Standard 1547
(2018) for Interconnecting Distributed Power Resources with Electric Power
Systems” issued by the Institute of Electrical and Electronic Engineers, Inc., 445
Hoes Lane, Piscataway, New Jersey, available as specified in Appendix B; or
(2) The “UL 1741 SA,
Standard for Inverters, Converters, Controllers with Interconnection System
Equipment for Use with Distributed Energy Resources,” 2010, issued by
Underwriters Laboratories, Inc., 333 Pfingsten Road,
Northbrook, Illinois 60062, available
as specified in Appendix B.
(b) Each net-metered facility
shall be installed in accordance with the State Building Code, including the
National Electrical Code, pursuant to RSA 155-A:1, IV, as may be modified from
time to time by the state building code review board pursuant to RSA 155-A:10,
V.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
PART Puc 907 COMPLIANCE PROCESS FOR NET-METERED FACILITIES
NOT USING AN INVERTER
Puc 907.01 Interconnection Requirements.
(a) Except as provided in (b) below, any net-metered
facility that interfaces with the electric distribution system by means other
than an inverter shall:
(1) Meet the following
safety and service quality requirements:
a. The facility shall not compromise the safety
of the distribution utility personnel, the customer-generator, or other
customers on the electric distribution system;
b. The facility
shall have:
1. Adequate non-islanding protection;
2. Utility-grade protective devices to separate
the facility from the electric distribution system, including:
(i)
Time over-frequency protection;
(ii) Time under-frequency protection;
(iii) Time over-voltage
protection; and
(iv) Time
under-voltage protection;
3. Protection devices at the primary voltage
level for ground fault and ground current contribution;
4. Adequate short circuit interrupting devices;
and
5. Reliable power sources for shunt-tripped
short circuit interrupting devices;
c. The generation
facility shall not reduce the quality of service on the electric distribution
system, including voltage fluctuations, excessive voltage, and current harmonic
content; and
d. Facilities greater than 35 kilowatts shall
certify that they comply with the standard for harmonics set forth in “IEEE
Standard 1547 (2018) for Interconnecting Distributed Power Resources with
Electric Power Systems” issued by the Institute of Electrical and Electronic
Engineers, Inc., 445 Hoes Lane, Piscataway, New Jersey, available as specified in Appendix B;
(2) Interface with the
electric distribution system in compliance with the following requirements:
a. The system shall synchronize with the primary
voltage level on the distribution system;
b. The transformer winding connection to be used
at the primary voltage interconnecting point shall be adequate to coordinate
with the distribution system;
c. The generation facility shall synchronize
with the electric distribution system; and
d. The generation facility shall correct the
power factor, if necessary;
(3) Not impair the quality of service standards maintained by the electric
distribution system;
(4) Provide other
protections and devices necessary, consistent with the requirements of this section,
to assure safety, quality of service, reliability, and power quality of the
electric distribution system; and
(5) Use utility grade
relays as required.
(b) A non-inverter-based system shall be installed
in accordance with the National Electrical Code, 2017, issued by the National
Fire Protection Association, Quincy, Massachusetts, available as specified in
Appendix B.
(c) An applicant proposing to interconnect a
net-metered facility to the electric distribution system shall provide to the
distribution utility the following:
(1) The
interconnection application form required by Puc 904.02;
(2) Alternating current
(AC) and direct current (DC) elementary and schematic diagrams describing the
planned protection package; and
(3) A one-line diagram of
the net-metered facility showing how the system protection shall be wired.
(d) The customer-generator shall provide for
testing of the relays of the net-metered facility once the settings have been
applied to confirm that the settings perform the intended function.
(e) With respect to the testing of relays
described in (d) above:
(1) The testing shall be
conducted by an individual qualified to conduct testing as provided in Puc 905.04(e) and (f); and
(2) The customer-generator
shall provide to the distribution utility the opportunity to:
a. Be present at and observe the testing; or
b. Conduct the testing of the relays by a
qualified utility representative.
(f) If the customer-generator and the distribution
utility cannot agree to the interconnection requirements, they shall file with
the commission a detailed statement of their disagreement for review and
determination by the commission.
(g) In determining
interconnection requirements for a non-inverter-based facility, the commission
shall consider safety, reliability, and power quality, in the context of the
legislative intent of RSA 362-A:9.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
PART Puc 908 PROCEDURAL
REQUIREMENTS FOR INTERCONNECTED FACILITIES
Puc
908.01 Emergencies and Maintenance.
(a) The customer-generator shall, during the
period it operates as a customer-generator, provide to the distribution utility
a current telephone number(s) at which the customer-generator shall be
contacted.
(b) The distribution utility shall make arrangements for routine utility repairs or inspections
that might involve the net-metered facility during normal business hours.
(c) The customer-generator shall not export
electricity to the electric distribution system during any outages of the
distribution system that serves the customer-generator.
(d) The customer-generator’s net-metered facility
may be operated during outages referred to in (c) above only with an open tie
to the distribution utility.
(e) The customer-generator’s net-metered facility
shall not:
(1) Create an islanding
situation on the electric distribution system; or
(2) Energize a de-energized
utility circuit for any reason.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09; ss by #9998, eff 9-20-11;
ss by #13080, eff 9-14-20
Puc 908.02 Procedures for
Disconnection.
(a) When an emergency condition, as described in
(b) below, exists and when it is necessary under the circumstances to do so,
the distribution utility may disconnect the customer-generator’s net-metered facility
and electric service.
(b) An emergency condition shall have occurred
when the interconnection represents a condition which:
(1) Is likely to result in
imminent significant disruption of service to the distribution utility’s customers;
(2) Is imminently likely to
endanger life or property;
(3) Constitutes emergency
or pre-emergency conditions on the utility system;
(4) Constitutes
a hazardous condition; or
(5) Reveals that a protective
device tampering has occurred on the customer-generator’s facility.
(c) The distribution utility may open the
disconnect switch or disconnect the customer-generator’s service, as applicable,
after notice to the customer-generator has been delivered and a reasonable time
to correct the condition, consistent with the conditions, has elapsed, if:
(1) The customer-generator
has failed to make available records of required verification tests, and, in
the case of a non-inverter-interfaced facility, maintenance of its protective devices;
(2) The customer-generator’s
net-metered facility impedes:
a. The normal use of distribution utility
equipment or equipment belonging to other distribution utility customers in a negative
manner; or
b. The normal quality of service of other
customers in a negative manner; or
(3) The
customer-generator’s net-metered facility has been modified so that it is not
in compliance with Puc 900.
(d) When the customer-generator has corrected the
problem and restored the net-metered facility to compliance with Puc 900 and notifies the distribution utility of such
compliance, the utility shall:
(1) Within 2 business days
provide:
a. Written verification to the
customer-generator of such compliance; or
b. Written notice to the customer-generator of
the specifics of any continued noncompliance; and
(2) When the system is in compliance, reconnect, or allow re-connection, as soon
as possible under the circumstances.
(e) The customer-generator may reconnect the
net-metered facility to the electric distribution system in coordination with
the distribution utility, upon receipt of verification as provided in (d) above,
if the customer-generator, upon the utility’s request or otherwise,
disconnected itself from the distribution system.
(f) If the distribution utility disconnects the
customer-generator’s net-metered facility as a result of
one of the emergency conditions described in (b) above, it shall notify the
customer-generator of the disconnection:
(1) Within
24 hours of the disconnection; or
(2) As soon as possible in
circumstances where a widespread emergency or other significant extenuating
circumstances preclude utility personnel contacting the customer-generator
within the 24-hour period.
(g) If the emergency referred to in (a) above was
not caused by the net-metered facility, then the distribution utility shall
reconnect the facility upon cessation of the emergency.
(h) Notwithstanding any special notification and
reconnection requirements for customer-generators established by this part, the
distribution utility shall not be required to provide for special notification
or reconnection for a customer-generator that differs from its usual and
regular policies and protocols in a disconnection situation, if:
(1) The disconnection is
not for reasons associated with the net-metered facility; and
(2) The distribution
utility does not open the customer-generator’s disconnect switch or pull the customer-generator’s
meter.
(i) If the emergency
referred to in (a) above was caused by the net-metered facility, then the
distribution utility shall communicate the nature of the problem to the
customer-generator within 5 days, and attempt to resolve the issue with the
customer-generator.
(j) Within 30 days of the disconnection referred
to in (h) above, the distribution utility shall file a disconnection petition
with the commission if the distribution utility and the customer-generator have
not reached a mutually agreed-upon resolution.
(k) Non-emergency disconnections of the net-metered
facility by a distribution utility shall follow the same process as emergency
disconnections of such systems, except that the utility shall:
(1) Provide the customer-generator
no less than 5 business days’ prior notice of the disconnection; and
(2) Describe in detail in
the notice to the customer-generator the reasons for the disconnection.
(l) If the net-metered
facility is not the reason for the disconnection, the distribution utility
shall reconnect the system as soon as the activity, such as line maintenance,
necessitating the disconnection, ceases.
(m) When a utility disconnects a
customer-generator’s net-metered facility, the customer-generator may file a
complaint with the commission at any time after disconnection.
(n) If a
disconnection complaint is filed with the commission, the commission shall hold
a hearing on the matter within 30 days and rule on whether the net-metered
facility has violated a condition necessary for it to operate.
(o) In any hearing referred to in (n) above, the
disconnecting utility shall have the burden of proof.
(p) A customer-generator shall not re-close a
disconnect device which has been opened and tagged by its distribution utility, or attempt to re-install a pulled meter without the
prior permission of the distribution utility, or in the event of a dispute, the
commission.
(q) A customer-generator shall be allowed to
disconnect the net-metered facility from the distribution utility without prior
notice in order to self-generate, but shall notify the
distribution utility as soon as practical following disconnection.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09; ss by #9998, eff 9-20-11;
ss by #13080, eff 9-14-20
Puc 908.03 Distribution
Utility Access to Net-Metered Facility.
(a) The distribution utility may inspect the net-metered
facility at its own expense at a time mutually agreeable to the
customer-generator upon reasonable notice to the customer-generator.
(b) Except in emergency circumstances, the
distribution utility shall provide not less than 5 business days’ prior notice
to the customer-generator to enter the facility site in order
to inspect the net-metered facility, install additional controls or
meters, or conduct additional tests.
(c) A customer-generator shall not deny access to
the distribution utility to inspect the net metered system, install additional
controls or meters or conduct additional tests.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
Puc
908.04 Complaints and Investigations.
(a) The procedures set forth in Puc 204 shall be applicable to filing and resolution of any
complaint and investigation arising out of Puc 900.
(b) A customer-generator, distribution utility,
or any other interested person may file with the commission a complaint or
request for resolution of a dispute relating to Puc
900.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09; ss by #9998, eff 9-20-11;
ss by #13080, eff 9-14-20
Puc 908.05 Notifying Public
of Net Energy Metering.
(a) When a customer initiates an inquiry and
requests information regarding net energy metering, the distribution utility
shall provide to the customer a copy of Puc 900 and
the name and telephone number of a contact person(s) at the utility and a
description of net energy metering.
(b) The distribution utility shall provide to
each customer in a billing insert or a billing message in the customer bill a
brief description of the availability of net energy metering, which billing
insert or message shall be of one paragraph or more in length.
(c) The distribution utility shall provide the
information described in (b) above on an annual basis.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09; ss by #9998, eff 9-20-11;
ss by #13080, eff 9-14-20
Puc 908.06 Violations of
Authorization to Interconnect.
(a) After notice and an opportunity for a
hearing, the commission shall revoke, suspend, or condition the authorization
for a customer-generator to interconnect a net-metered facility, or take such
other action consistent with the above that it deems warranted if it finds good
cause therefor.
(b) “Good cause,” as such phrase is used in (a)
above, shall exist if the commission finds one or more of the following:
(1) The customer-generator
was granted authority to operate based on false or misleading information supplied
by the applicant which:
a. Is material; and
b. The applicant knew or should have known was
false or misleading;
(2) The facility was not
installed or is not being operated in accordance with the National Electrical
Code and applicable utility interconnection requirements;
(3) The customer-generator
has failed to comply with the conditions of approval to operate or
representations made in the filing for approval to operate; or
(4) Other conditions,
consistent with (1) through (3) above, exist which the commission finds
necessitate revocation or suspension, or placing conditions on, the
authorization to interconnect.
(c) In determining the actions to be taken based
on its finding in (a) above, the commission shall consider the following:
(1) The severity of the
consequences resulting from the violation, such that the more severe the consequences,
the more severe the action to be taken;
(2) Mitigating
circumstances, such as how quickly the customer-generator took action to
rectify the situation, how much control the customer-generator had over the
situation, and other circumstances that would tend to lessen the fault of the
customer-generator; and
(3) Any
prior violations of Puc 900.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
Puc
908.07 Utilities Shall Report Number
and Size of Net-Metered Facilities.
(a) Each
distribution utility shall:
(1) Track the number and
size of net-metered facilities interconnected to their distribution systems;
(2) Report to the
commission annually by April 1 of each year for the prior year, the following information
regarding net-metered facilities:
a. The number of facilities
operating;
b. The generation output rating of the facilities
in kilowatts; and
c. Information regarding any net-metered
combined heat and power facilities.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09; ss by #9998, eff 9-20-11;
ss by #13080, eff 9-14-20
Puc 908.08 Existing
Facilities Grandfathered.
(a) Net-metered facilities
that have been interconnected with the distribution utility, with the knowledge
of the distribution utility, as of June 13, 1982
shall:
1. Be
deemed to be registered; and
2. Not be required, due to
the adoption of Puc 900, to:
a. Re-apply for interconnection pursuant to Puc 904; or
b. Upgrade to
meet the applicable requirements for interconnection of Puc
905, the requirements for inverter units of Puc 906,
or the requirements for non-inverters of Puc 907.
(b) The grandfathered facilities referred to in
(a) above shall comply with the procedural requirements for interconnected facilities
contained in Puc 908.
(c) A customer-generator may repair a net-metered facility
that is grandfathered under (a) above, such as by repairing relays in a
non-inverter system, but if the customer-generator changes the inverter or adds
to the generation capacity or otherwise upgrades or alters the facility as
provided in Puc 904.05, the customer-generator shall
update the qualifications of the facility as provided in Puc
904.05.
(d) The distribution utility or electricity
supplier may request, and the customer-generator shall provide, with respect to
any facility grandfathered under this section, the information required in
connection with the interconnection application form set forth in Puc 904.02, and the customer-generator shall, without
request, update any such information as it may change.
(e) A net-metered facility that has been
interconnected with its distribution utility prior to the initial adoption of Puc 900, without the knowledge of the distribution utility,
shall not be grandfathered for purposes of this section.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09; ss by #13080, eff 9-14-20
New.
#9515, eff 7-18-09; ss by #9998, eff
9-20-11; ss by #13080, eff 9-14-20
Puc 908.09 Relationship to
Other Commission Rules. Unless
otherwise specified, Puc 900 shall not supersede any
other rule of the commission, but instead shall supplement such rules.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New.
#9515, eff 7-18-09 (from Puc 908.10); ss by #9998, eff 9-20-11 (from Puc 908.10) ; ss by #13080, eff 9-14-20
Puc 908.10 Transferability.
(a) A customer-generator’s certificate to operate
a net-metered facility shall transfer to the new owner when the property with
the net-metered facility is sold or otherwise conveyed, if the new owner
provides to the distribution utility in writing:
(1) Any information that is
new or different from that provided in connection with the interconnection
application as described in Puc 904.02; and
(2) An agreement to operate
and maintain the net-metered facility according to Puc
900, RSA 362-A, and other applicable requirements.
(b) The distribution utility shall not deny a new
owner acquiring a currently-registered net-metered
facility, which otherwise complies with the requirements of Puc
900, the right to register, provided that the new owner complies with (a)
above.
(c) The new customer-generator owner, as
described in (a) and (b) above, shall notify the distribution utility of the
transfer and of the applicable information required by the interconnection
application as described in Puc 904.02.
(d) A net-metered facility transferred as
described in this section shall not be deemed to have exited from the system,
and neither Puc 903.02(q) nor Puc
903.02(r) shall apply to any such transfer.
(e) If any change or upgrade in a net-metered
facility would otherwise require new approval pursuant to Puc
904.05, a mere transfer of ownership shall not relieve the customer-generator
from that requirement.
Source. #7424, eff 1-12-01; ss by #9353, INTERIM, eff
1-12-09, EXPIRED: 7-11-09
New. #9515, eff 7-18-09 (formerly Puc 908.11); ss by #9998, eff 9-20-11 (from Puc 908.11); ss by #13080, eff 9-14-20
PART Puc 909 GROUP NET
METERING
Puc 909.01 Purpose. The purpose of this part is to implement the
group net metering provisions of RSA 362-A:9, XIV and commission’s expanded reporting
requirement pursuant to RSA 362-F:10, IV.
Source. #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15; ss by #13080, eff 9-14-20
Puc
909.02 Applicability.
(a) Puc 909.01 through Puc 909.15 shall apply to customer-generators who elect to
become hosts, to group members, and to distribution utilities that serve hosts
and group members.
(b) Large customer-generators subject to the alternative
net metering tariff that do not consume behind-the-meter at least 20 percent of
the actual or estimated annual electricity production from their facilities
shall register as group hosts pursuant to this part or they shall be ineligible
to net meter.
(c) Puc 909.12 applies
to customer-generators who or which register or re-register as a host on or
after July 1, 2019 and elect to receive on-bill
credits.
(d) Puc 909.13 applies
to customer-generators who or which meet the requirements specified therein to
register as a low-moderate income community solar project.
Source. #13080, eff 9-14-20
Puc
909.03 Registration and Re-Registration
of Hosts.
(a) To register as a host, a customer-generator
shall provide the commission with the information specified in Puc 909.09, and shall send a copy
to the host’s distribution utility.
(b) No customer-generator shall begin acting as a
host until it has received a registration number from the commission.
(c) Unless the commission denies a host registration
application for being incomplete or ineligible within 60 days of its filing,
the commission shall issue the host a registration number, with a copy provided
to the distribution utility.
(d) Re-registration shall not be required so long
as a registered host complies with the annual report requirements of Puc 909.07 and Puc 909.10.
(e) If a host must
re-register, the host shall follow the requirements of (a) above.
(f) If a
customer-generator requests that the commission issue a provisional host
approval, the customer-generator shall provide the commission with the
information specified in Puc 909.09 that demonstrates
compliance with those requirements at a specific date in the future. Unless the commission denies a request for
provisional approval for being incomplete or ineligible within 60 days of its filing, the commission shall issue a
provisional approval, with a copy provided to the distribution utility. A provisional approval shall expire 12 months
from the date of its issuance. A provisional
approval does not supersede the requirement to obtain a host registration
number under (b) above. Prior to
receiving a host registration number, a customer-generator that received
provisional approval shall provide to the commission updated information that
demonstrates current compliance with Puc 909.09. The commission shall act upon the updated
information as provided in (c) above.
(g) A host may voluntarily surrender its host
registration at any time by so notifying the commission and the distribution
utility.
(h) Upon request, a host shall provide to the
commission copies of agreements with its members and any other document related
to its host status, operation of its facility, and relationship with its
members.
Source. #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15; ss by #13080, eff 9-14-20
Puc 909.04 Transfer of
Registration Numbers.
(a) A group host registration number may be
transferred by the host or by operation of law to another, provided that the
following conditions have been met:
(1) The proposed host meets
the definition of Puc 902.18; and
(2) The proposed host shall
serve as host of the same facility under the terms of the agreement governing
the existing host and group members.
(b) Within 30 days of the transfer of the
registration number, the new host shall provide the commission the following
information, with a copy provided to the host’s distribution utility:
(1) The former host’s name
and registration number;
(2) The new host’s name,
mailing address, trade name, if any, telephone number, email address, and
website address, if any;
(3) The physical address,
service address, account number(s), and meter number(s) of the facility that
the new host serves;
(4) The name, telephone
number, and email address of the individual responsible for responding to
commission inquiries after transfer of the registration number;
(5) The
identity of the owner and operator of the facility after transfer of the
registration number;
(6) A
description of changes to the members in the group, if any, including changes
in names, billing addresses, service addresses, account numbers, meter numbers,
and projected annual load;
(7) A certification that
all members and the new host are customers of the same distribution utility;
(8) A certification that
the new host has provided to the distribution utility a copy of the notice
required by this paragraph;
(9) A certification that
the information provided is true, accurate, and complete; and
(10) Except as allowed by Puc 902.16 and Puc 902.22, a
certification that none of the members is a customer-generator.
Source. #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15; ss by #13080, eff 9-14-20
Puc 909.05 Agreement.
(a) The host and its members shall sign an
agreement, as defined in Puc 902.02, which includes
at least the following:
(1) The contact information
for the host and each member, including their names, billing addresses, service
addresses, account numbers, meter numbers, phone numbers, email addresses, and
name of distribution utility;
(2) The procedure by which
the host will allocate and make payments to, and allocate and collect payments
from, its members, including the frequency and manner of such payments and
collection, or, for groups electing on-bill crediting, the procedure by which
on-bill credit percentage allocations will be determined, subject to the
restrictions specified in Puc 909.12 and Puc 909.13;
(3) The procedure by which
members may join and leave the group, which procedure shall, at a minimum,
comply with and contain the language required by Puc 909.06;
(4) A binding process for
the resolution of any disputes arising under the agreement involving the host,
its members, or among members, including disputes arising out of the member
removal process required by Puc 909.06, which dispute
resolution process does not rely on the distribution utility or the commission;
and
(5) For groups electing on-bill
crediting, each member shall grant limited permission for the host to obtain member
load and account information from the distribution utility for the purposes of
complying with Puc 909.06 and Puc
909.10.
(b) The host and each member shall sign an
agreement attesting that the information provided is true to the best of their
knowledge and belief.
(c) A member that is not participating in on-bill
crediting may sign an agreement with more than one host, but the portions of
that member’s load which are allocated to each host, when combined, shall not
exceed that member’s total load. A
member in a group participating in on-bill crediting shall not be a member of
more than one group at the same time.
(d) The requirements of this section to sign an
agreement shall not apply if the host and members are the same person or the
same entity.
(e) No agreement shall in any way prohibit or restrict
the members of a low-moderate income community solar project group who are
residential end-user customers with household income at or below 300 percent of
the federal poverty guidelines from leaving such groups, consistent with Puc 909.13(d)(8).
Source. #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15; ss by #13080, eff 9-14-20
Puc 909.06 Group Changes.
(a) The procedure by which members are added to
and removed from the group shall be defined in the agreement. The agreement shall describe how members may
be added, how members may leave voluntarily, and how members may be removed
involuntarily, subject to the limitation specified in Puc
909.05(e).
(b) For groups participating in group net
metering without on-bill crediting, changes in group membership shall be
implemented as follows:
(1) The addition of a
member shall be effective on the member’s first meter read date immediately following
the new member’s addition;
(2) The departure of a
member shall be effective on the member’s first meter read date immediately following
the member’s date of departure;
(3) Departing members shall
receive their allocated share of any payments due from the host, and shall be
responsible for their allocated share of any payments due to the host, through
the effective date of their departure, and the agreement shall describe how
payments are to be made between the host and members upon the departure of a
member; and
(4) The host shall notify
the commission of changes to the group membership, and the month in which each
such change occurs, on an annual basis, pursuant to Puc
909.07.
(c) For groups participating in group net metering
with on-bill crediting, changes shall be implemented as follows:
(1) A host may make changes
to group membership or credit percentage allocations up to 4 times each year,
and only once in each calendar quarter ending March 31, June 30, September 30,
and December 31, by submitting the information specified in (e) below;
(2) Group changes submitted
pursuant to (1) above, and approved by the commission when applicable under Puc 909.06(h) shall take effect for the next host and
member billing cycles beginning at least 10 business days following the date of
change notification submission or approval of changes by the commission, if required;
(3) Group changes for
low-moderate income community solar projects shall continue to meet the
requirements for such projects specified in Puc 909.06(e)(7)
and (8);
(4) In the event a member
has moved, the member’s credit percentage allocation for the applicable meter
shall continue to accrue until the implementation of (2) above following the
submission and approval of the information required in (e) below pursuant to
the applicable schedule specified in (1) above; and
(5) If the meter of a
member becomes inactive, the credit percentage allocation for the account
associated with that meter shall be redistributed the host until the implementation
of (2) above, following the submission and approval of the information required
in (e) below pursuant to the applicable schedule specified in (1) above.
(d) Unless the agreement provides otherwise, in
the event of a host’s or member’s death, the meter(s) associated with that
deceased host or member shall continue to be a part of the group until removed
according to the terms of the agreement or by order of a court of competent
jurisdiction. The legal representatives
of deceased hosts or members shall remain bound by the terms of the agreement, unless the agreement provides otherwise.
(e) The host shall notify the commission and the distribution
utility of any change to the group by providing the following information in
accordance with (b)(4) above or (c)(1) above, as applicable:
(1) The host’s name, trade
name, if any, address, service address, telephone number, email address,
website address, if any, name of distribution utility, meter number, and
account number;
(2) For a group adding or
removing members, each departing member’s name, billing address, service
address, account number, meter number, projected annual load, percentage
allocation, month of member change, and low-moderate income status, as applicable;
(3) For a group adding or
removing members, each new member’s name, billing address, service address, account
number, meter number, projected annual load, percentage allocation, month of
member change, and low-moderate income status, as applicable;
(4) Except as otherwise
permitted under Puc 902.16 and Puc
902.22, a certification that no new member is a customer-generator;
(5) For a group using
on-bill crediting and changing credit percentage allocations, the name, billing
address, service address, account number, meter number, current percentage
allocation, and low-moderate income status, if applicable, for each group member
and the host;
(6) For a group using
on-bill crediting and changing credit percentage allocations, the new
allocation percentage for each group member and the host;
(7) For a group with a
low-moderate income community solar project, the information specified in Puc 909.09(a)(17); and
(8) For a group with a
low-moderate income community solar project, verification that the percentage
allocations meet the requirements of Puc 909.12(c)
through (e) and Puc 909.13(h).
(f) The host shall
sign and date the change notification submitted.
(g) The individual signing the change
notification shall certify that the information provided is true, accurate, and
complete, to the best of the individual’s knowledge and belief.
(h) For any group with a
low-moderate income community solar project, the commission shall review each
complete change notification for continued low-moderate income community solar
project adder eligibility, and approve or deny such
change notification within 20 business days following its submission pursuant
to Puc 909.06(c)(1). The commission shall notify the utility and the
host of its approval or denial.
Source. #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15 (from Puc
909.05); ss by #13080, eff 9-14-20
Puc 909.07 Annual Report.
(a) Except as otherwise provided in (b) below, each
host shall file with the commission, on or before April 1 of each year after
registration, an annual report that contains the information required by Puc 909.10, and shall send a copy
of the report to the host’s distribution utility. Failure to timely file an annual report shall
authorize the distribution utility to cease making the payments provided for in
Puc 909.08 until the host files its annual report, as
described in Puc 909.08(i)
and (j).
(b) A customer-generator with a residential net-metered
facility with generating capacity less than 15 kilowatts interconnected to a distribution
utility that is not a low-moderate income community solar project, is not
required to file an annual report under this section.
(c) A host’s registration shall expire without
further action by the commission if the host fails to file an annual report by
October 1 of the year the annual report is due, with the
exception of hosts subject to the exemption in (b) above.
(d) The commission shall notify the appropriate
utilities of hosts whose registration has expired under (c) above.
Source. #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15 (from Puc
909.06); ss by #13080, eff 9-14-20
Puc 909.08 Duties
of the Distribution Utility.
(a) With the exception of groups that elect to
receive on-bill credits pursuant to Puc 909.12, upon
receipt of a host registration number, the distribution utility shall
thereafter pay the host for the host’s net excess electricity exported to the
distribution system at the end of each billing cycle in accordance with the utility
tariff provisions applicable to the host’s customer class, unless the host is a
large customer-generator that does not receive default service from the utility.
The first payment shall be due for the
billing cycle beginning with the meter read date immediately following the
effective date of the host’s registration, unless the meter read date is less
than 5 business days after the effective date, in which case the first payment
shall be due for the billing cycle beginning with the next meter read date.
(b) Upon receipt of a host registration number for a group that elects to receive on-bill credits under Puc 909.12, the distribution utility shall thereafter
allocate a monetary credit on the account of the host and each member of the
group pursuant to Puc 909.12(f).
(c) Upon
receipt of a host registration number for a
group with a low-moderate income community solar project under Puc 909.13, the distribution utility shall thereafter
allocate a monetary credit on the account of the host and each member of the
group pursuant to Puc 909.13(c) and (i).
(d) For hosts that are small customer-generators
subject to the standard net metering tariff that receive default service from
the distribution utility, the payments or credits from
the distribution utility for net excess electricity exported to the
distribution system shall be based on all charges assessed on a per-kilowatt-hour
basis.
(e) For hosts that are small customer-generators
subject to the alternative net metering tariff that receive default service
from the distribution utility, the payments or credits from the distribution
utility for net excess electricity exported to the distribution system shall be
calculated based on 25 percent of any distribution charges assessed on a
per-kilowatt-hour basis, any transmission charges assessed on a per-kilowatt-hour
basis, and the default service rate on a per-kilowatt-hour basis.
(f) For hosts that are large customer-generators
and receive default service from the distribution utility, the payments or credits from the distribution utility for net
excess electricity exported to the distribution system shall be based on the
distribution utility’s default service rate.
(g) For hosts that are small customer-generators
subject to the alternative net metering tariff that do not receive default
service from the distribution utility, the payments or
credits from the distribution utility for net excess electricity exported to
the distribution system shall be calculated based on 25 percent of any
distribution charges assessed on a per-kilowatt-hour basis and any transmission
charges assessed on a per-kilowatt-hour basis.
(h) For all hosts not exempted under Puc 909.07(b), by June 1 of each year the distribution
utility shall determine for the prior year whether the host’s net exported
generation exceeded the group’s total electricity use. If so, the host shall only be entitled to compensation
for that excess generation at the avoided cost or default service rate. For purposes of calculating the payment
adjustment under this subsection, the distribution utility shall be bound by
its election pursuant to Puc 903.02(p) of the avoided
cost rate calculated by the commission, or by the distribution utility for each
specific host, or the distribution utility’s default service rate. The distribution utility shall calculate
whether it overpaid the host for that excess generation according to the rates
in (d) through (g) above, and bill the host
accordingly.
(i) If the host’s
registration is suspended under Puc 909.11, or if the
host fails to timely file an annual report required by Puc
909.07(a), the distribution utility shall cease making payments or providing
credits due under this chapter beginning with the billing cycle that starts
with the meter read date immediately following the date of suspension or the
due date for the annual report.
(j) If the distribution utility ceased making payments
under (i) above, the distribution utility shall resume
making monthly payments or providing monthly credits beginning with the billing
cycle that starts with the meter read date immediately following the host’s
re-registration or filing of its annual report, as applicable. The host shall not be entitled to payments,
nor shall the host and members be entitled to any credits, for any billing
cycles with respect to which payments were not made or credits were not
provided as a result of suspension or failure
to timely file any required annual reports.
(k) Any distribution utility serving registered
hosts shall file an annual report with the commission on or before June 1 of
each year, beginning June 1, 2015, covering the immediately preceding calendar year,
which report shall describe the number and location of all registered group
host facilities it serves, the generating capacity and renewable source of each
facility, whether the group is using on-bill crediting, whether the group is a
low-moderate income community solar project, the payments to each host, the
credits provided to each group host and members, and the total load of the
members for each facility, and the load of each host. The distribution utility shall
not be required to include actual host and member load data for hosts that are
exempt from filing annual reports under Puc 909.07(b),
but instead shall include the estimated facility production and estimated host
and member load data for such exempt groups.
(l) Any distribution utility serving registered
hosts with low-moderate income community solar projects shall file with the
commission an appendix to its annual report on or before June 1 of each year covering
the immediately preceding calendar year, which appendix shall provide the total
annual amount of on-bill monetary credits provided to each member of any such
group.
(m) For any
existing net metering customer-generator who becomes a host under this chapter,
the distribution utility shall close out that customer-generator’s net metering
account and make any payments or bill credits due under the applicable tariff
rate for standard or alternative net metering pursuant to Puc
903.02(l) or (m), Puc 903.02(q) shall not apply to an
existing net metering customer who becomes a host.
(n) For any group
which elects to receive on-bill credits, the distribution utility shall make
available to the host through electronic mail, letter, or internet portal the
following information following the end of each host monthly billing cycle:
(1) The total net electricity exports from the
host’s facility during the billing cycle;
(2) The total amount of on-bill monetary credits
accrued to the host and group members during the billing cycle; and
(3) The on-bill monetary credit
allocated to the host and each group member for the billing cycle.
(o) For any group
which elects to receive on-bill credits, the distribution utility shall make
available to the host by January 30th of each year the load for each group
member who was a member for any period during the preceding calendar year, by
such member’s monthly billing cycle during the year.
Source. #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15 (from Puc
909.07); ss by #13080, eff 9-14-20
Puc 909.09 Application to Register or Re-Register as a
Host.
(a) An applicant for registration or
re-registration as a host shall provide to the commission, with a copy to the
distribution utility, the following information:
(1) The host’s name, trade name, if any, address,
service address, telephone number, email address, website address, if any, name
of distribution utility, meter number, and account number;
(2) The name, telephone number, and email address
of the individual responsible for responding to commission inquiries;
(3) The identity of the owner and operator of the
facility;
(4) A list of all members in the host’s group,
including each member’s name, billing address, service address, account number,
meter number, and projected annual load;
(5) Certification that all members of the group
have executed an agreement with the host;
(6) A statement that all members and the host are
customers of the same distribution utility;
(7) The total historic annual load and the total
projected annual load of the host;
(8) The total historic annual load and the total
projected annual load of the members;
(9) The fuel source of the host’s facility, its
generating capacity, the actual annual output of the host’s facility, if known,
and the projected annual output of the facility;
(10) A statement that the total historic annual
load of the members together with the host exceeds the projected annual output
of the host’s facility;
(11) A statement
that the host has provided a copy of the application to the distribution utility;
(12) A statement that the applicant has the
authority to file the application on behalf of the host and that the contents
of the application are true, accurate, and complete;
(13) Except as allowed by Puc
902.16 and Puc 902.22, a certification that none of
the members is a customer-generator;
(14) A statement regarding whether the group is
electing to receive on-bill monetary credits;
(15) A statement regarding whether the group has a low-moderate
income community solar project;
(16) For groups that elect to receive on-bill
monetary credits:
a. The
annual credit percentage allocation for the host and each member; and
b.
A statement verifying that the specified percentage allocations meet the
requirements of Puc 909.12(e); and
(17) For hosts registering a group with a low-moderate
income community solar project:
a. Indication
of residential end-user customer status for the host and each member;
b. Indication
whether the host and each member is a residential
end-user customer with household income at or below 300 percent of the federal
poverty guidelines;
c. Specification
of the amount of any group host or member load attributable to non-residential
end-user customers, residential end-user customers, and affordable housing projects;
d. Description
of the income verification procedure for the group;
e. Certification
that the group meets the requirements of Puc 909.13(d);
f. Certification
that the agreement meets the requirements of Puc 909.05(e);
g. Statement confirming that the specified credit
percentage allocations meet the requirements of Puc
909.12(c) through (e) and Puc 909.13(h);
h. Certification
that no member is also a member of another group at the time of registration;
i. Documentation
demonstrating that any member which is an affordable housing project qualifies
as such under Puc 902.01; and
j. Description
of the direct, quantifiable benefits to be provided by any member which is an
affordable housing project to the tenants or residents of that project pursuant
to Puc 909.13(e).
(b) The applicant shall sign and date the
document.
(c) The individual signing the document shall certify
that the information provided is true, accurate, and complete, to the best of
the individual’s knowledge and belief.
(d) For groups participating in on-bill crediting,
member information and credit percentage allocations shall be provided in xls format.
(e) The applicant shall electronically file the
document and any attachments, in a format compatible with the computer system
of the commission, pursuant to Puc 203.03, or through
the following email address: PUCGroupNetMetering@puc.nh.gov. The
commission shall accept the document and any attachments through the U.S. mail,
by overnight express service, or by hand delivery, if the applicant is unable
to file the document electronically.
Source. #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15 (from Puc
909.04); ss by #13080, eff 9-14-20
Puc 909.10 Host’s Annual Report.
(a) On or before April 1 of each year, beginning
the year after the host received a registration number, all hosts shall provide
to the commission, with a copy sent to the distribution utility, an annual
report containing the following information, covering the immediately preceding
calendar year:
(1) Any changes to the
information required by Puc 909.09;
(2) For
groups participating in group net metering without on-bill crediting, the
applicable information regarding changes to the group as required by Puc 909.06(e);
(3) A calculation, with
supporting documentation, for each month of the year, of the total electricity
generated by the host’s facility, the total net electricity exported to the
distribution system for which the host was compensated under these rules, the
host’s total load for which it was billed by the utility, the total billed load
of each member, and the total billed load of all members; and
(4) Any
host with a low-moderate income community solar project shall provide in xls format the following additional information, covering
the immediately preceding calendar year, together with the host annual report:
a. Identification
of each group member who is a residential end-user customer with household
income at or below 300 percent of the federal poverty guidelines, who is a
residential customer not identified as having such a household income level, or
which is an affordable housing project;
b. Certification
that all members who are residential end-user customers with household income at
or below 300 percent of the federal poverty guidelines have been income-verified
by a method or methods consistent with Puc 909.13(f) within
the year covered by the annual report;
c. The total
amount of monetary credits awarded by month to each group member and the host;
d. Copies of the
monthly documentation provided to the host by the distribution utility pursuant
to Puc 909.08(n);
e. The total
percentage of all monetary credits that was distributed to group members who
are residential end-user customers with household income at or below 300
percent of the federal poverty guidelines or which are affordable housing projects;
f. Certification
that the group met the requirements specified in Puc 909.13
during the preceding calendar year;
g. For any member
which is an affordable housing project, the total amount of on-bill monetary
credits, net of payments or other charges under any power purchase agreement or
other contractual arrangement with the host, that was available to provide
direct, quantifiable benefits to the tenants or residents of that project
pursuant to Puc 909.13(e); and
h. Description of
the direct, quantifiable benefits provided by a member which is an affordable
housing project to the tenants or residents of that project pursuant to Puc 909.13(e), including total benefit-related spending for
the calendar year covered by the report.
(b) The host shall
sign and date the annual report.
(c) The host signing the annual report shall state
that the information in the annual report is true, accurate, and complete, to
the best of the individual’s knowledge and belief.
(d) The host shall electronically file the annual
report, in a format compatible with the computer system of the commission,
pursuant to Puc 203.03, or through the following
email address: PUCGroupNetMetering@puc.nh.gov. The commission shall accept the annual report
through the U.S. mail, by overnight express service, or by hand delivery, if
the host is unable to file the report electronically.
Source. #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15 (from Puc
909.06); ss by #13080, eff 9-14-20
Puc 909.11 Sanctions
for Failure to Comply.
(a) The commission shall suspend a host’s registration
for a period of not more than 2 years, after notice and an opportunity to be
heard, for any of the following:
(1) A material
misrepresentation of information required by Puc
909.09, which, if accurately reported, would have resulted in the denial of the
application;
(2) A material violation of
Puc 909 or RSA 362-A:9, XIV; or
(3) A material violation of
any commission order.
(b) The commission shall determine the period of
suspension based on:
(1) The severity of the infraction;
(2) Whether the host acted
in good faith;
(3) Whether other
mitigating or aggravating circumstances exist; and
(4) Other relevant
information pertaining to the host and its principals.
(c) The commission shall notify the appropriate
distribution utility of any host suspension.
(d) A host whose registration was suspended may,
at the end of the period of suspension, seek reinstatement by submitting a
re-registration application pursuant to Puc 909.03.
Source. #10502, INTERIM, eff 1-3-14, EXPIRED: 7-2-14
New. #10757, eff 1-8-15 (from Puc
909.08); ss by #13080, eff 9-14-20
Puc 909.12 Group Net Metering with On-Bill
Credits.
(a) A customer-generator registering or re-registering a group with the commission on
or after July 1, 2019 may elect in the application for
registration or re-registration for the group host and all group members to
receive on-bill credits.
(b) To elect on-bill monetary credits, a group
shall meet all of the applicable requirements of this
chapter and the host shall provide the
additional information required under Puc 909.09(a)(16).
(c) The host of a group for which on-bill
monetary credits have been elected shall specify the percentage of the net metering credit monetary amount otherwise payable
to the host to be allocated to the host and to each group member on their
respective distribution utility bills, which percentage shall apply to the sum
of the base net metering credit and the additional credit amount described in Puc 909.13(b) for any group registered as a low-moderate
income community solar project,
pursuant to Puc 909.13(h).
(d) The percentage allocations required under (c) above shall be made initially in the
registration or re-registration application submitted by the host, and
thereafter any changes to such allocations shall be made in the group change notification required to be
submitted pursuant to Puc 909.06(c).
(e) For all groups receiving on-bill monetary credits, the credit percentage allocations
shall be subject to the following restrictions:
(1) The percentage allocations
shall total 100 percent; and
(2) Each group member’s total
percentage allocation shall be greater than zero.
(f) Upon receipt of a host registration number
for a group for which on-bill monetary credits have been elected under this
section, the distribution utility shall thereafter allocate a monetary credit
on the host’s and each member’s account as follows:
(1) A total monetary credit shall
be calculated for the host’s net excess electricity exported to the
distribution system at the end of each billing cycle based on the applicable
net metering tariff and host rate class;
(2) The total monetary credit
calculated pursuant to (1) above shall be distributed to the host and the group
members as monetary credits on their monthly utility bills in accordance with
the percentage allocations specified in accordance with (c) through (e) above; and
(3) The monetary credit shall be
separately itemized on a customer’s bill and deducted from the balance due on
the bill after all applicable charges and all other credits.
Source.
#13080, eff 9-14-20
Puc 909.13 Low-Moderate
Income Community Solar Projects.
(a) The host
customer-generator for a low-moderate income community solar project shall
register as a low-moderate income community solar project group by providing
the information in its registration application as specified in Puc 909.09(a)(1) through (17).
(b) A group registered with a
low-moderate income community solar project shall receive additional on-bill
monetary credits for all excess electricity production eligible under Puc 909.08(c) through (j), at the following rates for the
specified time periods:
(1) An
additional 3 cents per kilowatt-hour through July 1, 2021; and
(2) An
additional 2.5 cents per kilowatt-hour on July 2, 2021 and thereafter.
(c) The group host of a
low-moderate income community solar project shall have the option to receive
payment from the electric distribution utility on a monthly
basis equal to the host’s on-bill monetary credit amount in excess of
the host’s billed charges for the billing period.
(d) To register as a low-moderate
income community solar project group, a project shall meet the following requirements:
(1) The host
facility has an initial operational date on or after July 1, 2019;
(2) The host
has elected for the group to receive on-bill credits pursuant to Puc 909.12;
(3) The host
shall indicate whether it elects the monthly payment option provided under (c) above;
(4) The group
includes at least 5 residential end-user customers;
(5) A majority
of the residential end-user customers in the group have household income at or below 300 percent of the federal
poverty guidelines, as verified by the methods specified in (f) below;
(6) No more
than 15 percent of the projected annual load for the group is attributable to
non- residential end-user customers;
(7) A group
member that is an affordable housing project will provide direct benefits to
the tenants or residents of that project as provided in (e) below;
(8) No group
member who is a residential end-user customer with household income at or below
300 percent of the federal poverty guidelines shall be charged or assessed any
subscription fee, investment amount, termination fee, withdrawal charge, or
other cost, expense, fee, charge, price, or other amount as a condition of his
or her group membership; and
(9) Solely
for the purposes of this paragraph (d), the projected annual load for a group
that is attributable to non-residential end-user customers shall not include
any such projected load attributable to affordable housing projects.
(e) A group member that is an
affordable housing project shall provide direct, quantifiable benefits, such as
rental payment
reductions, building improvements, energy efficiency measures, wireless
internet access, investments in new affordable housing units, or resident
services to the extent not reimbursed or otherwise funded by a federal, state,
or local source, to the tenants or residents of that project, unless the provision of such benefits would result in
any tenant’s or resident’s ineligibility for, or reduction in the amount of
benefits available from, any other federal, state, or local assistance program.
(f) The host shall be responsible for initial and
ongoing annual income verification for group members who are residential
end-user customers with household income at or below 300 percent of the federal
poverty guidelines, using one of the following income verification methods:
(1)
Participation in the electric assistance program;
(2)
Income verification performed by a community action agency;
(3) A
complete copy of an award letter dated within 12 months of the income
verification date for the Home Energy Assistance Program/Fuel Assistance
Program, Supplemental Nutrition
Assistance Program, Temporary Assistance for Needy Families, or Supplemental
Security Income;
(4)
Verification of moderate income members with
sufficient documentation to verify that
annual income is at or below 300 percent of the federal poverty guidelines; or
(5) An
alternative income verification method functionally equivalent to the methods described
in (1) through (3) above that is proposed by a host and approved by the
commission.
(g) The commission or its third
party contractor may independently review and verify a host’s income
verification method and documentation, group members’ income information, and
eligibility criteria compliance for low-moderate income community solar projects.
(h) In addition to compliance with Puc 909.12(c) through (e), the host of a group registered
as a low-moderate income community solar project shall make on-bill monetary
credit percentage allocations to the host and group members such that the sum
of such percentage allocations to members that are residential end-user
customers with household income at or below 300 percent of the federal poverty
guidelines or affordable housing projects shall not be less than 12 percent of
the total credit amount allocated to the host and all group members.
(i) Upon receipt of a
host registration number for a group registered as a low-moderate income
community solar project, the distribution utility shall thereafter allocate an on-bill monetary credit to the
host’s and each group member’s account as follows:
(1) A
total monetary credit shall be calculated for the host’s net excess electricity
exported to the distribution system
at the end of each billing cycle,
based on the alternative net metering
tariff and host rate class, plus an additional 3 cents per kilowatt-hour
through July 1, 2021 and 2.5 cents per kilowatt-hour after
that date;
(2)
The total monetary credit for each billing cycle calculated pursuant to
(1) above shall be distributed to the host’s and members’ accounts in
accordance with the percentage allocations specified pursuant to Puc 909.12(c) through (e) and (h) above;
(3)
The monetary credit shall be separately itemized on one line on a
customer’s bill and deducted from the balance due on the bill after all
applicable charges and all other credits; and
(4)
Monthly payments shall be made to any group host that has elected the
monthly payment option provided under (c) above.
(j) The host of a group registered as a
low-moderate income community solar project shall demonstrate the continuing
eligibility of the group on an annual basis by providing the information
required pursuant to Puc 909.10(a)(4).
Source.
#13080, eff 9-14-20
Puc 909.14 Confidentiality.
The registration and re-registration applications,
the host’s annual report, the distribution utility’s annual report described in
Puc 909.08(i), and any
related attachments provided to the commission shall be public documents which shall be disclosed by the
commission upon request, except that the commission shall protect from public
disclosure to the extent permitted by law information that is considered to be
confidential, commercial, or financial, or other information, the disclosure of
which would constitute an invasion of privacy. Notwithstanding the foregoing, any information
submitted to the commission pursuant to this chapter shall be available to the
commission for the preparation and public release of statistics and other
metric and non-metric data.
Source. #10757, eff 1-8-15
(from Puc 909.11); ss by #13030, eff 9-14-20)
(formerly Puc 909.12)
Puc 909.15 Electronic Documents
and Signatures. All documents and
signatures referenced in this chapter may be electronic as authorized by RSA
294-E.
Source. #10757, eff 1-8-15;
ss by #13080, eff 9-14-20 (formerly Puc 909.13)
APPENDIX A
Rule(s) |
Statute |
Puc 902
and 909 (other specific provisions implemented by specific rules listed
below) |
RSA 362-A:9, X and 365:8, I(l) |
Puc
902.01 |
RSA 362-A:9, XIV(a) |
Puc
902.02 |
RSA 362-A:9, XVI |
Puc 902.03 |
RSA 362-A:1-a, I-d |
Puc
902.04 |
RSA 362-A:1-a, II-b |
Puc
902.08 |
RSA 374-F:2, II |
Puc
902.09 |
RSA 362-A:1-a, II-c |
Puc
902.12 |
RSA 362-A:9, XIV(a) |
Puc
902.13 |
RSA 362-A:1-a, II-d |
Puc 902.14 |
RSA 362-A:9, XIV(a) |
Puc
902.17 |
RSA 362-A:9, XIV(a) |
Puc
902.18 |
RSA 362-A:1-a, III-a |
Puc
902.22 |
RSA 362-A:9, XVI |
Puc 903 |
RSA 362-A:9 |
Puc
903.01(c) |
RSA 362-A:9, II |
Puc
903.01(n) |
RSA 362-A:9, XIII |
Puc
903.02(g) |
RSA 374-F:7 |
Puc
903.03 |
RSA 362-A:1-a, II-b; RSA 362-A:9, X(b); RSA 365:8, I(l) |
Puc
904.02 |
RSA 362-A:9; RSA 362-F:4, I (a) through (f); RSA 365:8, I(1) |
Puc
908.03 |
RSA 365:8, I |
Puc
908.05 |
RSA 365:8, I(1) |
Puc
908.06 |
RSA 541-A:30, II |
Puc
908.07 |
RSA 362-A:9; RSA 374:15 |
Puc
909.01 |
RSA 362-A:9, XIV |
Puc
909.02 |
RSA 362-A:9, XIV |
Puc
909.03 |
RSA 362-A:9, XIV(a) |
Puc
909.04 |
RSA 362-A:9, XIV(a) |
Puc
909.05 |
RSA 362-A:9, XIV(a) |
Puc
909.06 |
RSA 362-A:9, XIV(a) |
Puc
909.07 |
RSA 362-A:9, XIV; RSA 362-F:10, IV |
Puc
909.08 |
RSA 362-A:9, XIV |
Puc
909.09 |
RSA 362-A:9, XIV(a) |
Puc
909.10 |
RSA 362-A:9, XIV(a); RSA 362-F:10, IV |
Puc
909.11 |
RSA 362-A:9, XIV(e) |
Puc
909.12 |
RSA 362-A:9, XIV |
Puc
909.13 |
RSA 362-A:9, XIV; RSA 362-A:9, XIX |
Puc
909.14 |
RSA 365:8, I(d); RSA 91-A:5 |
Puc
909.15 |
RSA 294-E |
APPENDIX B: INCORPORATION
BY REFERENCE INFORMATION
Rule |
Title (date) |
Source |
Puc
906.01(a)(1) Puc
907.01(a)(1)d. |
IEEE
Standard 1547 (2018) for Interconnecting Distributed Power Resources with
Electric Power Systems |
Institute
of Electrical and Electronic Engineers, Inc., 445 Hoes Lane, Piscataway, New
Jersey 08854 Purchase
of pdf for $151.00 available at https://standards.ieee.org/standard/1547-2018.html |
Puc
906.01(a)(2) |
UL
1741 SA, Standard for Inverters, Converters, Controllers with Interconnection
System Equipment for Use with Distributed Energy Resources (2010) |
Underwriters
Laboratories, Inc., 333 Pfingsten Road, Northbrook,
Illinois 60062 Standard 1741, Edition
2 Edition Date: January
28, 2010 Available for purchase
at: https://standardscatalog.ul.com/standards/en/standard_1741_2 for $716.00-$1,567.00 |
Puc
907.01(b) |
National Electrical Code, 2017 Edition |
National Fire Protection Association 1 Batterymarch
Park Quincy, Massachusetts 02169-7471 Available for $108.00 for softbound volume and $201.50 for handbook
at: http://www.nfpa.org/ |