CHAPTER Puc 300
RULES FOR ELECTRIC SERVICE
Statutory
Authority: RSA 365:8.
PART Puc 301
APPLICATION OF RULES
Puc 301.01
Application of Rules.
(a) This
chapter shall apply to any utility as defined by Puc 302.23 except as provided
in (b) below.
(b) This
chapter, except for the sections below, shall not apply to any rural electric
cooperative for which a certificate of deregulation is on file pursuant to RSA
301:57:
(1) Puc 303.01,
filing of tariffs;
(2) Puc
307.01, records;
(3) Puc
307.02, preservation of records; and
(4) Puc
307.04, uniform system of accounts.
Source. #2011, eff 5-4-82; amd by #2031, eff 5-11-82;
ss by #2912, eff 11-26-84; ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff
11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97, ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 301.02 Notice of Intent to Produce Electricity. Any facility located within New Hampshire
proposing to generate electricity over one megawatt ultimately sold to the
public shall notify the commission in writing of its intent to produce
electrical energy at least 6 months prior to the date energy is first proposed
to be produced.
Source. #6605, eff 10-21-97, ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
PART Puc 302
DEFINITIONS
Puc 302.01 "Commission" means the
Source. #2011, eff 5-4-82; amd by #2031, eff 5-11-82;
ss by #2912, eff 11-26-84; ss by #4999, eff 11-26-90; ss by #5716, eff 10-7-93;
ss by #5877, eff 8-9-94; ss by #6605, eff 10-21-97; ss by #8448, eff 10-18-05;
ss by #10603, eff 5-21-14
Puc 302.02. “Competitive electric power supplier (CEPS)”
means any person or entity that sells or offers to sell electricity to retail
customers in this state pursuant to RSA 374-F:7. The term does not include any utility or any
municipal or county corporation operating within its corporate limits or
submetering at campgrounds as described in RSA 362-a.
Source. #6605, eff 10-21-97 (from Puc 302.01); ss by
#8448, eff 10-18-05; ss by #10603, eff 5-21-14
Puc
302.03 “Creep” means a condition where
the rotor of a mechanical meter rotates continuously when rated voltage is
applied and the load terminals are open circuited.
Source. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14 (from Puc 302.02)
Puc 302.04 "Customer" means any person, firm,
corporation, cooperative marketing association, utility, governmental unit, or
subdivision of a municipality or of the state or nation, supplied with electric
service by any utility.
Source. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14 (from Puc 302.03)
Puc 302.05 “Demand” means the average power measured
over a specified interval of time.
Source. #6605, eff 10-21-97 (from Puc 302.01); ss by
#8448, eff 10-18-05; ss by #10603, eff 5-21-14 (from Puc 302.04)
Puc 302.06
“Electronic indicating demand device” means an indicating device that
determines demand values based on electronic pulse inputs from an auxiliary
device to a solid state circuit designed to calculate and display demand
quantities in conjunction with a timing signal derived from the line frequency
or a crystal oscillator timing circuit.
Source. #6605, eff 10-21-97 (from Puc 302.01); ss by
#8448, eff 10-18-05; ss by #10603, eff 5-21-14 (from Puc 302.05)
Puc 302.07
“Electronic meter” means a meter that has measurement circuitry built
primarily of solid state electrical components.
Source. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14 (from Puc 302.06)
Puc 302.08
"Electric service" means the delivery of electricity to a
customer in this state by a utility.
Source. #6605, eff 10-21-97 (from Puc 302.01); ss by
#8448, eff 10-18-05; ss by #10603, eff 5-21-14
Puc 302.09 "Energy conservation" means energy
use activities that cost less to implement than the value of the resources saved.
Source. #6605, eff 10-21-97 (from Puc 302.01); ss by
#8448, eff 10-18-05; ss by #10603, eff 5-21-14 (from Puc 302.07)
Puc 302.10
“Full load” means the meter accuracy test point at rated test voltage,
rated test current and 1.0 power factor.
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14 (from Puc 302.09)
Puc 302.11
“Independent System Operator for New England” (ISO-NE) means the
administrator or operator for
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14
Puc
302.12 “Indicating demand device” means
a type of metering equipment used to measure and display demand values.
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14 (from Puc 302.10)
Puc
302.13 “Light load” means the meter
accuracy test point at rated test voltage, 10% of rated test current and 1.0
power factor.
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14 (from Puc 302.11)
Puc 302.14
“Master metering” means the use of a single meter to supply electric
service at a building that contains 2 or more residential premises.
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14 (from Puc 302.12)
Puc 302.15
“Mechanical indicating demand device” means a device which uses either
mechanical thermal elements or mechanical gearing in conjunction with a demand
interval timing motor to determine demand values.
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14 (from Puc 302.13)
Puc 302.16
“Mechanical meter” means a watt-hour meter built with a stator and rotor
assembly that operates via electromagnetic induction principles.
Source. #8448, eff 10-18-05; ss by #10603, eff 5-21-14
(from Puc 302.14)
Puc 302.17
"Meter" means a device installed for the measurement of
electrical quantities to be used as a basis for determining charges for
electric service.
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14 (from Puc 302.15)
Puc 302.18
"Power factor" means "power factor" as defined in
the
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14 (from Puc 302.16)
Puc 302.19
“Power factor load” means the meter accuracy test point at rated test
voltage, rated test current and 0.5 lagging power factor.
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14 (from Puc 302.17)
Puc
302.20 “Recording demand device” means
separate equipment used to record electronic pulse inputs from an auxiliary
device in measured time intervals where the timekeeping signal is derived from
the line frequency or a crystal oscillator timing unit.
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14 (from Puc 302.18)
Puc 302.21
“Register multiplier” means the multiplier used to convert the displayed
register readings in kilowatt hours or other units taking into consideration
the watt-hour constant, gear ratios, electronic register programming constants
and instrument transformer ratios as necessary.
This term includes “register constant.”
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14 (from Puc 302.20)
Puc 302.22
“Root mean square (RMS)” means the measure of steady-state voltage or
current as calculated from the square root of the mean of the squares from the
voltage or current waveform.
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14 (from Puc 302.21)
Puc 302.23
"Utility" means any public utility as defined in RSA 362:2
owning, operating or managing any plant or equipment or any part of the same
for the transmission, distribution or generation of electricity ultimately sold
to the public within New Hampshire except:
(a)
Municipal corporations, to the extent exempt pursuant to RSA 362:4-a;
(b)
Entities specifically exempted from the definition of “public utility”
pursuant to RSA 362:4-c; and
(c)
Competitive energy suppliers that have not requested public utility
status pursuant to RSA 374-F:7,I.
Source. #10603, eff 5-21-14 (from Puc 302.22)
Puc 302.24 “Wide-scale emergency” means an event that is
an event which results in, or is or expected to result in:
(a)
A sustained interruption of electric service to 10% or more of the
utility’s customers, or 40,000 of the utility’s customers, whichever is less
and restoration of electric service to any of these customers takes more than
24 hours; or
(b)
The federal, state or local government declaring an official state of
emergency in the utility’s service territory and the emergency involves an
interruption of electric service.
Source. #10603, eff 5-21-14
PART Puc 303
SERVICE PROVISIONS
Puc
303.01 Filing of Tariffs. No utility shall provide electric service
until it has published and filed a complete tariff with the commission in
accordance with Puc 1600.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97, ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 303.02
Master Metering.
(a)
No utility shall install master metering in a building with multiple
dwelling units. The energy in each dwelling
unit in such a building shall be separately metered.
(b) A
utility shall only install master metering in commercial buildings and as
consistent with the International Energy Conservation Code 2009 as adopted pursuant to RSA 155-A:1,IV.
(c) Hotels, motels, dormitories, boarding houses
and time-sharing interests in
condominiums as defined in RSA 356-B:3 shall not be considered a dwelling unit
within the meaning of Puc 303.02(a) above.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6245, eff 5-14-96; ss by #6605, eff 10-21-97;
ss by #8448, eff 10-18-05; ss by #10603, eff 5-21-14
Puc 303.03
Meter
(a) The
customer shall be provided metering equipment for each service location which
measures or provides information to determine the following:
(1) The
number of kilowatt-hours (kWh) registered; and
(2) If
applicable, the following:
a.
Kilowatt (kW) demand;
b.
Kilovolt amperes (kVA) demand; and
c. Kilovolt-ampere
reactive (kVAr) demand.
(b) A
utility shall plainly mark the meter constants on a visible surface or base of
all its meters which show the watt-hours per revolution of the meter disk or
the electronic equivalent applicable to an electronic meter.
(c) A utility shall plainly mark on a visible
surface or base of all its meters the register constant if the register
constant is not one.
Source. #2011, eff 5-4-82; amd by #2173, eff
11-11-82; ss by #2912, eff 11-26-84; ss by #4999, eff 11-26-90; ss and moved by
#6245, eff 5-14-96 (from Puc 303.05); ss by #6605, eff 10-21-97; ss by #8448,
eff 10-18-05; ss by #10603, eff 5-21-14
Puc 303.04 Change in Character of Service.
(a) For purposes of this section, "change in
the character of service” means any
change in voltage, location of facilities or direction of feed implemented by
the utility which results in new equipment requirements for an affected
customer.
(b) If a
utility makes a change in the character of a customer's service for the
convenience or benefit of the utility, the utility shall pay such part of the
cost of changing the equipment of the customers affected as determined by
agreement between the customer and the utility or, in the absence of such an
agreement, by the commission.
(c) If
called upon to determine the cost which the utility shall bear for a change in
the character of service for the benefit of the utility, the commission shall
order payment by the utility to the customer of:
(1) The
cost of the customer's electrical utilization equipment from the point of
delivery back to the source which is made obsolete by the change, less proper
allowance for depreciation;
(2) The
cost of installing the new equipment and removing the old equipment, less the
salvage value of such equipment which the customer elects to retain; and
(3) The
cost of making the necessary change in the customer's wiring.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
amd by #4341, eff 11-24-87; ss by #4999, eff 11-26-90; ss and moved by #6245,
eff 5-14-96 (from Puc 303.07); ss by #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
PART Puc 304
QUALITY OF ELECTRIC SERVICE
Puc 304.01
Frequency. A utility shall
provide alternating current distribution systems which shall have a design and
operating frequency of 60 cycles per second under normal system conditions
which shall vary only within a narrow range according to operations criteria
established by the ISO-NE.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 304.02
Voltage Variation.
(a) For
purposes of this section, "Y" means the 4 wire connection type used
for a particular 3 phase electric system component.
(b) Each
utility furnishing electric service shall adopt a standard nominal average RMS
voltage or voltages which are consistent with the design of the distribution
system for its entire service area and for each of the districts or zones into
which the distribution system or systems are divided from one of the following
systems:
(1) For
secondary voltages of 120 and 120/240 volts, single phase 2-wire or 3-wire
systems; or
(2) For
secondary voltages of 120/208Y, 240, 277/480Y, 480 and 600 volts, 3-phase,
3-wire or 4-wire systems.
(c)
A utility shall maintain the nominal secondary voltage at the utility's
service terminals or at the street lamp in the case of multiple street
lighting, as installed for each customer, within plus or minus 5% average RMS.
(d) When a customer receives service from primary
distribution voltage and is responsible for supplying its own voltage
regulation, the utility shall maintain the nominal secondary voltage at the
utility’s service terminals as installed for each customer, within plus or
minus 10% RMS, except as provided in (e) below.
(e) When a customer is not responsible for its
own voltage regulation, the utility shall maintain the nominal average RMS voltage
at the utility’s service terminals, as installed for each customer, within plus
or minus 5%.
(f) The requirements of (d) and (e) above shall
not apply to transactions between utilities provided that primary customer
voltage requirements are maintained.
(g) Each utility shall submit a compliance plan
for (c) above for commission approval.
(h)
Voltage variations outside of the limits in (c), (d) and (e) shall be
allowed in accordance with American National Standards Institute (ANSI)
C84.1-2011, available as noted in Appendix B.
(i) A
utility may vary from the voltage requirements provided by this section in a
special contract provided that:
(1) The permissible variation in voltage for
service shall be specifically mentioned in the contract; or
(2) A statement is included in the contract to
indicate that the contracting parties are in agreement concerning the allowable
variation.
(j) When
voltage measurements for detecting variations are required, a utility shall
make the measurements at the utility's service terminals, or at the street lamp
in the case of multiple street lighting, unless otherwise agreed to by the
customer and the utility.
(k) If
voltage measurements are taken at places other than at the utility’s service
terminals or at the street lamp in the case of multiple street lighting, those
measurements shall be corrected to the utility’s service terminal or street
lamp in the case of multiple street lighting.
(l) The
utility shall maintain the voltage and frequency delivered at the utility’s
service terminals or at the street lamp in the case of multiple street
lighting, pursuant to Puc 304.01 and Puc 304.02(b), (c), (h) and (i).
(m)
Voltage outside the limits specified in this section shall not be
considered a violation of this section when such variations:
(1) Arise
from adverse weather conditions;
(2) Arise
from operation of the affected customer's equipment at low power factor;
(3) Arise
from unbalanced operation of the affected customer's equipment;
(4) Arise
from failure of, or emergency maintenance on, equipment;
(5) Are
transient events on a system designed to good utility practice, as defined in
Puc 306.01(b), arising from operation of system equipment during system
protection, control, and switching activities;
(6) Are
caused by emergency system operating conditions or order of the independent
system operator; or
(7) Arise from actions of others.
(n) A
voltage variation shall not be considered a violation of this section if:
(1) The
variation does not occur more than once per day; and
(2) Does not exceed 2 minutes in duration.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 304.03 Interruptions of Service.
(a) Each utility shall use all reasonable means
within industry practices to avoid interruptions to service, including:
(1) Maintaining
appropriate levels of maintenance;
(2)
Planning for unexpected events; and
(3)
Considering in decisions affecting potential interruptions to service:
a. The
potential safety, reliability, cost and delay issues; and
b. The
manner that best accommodates the public.
(b) If an
interruption to service occurs, the utility shall restore service within the
shortest time reasonable, consistent with safety, and provide service on a
24-hour basis.
(c) Each utility
shall maintain a record, as required in (d) below, when an interruption to
service of more than a 5 minute duration occurs affecting:
(1) An
entire substation; or
(2) The
entire distribution circuit of a substation.
(d) When
an interruption to service occurs as described in (c) above, a utility shall:
(1) Keep
a record of the circumstances of the interruption; and
(2)
Report the interruption to the commission on form E-2, pursuant to Puc
308.02.
(e) When service
is interrupted to perform work on lines or equipment, the utility shall conduct
such work at a time causing minimum inconvenience to customers consistent with
the circumstances.
(f) A
utility shall attempt to notify all affected customers in advance of all
planned interruptions to service.
(g) When a utility has actual notice of
customers known by the utility who would encounter a potentially
life-threatening situation as a result of a planned service interruption, the
utility shall provide actual notice to those customers of planned service
interruptions.
(h) A
potentially life-threatening situation, for purposes of (g) above, shall mean a
situation where:
(1) A
customer relies upon life support equipment; or
(2) Any
other potentially life-threatening medical condition exists.
(i) A
utility shall be permitted to require the customer to document the potentially
life-threatening situation and to request such documentation be updated on an
annual basis.
(j) A
utility shall interrupt or curtail electric service or vary the characteristics
thereof under the following circumstances:
(1) When
necessary to prevent injury to persons or damage to property;
(2) When
directed or requested to do so by police, fire, or other public safety officials;
(3) When
required by conditions occurring in the interconnected transmission grid
connected to its facilities, to effect temporary load reduction for the common
good; or
(4) With notice
to the customers or group of customers and the commission pursuant to Puc
1203.11, to prevent a single customer or group of customers from causing
continuing adverse effects to the electricity supply of another customer or
group of customers.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 304.04
Voltage Complaints.
(a) Upon
receipt of a customer voltage complaint, a utility shall investigate to
determine whether the complaint was founded or unfounded.
(b) For
the purposes of this section:
(1)
“Founded” means the utility’s determination that the voltage complaint
was based on a voltage variation in violation of Puc 304.02;
(2)
“Unfounded” means the utility’s determination that the voltage measures
were within the limits established in Puc 304.02; and
(3)
“Voltage complaint” means written notice to the company or oral
communication with the utility’s customer service representatives by the
customer of conditions or circumstances that suggest or evidence voltage
variations outside of the limits established in Puc 304.02.
(c) When
a utility determines that a voltage complaint is founded, it shall take
appropriate steps to correct the condition and bring voltage into the limits
established in Puc 304.02.
(d) When
a utility determines that a voltage complaint is founded or unfounded, it shall
provide written notification to the customer within 10 calendar days of such
determination.
(e) Each
utility shall report voltage complaints on a monthly basis to the commission
pursuant to Puc 308.01.
(f) Each utility shall maintain all records of
voltage complaints investigated pursuant to (a) above for a period of 5 years
from the date of the complaint.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
PART Puc 305
METER ACCURACY AND TESTING
Puc 305.01
Inspection of Meters.
(a) A
utility shall inspect all meters for correctness of register constant before
installing the meter on a customer's premises.
(b) No
new watt-hour meter shall be placed into service unless specific test results
indicate a registration within the tolerances of Puc 305.02(a) below.
(c)
Paragraph (b) above shall not apply to electronic indicating demand
devices such as electronic recorders and internal electronic registers which
shall be subject to examination by utilities to assure that the devices have
not been modified in a way that affects performance.
(d) A
utility shall test each new watt-hour meter prior to installation.
(e) A
utility shall use one of the following methods to comply with (d) above:
(1) Test
all meters received from the manufacturer;
(2) Conduct sample testing after commission
approval of the sample testing methods; or
(3)
Accept manufacturer testing data with specific test results consistent
with Puc 305.03(a) below.
(f) Before returning a meter to service which has
been removed from service for any reason, a utility shall inspect and, if
necessary:
(1) Repair the meter; or
(2) Recalibrate the accuracy of the meter.
(g) A
utility shall inspect all watt-hour meters and demand devices for correctness
of operation when installed, perform an electrical test of all instrument
transformer connections, and correct or repair such meters and devices as
necessary.
(h) Prior
to or at the time of installation of all instrument transformers, a utility
shall also conduct the following activities:
(1)
Review and maintain manufacturer’s test data for instrument transformers
purchased;
(2)
Verify the current transformer ratio and voltage transformer ratio via
electrical testing;
(3) Verify wiring by performing an inspection of
instrument transformer secondary circuit connections consisting of:
a.
Verification of polarity by using one of the following methods:
1.
Electrical testing where sufficient load current exists; or
2. Visual inspection of control cable wiring between
the instrument transformer secondary terminals and the meter terminals;
b.
Verification that the current transformer input signal phase matches the
corresponding voltage or voltage transformer input signal phase to the meter;
and
c.
Verification that phasing is appropriate where multiple primary
conductors exist for one or more phases that serve as the primary windings for
a window type current transformer; and
(4) Confirm the effective current transformer
ratio based on the nominal nameplate ratio for the connected secondary
terminals along with proper consideration for multiple primary conductor loops
in window type current transformer installations.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 305.02 Test and Calibration of Meters.
(a) A utility shall test all watt-hour meters at loads
and adjust to tolerances as follows:
(1) At full load, the meter shall register within
plus or minus 1%;
(2) At light load, the meter shall register
within plus or minus 1%; and
(3) At power factor load, the meter shall register
within plus or minus 2%.
(b) A utility shall test mechanical meters for
creep by visual inspection of the meter’s rotor or utilizing electronic test
methods.
(c) If the rotor does not move with rated voltage
and no load current applied to the meter, it shall be considered to have passed
the test required by (b) above.
(d) If movement is detected in the rotor when
rated voltage and no load currents are applied to the meter, the movement shall
be timed and if the results comply with the creep test guidelines of section
4.7.2.1. of ANSI C12.1-2008, as noted in Appendix B, it shall be considered to have passed the
test required by (b) above.
(e) Meters which fail the creep test shall not be
placed into service.
(f) A utility shall test and adjust all
indicating and recording demand devices as follows:
(1) The utility shall verify that any indicating
demand device shall reset properly to zero when placed in service or allowed to
remain in service without adjustment;
(2) The utility shall, in order to determine the
accuracy of each mechanical indicating demand device, conduct an up-scale test,
meaning a test on the upper end or at the higher values of the scale of the
meter, as follows:
a. According to the meter manufacturer's specifications;
or
b. If the meter manufacturer does not provide
specifications as to conducting an up-scale test, with a test conducted at a
minimum of one demand interval cycle, at a point near 1/2 scale;
(3) A utility shall not place in service or allow
to remain in service after inspection any mechanical indicating demand device
which has an error in indication of more than plus or minus 2% in full scale
registration without adjustment; and
(4) Recording demand devices shall conform to the
in service requirements of ANSI C12.1-2008, available as noted in Appendix B.
(g) To determine the accuracy of electronic
indicating demand devices, each utility shall conduct a test at a load and time
interval that will result in a demand reading with resolution sufficient to
determine that the reading is within plus or minus 2% of the average load
applied to the meter during the test. For shipments of new self-contained
single phase or network demand meter purchases, the utility shall only be
required to test a sample of meters, consistent with 305.01(e)(2), to verify
the demand related programming values are correct and that demand calculations
are performed correctly.
(h) A utility shall test all motors used to
maintain a timing cycle in a mechanical indicating demand device to insure they
are running at the proper speed, where such timing cycle directly affects meter
registration.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 305.03
Test Schedules for Watt-hour Meters and Demand Devices.
(a) A utility
may accept as a first test and record as a test a manufacturer's test on new
meters if the meter is certified by the manufacturer as built to comply with
ANSI C12.1-2008 of the American National Standard Code for Electricity Metering
or ANSI C12.20-2010, available as noted in Appendix B.
(b) A
utility shall test and calibrate all new meters not certified by the
manufacturer as provided in (a) above before placing any such meter into
service.
(c) A
utility shall each year test and, as necessary, repair and recalibrate or
retire all watt-hour meters and demand devices in service on a test schedule as
follows:
(1) All
self-contained single-phase watt-hour meters:
a. On a
periodic basis resulting in each meter being tested at least once every 12 years;
or
b. By
each year selecting, testing and, as necessary, retiring meters under a plan as
follows:
1.
A sample test group, selected at random and representing a cross-section
of the utility's meters, comprised of at least 1% of meters in use but not
fewer than 500 meters; and
2.
An additional number of meters, determined pursuant to (d) below,
selected from those meters which appear to be most adversely affecting meter
accuracy;
(2)
Self-contained polyphase meters, each meter no less than once every 12
years;
(3)
Single-phase transformer-rated meters, each meter no less than once
every 8 years; and
(4)
Polyphase transformer-rated meters, each meter no less than once every 4
years.
(d) Each utility
which tests self-contained single-phase watt-hour meters pursuant to (c)(1)b.
above, shall test and repair and recalibrate or retire each year a minimum
number of meters, pursuant to (c)(1)b.2. above, in addition to sample meter
tests required to be conducted pursuant to (c)(1)b.1. above, according to the
formula as follows:
(1) The
utility shall create a test curve ratio in which:
a.
"X" means the percentage of meters in the cumulative sample
test group which tested outside of the weighted accuracy limits of between 98%
and 102% for mechanical meters and between 98% and 101% for electronic meters;
and
b.
"R" means the percentage of the total number of meters subject
to sample testing which it shall test and repair and recalibrate or retire in addition
to those meters tested pursuant to (c)(1).b.1. above; and
(2) Each
utility shall determine the number of additional meters it shall test pursuant
to this paragraph by calculating “R” as described below and applying this
percentage to the total number of in-service meters subject to sample testing,
as follows:
a. When
"X" is between 0% and 3%, by multiplying 12.5 by "X"
divided by 3, squared, as in the formula below:
R = 12.5 (X/3)2 percent;
b. When
"X" is greater than 3% and less than 6% by subtracting from 25, 12.5
multiplied by 2 minus "X", divided by 3, squared, as in the formula
below:
R = 25 - 12.5(2 - X/3)2 percent;
c. When
"X" is greater than 6%, R shall equal 25%;
d. If X
is 0.0% to 0.5%, the number of the additional meters to be tested shall be
multiplied by 1.0; and
e. If X
is greater than 0.5%, the number of additional meters to be tested shall be
multiplied by 1.0 + ((X – 0.5) /2).
(e) A
utility shall include in the cumulative sample required by (d)(1)a. above:
(1) The
sample test group of the current year; and
(2) To
the extent available, the sample test groups of the immediately preceding 3
years.
(f) In
determining the minimum number of additional meters which it shall be required
to test pursuant to (c) above, a utility shall not include any meter returned
to the shop for maintenance.
(g) A
utility shall notify the commission in writing before changing any meter
testing schedule which the utility has adopted pursuant to this section.
(h) A
utility shall test and recalibrate as necessary all polyphase meters removed
from service before returning the meter to service.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 305.04
Request Tests and Reports and Records of Meter Tests.
(a) When
a customer requests that a utility test the customer's meter, the utility shall
test the accuracy of the customer's meter within 15 calendar days from the time
this request is made.
(b) A
utility may require the deposit of a fee of not more than $20.00 for such a
test and shall, in cases where a customer presents evidence of financial
hardship as defined in Puc 1202.10, either waive the fee or offer the customer the opportunity to enter
into a payment plan for such fee.
(c) A
utility shall conduct any test on a meter requested by the customer with the meter
in its service location.
(d) If,
on testing, as described in (a) above, the meter is found to have an average
error greater than 2%, the utility shall promptly refund the deposit to the
customer.
(e) If the
meter, upon testing as described in (a) above, is not found to have an average
error greater than 2%, the utility may retain the amount deposited for the
test.
(f) A
utility shall allow a customer to be present or to be represented by an agent
who the utility shall permit to be present when the utility conducts the test
on that customer's meter.
(g) The
utility shall report the results of the meter test to the customer within 15
calendar days of the test.
(h) In
the report required by (g) above, the utility shall provide:
(1) The
name of the customer requesting the test;
(2) The
date of the request;
(3) The
location;
(4) The
type, make, and the serial number of the meter;
(5) The
date tested;
(6) The
numeric result of the weighted-average test;
(7) The
numeric range of weighted-average test results permitted by the commission; and
(8) A
statement indicating whether the customer’s test result was within or outside
the range permitted by the commission.
(i) When a
utility has received a request for a meter test, the utility shall not remove
the meter from the customer’s premises or interfere with or adjust the meter to
be tested unless it has first obtained:
(1) The
written consent of the customer; or
(2) A waiver
of the consent requirement pursuant to Puc 201.05.
(j) When
a customer requests that the commission verify the accuracy of the customer's
meter, the commission shall, by a representative, monitor the conducting of a
meter test conducted by the utility.
(k) Each
utility shall submit to the commission reports of periodic and sample tests of
meters on form E-3 and form E-3A once a year pursuant to Puc 308.03 and Puc
308.04.
(l) Each
utility shall submit to the commission quarterly reports containing monthly
data of customer requests for meter tests on form E-4 pursuant to Puc 308.05.
(m) A utility shall retain in its files a
complete record of the last test made on each meter.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 305.05
Customer's Bill Adjustments.
(a) In meter
tests made by the utility pursuant to Puc 305.04, the utility and the
commission shall judge the correctness of registration of the meter and its
performance in service by its average error.
(b) A
utility and the commission shall determine average error for purposes of meter
tests as follows:
(1) If
the meter is used to measure a load which is constant, such as a street
lighting load or a display sign load, the meter shall be tested at the constant
load;
(2) The
error of a meter used to measure a constant load shall be accepted as the
average meter error;
(3) If
the meter is used on a varying load, the average error shall be:
a. The
weighted average of its error at light load with a weighting of 1.0; and
b. The
weighted average of its error at full load with a weighting of 4.0; and
(4) Any
adjustment of charges which is made in accordance with this section shall be
based on the average error as determined by this paragraph.
(c)
Whenever, as the result of a test made by the utility, a watt-hour meter
is found to have an average error greater than 2%, the company shall, except to
the extent provided in (d) below, refund to the customer an amount equal to the
charge for the excess kilowatt-hours billed for a period:
(1) Equal
to 1/2 the time elapsed since the last test; or
(2) The
time when the error first developed or occurred can be definitely fixed, from
that point.
(d) The
calculation for a bill adjustment in (c) above shall not consider any period
during which:
(1) The
customer did not receive service at that location; or
(2) The customer was purposefully diverting
electricity or tampering with the metering installation.
(e)
Whenever, as the result of a test made by the utility, a watt-hour meter
is found to have an average error greater than 2%, the company may bill the
customer for the unbilled kilowatt-hours supplied for the shorter of the
following periods:
(1) The
previous 6 months of active usage; or
(2) The
period since the last test.
(f) When
a customer is charged pursuant to (e) above, the utility shall allow the
customer to request a payment plan, regardless of the customer’s financial
circumstances, such payment plan shall not exceed the period of time over which
the unbilled kilowatt-hours accrued unless agreed to by the utility and the
customer.
(g) If a
meter is either not registering or partially registering the electricity
delivered to the customer, the utility shall base the bill for the period of
non-registration or partial registration upon:
(1) Information recorded by a meter properly
registering usage at that location prior or subsequent to the period of
non-registration or partial registration; and
(2) Any
other pertinent information supplied by the customer or known to the utility.
(h) When
calculating the difference between the billed and estimated amounts resulting
from the non-registration or partial registration, the utility shall not bill
the customer for more than 6 months of partial or non-registration unless the
customer was purposely diverting electricity or tampering with the metering
installation.
(i) The
utility shall provide each customer receiving a refund pursuant to (c) above or
being charged pursuant to (e) above with a clear explanation of how such refund
or charges were calculated.
(j) If a
meter is determined to have been assigned to the wrong customer and a customer
has been billed based on usage recorded on a meter connected to residential or
commercial space not occupied by that customer, the utility shall correct the
billing to affected customers as follows:
(1) For
customers who have been under billed, invoices for the billing difference shall
cover the customer’s period of occupancy or 6 months, whichever is shorter; and
(2) For
customers who have been overbilled, refunds of the billing difference shall
cover the period of occupancy or 24 months, whichever is shorter.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 305.06 Testing Facilities and Equipment,
Watt-Hour Standards.
(a) Every utility shall have available one or
more reference standards for the sole purpose of checking working standards.
(b) Each
utility shall have all reference standards and all working standards certified
at least once each year in a laboratory meeting specifications recommended by
the watt-hour standard manufacturer.
(c) Each
utility shall have each working standard which it maintains accompanied by a
calibration card noting the corrections at various working loads.
(d) Each
utility shall keep on file in its office for 2 years any calibration cards
which have been superseded.
(e) Each
utility shall maintain an adequate number of working standards for testing
customer meters.
(f) Each
utility shall check the mechanical field working standards used in the direct
calibration of customer meters every 3 months to determine whether there has
been a change in the performance of a standard unless the mechanical field
working standard is certified at intervals recommended by the manufacturer not
to exceed one year.
(g) Each
utility shall check the mechanical meter shop working standards used in the
direct calibration of customer meters once a week to determine whether there
has been a change in the performance of the standard, and shall certify the
mechanical meter shop working standard at intervals recommended by the
manufacturer not to exceed one year.
(h) Each
utility shall compare its electronic working standards for testing customer
meters to reference standards at least once every year.
(i) Any working
standard found to be in error by more than 1% shall be removed from service.
(j) A
utility shall certify its watt-hour standards as follows:
(1) In an independent standards laboratory; or
(2) In a laboratory maintained by the utility
provided that the commission accepts the instruments and methods pursuant to
Puc 201.05.
Source. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 305.07
Testing Facilities and Equipment, Portable Indicating Standards.
(a) Every
utility shall have available reference indicating electrical instruments of
suitable range for checking working instruments.
(b) Each
utility shall check reference indicating instruments required by (a) above at
least once each year in an independent standards laboratory.
(c) Each
utility shall not use the reference indicating instruments required by (a)
above in the field as working instruments.
(d) Each
utility shall have calibration cards accompany each instrument required by (a)
above which note the corrections to be applied at the various parts of the
working scale.
(e) Each
utility shall have available the types and quantities of working instruments
necessary to determine compliance with these rules for:
(1)
Recording and indicating customer voltage; and
(2) Testing any other electrical quantities
which may be necessary to comply with the measurement and reporting
requirements of this chapter.
(f) Each
utility shall check the working instruments required by (e) with the reference
instruments at least once each year.
(g) If
reference instruments are not available within the utility, the utility shall
have field instruments checked in an independent standards laboratory meeting
specifications recommended by the meter manufacturer in intervals not to exceed
one year.
(h) A
utility may certify its indicating standards in a standards laboratory which it
maintains provided that the instruments and methods meet specifications
recommended by the meter manufacturer.
(i) Pursuant to RSA 365:6, each utility shall,
upon request, provide the commission access to its meter testing facilities and
any and all meter test results.
Source. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
PART Puc
306 EQUIPMENT AND FACILITIES
Puc 306.01 Standard Practice in Construction,
Operation and Maintenance.
(a) Each
utility shall construct, install, operate and maintain its plant, structures
and equipment and lines, as follows:
(1) In
accordance with good utility practice;
(2) After
weighing all factors, including potential delay, cost and safety issues, in
such a manner to best accommodate the public; and
(3) To prevent
interference with other underground and above ground facilities, including
facilities furnishing communications, gas, water, sewer or steam service.
(b) For
purposes of this section, “good utility practice” means in accordance with the
standards established by:
(1) The
National Electrical Safety Code C2-2012, available as noted in Appendix B;
(2) When
applicable, the International Energy Conservation Code 2009 as adopted pursuant
to RSA 155-A:1,IV; and
(3) The
ISO-NE.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 306.02
Joint Pole Construction.
Each utility involved in any installation which makes use of poles
either for single or joint occupancy shall conform its construction,
installation, operation and maintenance to the requirements of Puc 306.01.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 306.03
Electrical Interference.
(a) Each
utility shall make a full and prompt investigation of complaints made by the
utility's customers or by the general public involving electrical interference
with reception by communications equipment in the proximity of the utility's transmission
and service areas, including but not limited to interference with television
and radio reception.
(b) Each
utility shall maintain a record of complaints which it receives pursuant to (a)
above.
(c) Each
utility shall report to the commission all complaints, as described in (a)
above, that it receives that are not resolved to the satisfaction of the
complaining party within 30 days of receipt or notification of the complaint.
(d) The
report referred to in (c) above shall include the location of the complaint,
the circuit number of the line, and a brief description of the interference.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 306.04
Safety Instructions.
(a) Each
utility, in the operation, construction or maintenance of its plant and
facilities, shall:
(1)
Develop and implement a safety and health program to ensure that its
employees have been:
a.
Properly informed of safety practices and procedures; and
b.
Protected from hazards associated with the work environment;
(2) Adopt
comprehensive written instructions for the safety of its employees; and
(3)
Distribute a copy of the written instructions required by (2) above to
each of its employees before assignment to duty in any assignment which
requires handling any energized electrical plant.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 306.05
Resuscitation.
(a) Each
utility shall periodically instruct all employees engaged in work on electrical
plant in accepted safety procedures for resuscitation from electric shock.
(b) Each utility
shall adopt written safety procedures for resuscitation from electric shock.
(c) Each
utility shall distribute copies of the written safety procedures required by
this section to each employee who works on any energized plant.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc
306.06 Notification of Accidents
and Property Damage.
(a)
A utility shall notify the commission in the event of accidents and
significant events in accordance with subparts (c) – (f), except during wide
scale emergencies as required by this rule.
(b)
The commission shall provide a protocol roster to the utilities updated
as necessary which:
(1) Lists commission representatives with their
after work hours telephone contact numbers, email addresses and text contact
information; and
(2) Lists the general commission telephone
number.
(c) A utility shall notify the commission by
telephone, automated telephone notification or electronic means as soon as
possible, but no later than 2 hours after becoming aware of an outage event
that interrupts service to more than 2,000 customers for more than 5 minutes.
(1) The notification shall include:
a. The name of the utility;
b. The name of the person initiating the
notification and a telephone number for call back;
c. A brief description of the event location;
d. Estimated number of customers affected; and
e. Estimated duration of outage or service
restoration time; and
(2) Notification shall be to all commission
representatives on the protocol roster, described in (b) above through automated
telephone notification, email or text.
(d) A utility shall notify the commission by
telephone as soon as possible, but no later than 2 hours after becoming aware
of an accident or event that:
(1) Results in serious injury or fatality;
(2) Involves a breach of security or threat
against the utility’s facilities addressed in section 306.10;
(3) Involves aircraft, trains or commercial
boats;
(4) Results in closure of a state highway; or
(5) Is not covered in this section but has been
or is anticipated to be reported publicly via major commercial news outlets.
(e) When an accident or event occurs as described
in (d) above, the utility shall notify the commission as follows:
(1) Attempt to contact the appropriate commission
representative listed on the protocol roster, described in (b) above, either at
the commission telephone number during regular commission hours or at the
after-hours number outside of regular commission hours;
(2) Proceed sequentially through the roster attempting
to contact a commission representative;
(3) If a utility is unable to reach a commission
representative after (2) above, the utility shall notify the commission as
follows:
a. Call the commission general telephone
listing, provided in the protocol roster, and leave a voice mail message:
1. Identifying the utility and the name and
return telephone number of the individual attempting to report; and
2. Stating that an accident or event requiring notification
has occurred and will be reported when the commission next opens; and
b. As soon as possible during regular commission
hours, contact the appropriate commission representative listed on the protocol
roster, described in (b) above, and proceed sequentially through the roster;
and
(4) When the utility is first able to speak to a
commission representative listed on the protocol roster as required by this
section, the utility shall notify the representative of the following:
a. The name of the utility;
b. The name of the person making the report and
the telephone number at which they can be called back;
c. A brief description of the accident or event
and location;
d. A description of any known fatalities,
personal injuries and damage;
e. Any other known information relevant to the
cause of the accident or event and the extent of the damage; and
f. The time at which:
1. The accident or event occurred; and
2. The utility was first notified or the
accident or event.
(f) Each utility
shall report in writing any accident or event requiring notification pursuant
to (d) above, by completing and submitting to the commission:
(1) Form E-5E, within 10 business days of
notification of the accident or event; and
(2) If requested by the commission, a more
detailed written report, referencing the original E-5E report number,
containing any additional supportive documentation not provided in the original
E-5E report, within 60 days of notification of the accident or event.
(g) If a utility is
requested to file a report pursuant to Puc 306.02(f)(2) and the accident or
event involves a utility’s pole or anchors located within the public way, the
utility shall include in its report whether the poles or anchors were licensed
and whether the poles or anchors were properly located according to that
license.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 306.07
Commission Inspection. The
commission shall, from time to time, inspect the works and system of each utility
and the manner in which each utility has conformed and presently conforms to
commission rules.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc
306.08 Uniform Utility Damage
Prevention Program. All utilities
shall comply with Puc 800, the underground utility damage prevention program
rules.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 306.09
Emergency Response Standards and Electrical Outage Restoration.
(a) On an
annual basis, each utility shall file with the commission one original and one
electronic copy of an emergency response plan (ERP).
(b) ERPs shall
incorporate the incident command system and follow the framework established in
the National Incident Management System, available as noted in Appendix B.
(c)
Utilities shall review and update plans at least once every calendar
year.
(d) Each ERP shall include a clear description
of the responsibilities and policies of senior management during an emergency.
(e) Each
ERP shall provide that one full readiness exercise and one table top exercise
be conducted annually. The utilities shall invite applicable state agencies and
commission staff to participate in such exercises.
(f) At
least annually, the utility shall request to meet with municipal emergency
response personnel to assure the accuracy of emergency response contact
information is shared between the two parties, and to validate or revise the
municipalities’ critical infrastructure listing.
(g) Each
ERP shall incorporate projected event levels consistent with Table 306-1.
Table 306-1 |
|||
Utility |
ERP Event Level |
% Customers Out |
Outage Duration (Hrs.) |
|
5 |
≤2 |
<12 |
4 |
>2≤5 |
0-24 |
|
3 |
>5 ≤10 |
24-48 |
|
2 |
>10≤20 |
48-144 |
|
1 |
>20 |
48-240 |
Source. #10603, eff 5-21-14
Puc 306.10
Physical and Cyber Security Plans, Procedures and Reporting.
(a) Each
utility shall develop, maintain and follow a written physical security plan
designed to protect the utility’s critical equipment and facilities from
breaches of security. For purposes of
this section, “critical equipment and facilities” means utility infrastructure
without which the utility could not provide safe and reliable service to its
customers.
(b) The
plan shall be risk-based and incorporate:
(1) A threat level assessment;
(2) A list of critical equipment and facilities
to which the plan applies;
(3) Defined security measures for critical
equipment and facilities;
(4) Response procedures and notifications upon
discovery of a breach in security;
(5) Defined process to track events; and
(6) Employee awareness training programs.
(c) Each utility shall develop, maintain and
follow a written information cyber security plan designed to protect the
utility’s critical cyber assets. For
purposes of this section, “critical cyber assets” means those electronic data,
communications, and computer network systems without which the utility could
not provide safe reliable service to its customers.
(d) The plan shall be risk-based and incorporate:
(1) A threat level assessment;
(2) A list of critical cyber assets;
(3) Defined security measures for critical cyber
assets;
(4) Response procedures and notifications upon
discovery of a breach in security;
(5) Defined process to track events; and
(6) Employee awareness training programs.
(e) Each utility shall submit to the commission
annually one original and one electronic copy of each of its physical security
plan and cyber security plan. If any
such plan contains confidential information, the utility shall so notify the
commission in writing to provide the commission with an opportunity to review
the confidential information at the utility’s offices in
(f) On
the 15th day of the month following the last day of each quarter, each utility
shall file Form E-37 Quarterly Report of Equipment Theft, Sabotage and Breaches
of Security, pursuant to Puc 308.17 reporting all material breaches of security
as defined within the plans.
Source. #10603, eff 5-21-14
PART Puc 307
RECORDS AND REPORTS
Puc 307.01
Records.
(a) Each utility shall keep records of the
operation and performance of its generating units and distribution circuits.
(b)
Unless complete information as required by the ISO-NE is furnished by
the utility transmitting the energy at each interconnection point, each utility
receiving electric energy shall maintain adequate instruments and meters to
obtain such complete information as to each delivery.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 307.02 Preservation of Records.
(a) Each
utility shall preserve all records pursuant to the requirements set forth in
the "Uniform System of Accounts Prescribed for Public Utilities and
Licensees Subject to Provisions of the Federal Power Act", as referred to
in Puc 307.04 and adopted by the commission pursuant to RSA 374:8.
(b) If
the "Uniform System of Accounts Prescribed for Public Utilities and
Licensees Subject to Provisions of the Federal Power Act" does not specify
a requirement for preservation of a record required to be kept pursuant to Puc
300, the utility shall preserve any such record for a period of not less than 2
years.
(c) If
any section of this chapter requires a utility to preserve certain records for
more than 2 years, utilities shall comply with the terms of this chapter.
(d) A
utility shall:
(1) Keep
or make available such records within
(2) Provide access to such records to the commission
or its representative during normal business hours for examination.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 307.03
Reports to Commission.
(a) Each
utility shall file periodic reports with the commission as required by Puc 308
on forms available on the commission website at www. www.puc.nh.gov. The utility shall file one paper original and
an electronic copy with the commission except that a utility shall not be
required to file a paper copy of reports identified in Puc 308.14 – 308.16.
(b)
Pursuant to Puc 202.05(b), each utility shall electronically file each
report, to the extent technologically feasible, in a format compatible with the
computer system of the commission.
(c) The
commission shall notify utilities no less frequently than on an annual basis of
the types of electronic formats compatible with its computer system by posting
the list of such formats on its website.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 307.04
Uniform System of Accounts.
Pursuant to RSA 374:8, each utility shall maintain and preserve its
accounts and records in conformity with the "Uniform System of Accounts
Prescribed for Public Utilities and Licensees Subject to Provisions of the
Federal Power Act" issued by the United States Federal Energy Regulatory
Commission, Department of Energy.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8443, eff
10-18-05; ss by #10603, eff 5-21-14
REVISION NOTE:
Pursuant to RSA 374:8,
II and RSA 541-A:21, I(q), as amended effective 7-23-94 by 1994, 193:3 and
193:4, the uniform system of accounts (USOA) for regulated utilities as
referenced in Puc 307.04 is exempt from the rulemaking requirements of RSA
541-A. The text of the USOA is not
included in Puc 307.04 above because the publication requirement for rules in
RSA 541-A:15, I does not apply.
By Order No. 21,310
dated August 8, 1994, the New Hampshire Public Utilities Commission (Commission)
ordered, because of 1994, 193, that the USOAs, including the USOA for electric
utilities, "shall remain in effect until such time as the Commission shall
prescribe, amend, rescind or otherwise affect the USOAs currently prescribed
for regulated utilities".
The Commission must
still file in the Office of Legislative Services a copy of all USOA rules
adopted, amended or repealed under RSA 374:8.
The text of the USOA for electric utilities subject to Order No. 21,310
was last filed in Document #6621.
A copy of the USOA as
referenced in Puc 307.04 may be obtained at the:
Puc 307.05
Short Term Debt. No
utility shall issue or renew any notes, bonds or other evidences of
indebtedness payable less than 12 months after the date thereof if such short
term debt exceeds 10% of the utility’s net fixed plant without prior commission
approval pursuant to Puc 201.05.
Source. #6605, eff 10-21-97 (formerly Puc 312); ss by
#8448, eff 10-18-05; ss by #10603, eff 5-21-14
Puc 307.06
Interconnection Agreements.
(a) "Interconnection agreement" means
an agreement that sets forth the contractual terms necessary for any person or entity
that generates electricity to connect to the utility's system.
(b) Each
utility shall file with the commission a copy of each interconnection agreement
entered into by the utility.
Source. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 307.07
Reliability Reporting.
(a) When
quarterly circuit or system reliability indices are furnished to the
commission, the utility shall include the total number of operations by device
which resulted in an interruption of greater than 5 minutes duration and the
information required by (c) below.
(b) For
purposes of this section, “device” means any equipment designed and used to
automatically operate to remove faulted system elements from the system.
(c) Any
utility submitting quarterly circuit or system reliability indices shall also
report:
(1) The
year and calendar quarter of the report;
(2) The
circuit number;
(3) The
device identification number;
(4) The type of device operated;
(5) The
number of actual operations of the device in the current reporting quarter, if
2 or more; and
(6) The
number of actual device operations in the current and previous 3 quarters, if 3
or more.
(d) A
utility calculating the number of device operations pursuant to (c) (5) and (6)
above shall exclude:
(1)
Operations of devices upstream of the device being reported; and
(2)
Device identification changes due to circuit reconfigurations.
(e)
Utilities shall not be required to report the information as required in
(a) above for service interruptions that result from major storms.
Source. #8448, eff 10-18-05; ss by #10603, eff
5-21-14
Puc 307.08 Reporting during Wide Scale Emergencies.
(a) Distribution crew reports shall be submitted
electronically 4 times per day at 6 am, 10 am, 2 pm and 8 pm using Form E-33
pursuant to Puc 308.15.
(b) Transmission crew reports shall be submitted
electronically 4 times per day at 6 am, 10 am, 2 pm and 8 pm using Form E-34 pursuant
to Puc 308.16.
(c) In the event
that commission staff anticipates the occurrence of a wide-scale emergency,
staff shall notify the utilities and the utilities shall file crew reports
prior to the onset of the wide-scale emergency.
Event names shall be determined by the commission and made known to each
of the utilities required to report.
(d) Crew reporting
shall consist of only those crews which are physically located within the state
boundaries regardless of what their work status is such as sleeping, resting,
eating, restoration of circuits and shall reflect the crews which are available
for restoration at the time of the report.
(e) Crew reporting
shall be completed for front line, field assessment and public safety functions
and as described in Forms E-33 and E-34.
(f) Electric utility
outage reports shall be submitted to the commission using applicable Forms
E-36a, E-36b, and E-36c any time outage information is not publicly available
on utility websites during wide scale emergencies pursuant to Puc 308.17.
(g) Electric utility
outage reports as described in (f) above shall be submitted at the same times
as required in (a) and (b) above or upon request of commission.
Source. #10603, eff 5-21-14
Puc 307.09
Reporting of Reliability Measures.
(a) For
purposes of this section, the following definitions shall apply:
(1)
“Customer average interruption duration index (CAIDI)” means the average
interruption duration or average time to restore service per interrupted
customer and shall be presented as the following ratio: Total sum of customer
interruption durations/total number of customer interruptions;
(2)
“System average interruption frequency index (SAIFI)” means the average
number of interruptions per customer
and shall be presented in the following ratio: Total number of customer
interruptions/average number of customers served;
(3)
”System average interruption duration index (SAIDI)” means the average
duration of customer interruptions and shall be presented as the following
calculation; SAIDI = CAIDI x SAIFI; and
(4)
“CIII” means the average number of customers without power per
interruption index as determined by dividing the number of customers
interrupted by the number of interruptions.
(5)
“TMED” means the threshold value used to determine a major event day as
defined in IEEE Guide for Electric Power Distribution Reliability Indices
1366-2012, Section 1.5, available as noted in Appendix B.
(6)
“Major event day” means a day during which a utility’s daily system
SAIDI exceeds the TMED.
(a)
Within 45 days of the end of each calendar quarter, each utility shall
file quarterly reports of reliability measures defined in (a) (1) – (4) above,
and shall separately report the reliability measures by area work center and as
aggregated for the whole company.
(c)
E ach utility shall report the indices separately:
(1) With
all interruptions included in the data; and
(2) With
major event days excluded from the data.
(d)
The report shall depict the reliability measure information by
distribution and transmission systems as applicable.
Source. #10603, eff 5-21-14
Puc 307.10 Tree-Pruning Standards.
(a) With the land-owner’s consent, utilities
shall prune trees adjacent to all distribution circuits to the following
minimum clearances on no more than a 5 year cycle:
(1) 10 feet below the conductors;
(2) 8 feet to the side of the nearest conductor;
and
(3) 15 feet above the conductors, at time of
pruning.
(b) Utilities shall implement measures such as
mid-cycle reviews to identify and mitigate elevated risk from
tree exposure on circuits or sections of circuits that are significantly and/or
continually experiencing tree-related interruptions, where it is practical to
do so.
(c) Utilities shall not be required to prune to
the clearance standards specified in (a) of this section where:
(1) The land-owner has refused or restricted
permission to prune;
(2) A municipality or other local governing body,
by ordinance or other official means, has refused or restricted permission to
prune; or
(3) Pruning to the standards specified in subpart
(a) would be detrimental to the health of the tree, in which the utility shall
adhere to the guidelines provided in ANSI A300 Part 1– 2008 Edition, available
as noted in Appendix B.
Source. #10603, eff 5-21-14
PART Puc 308
FORMS REQUIRED BY ALL UTILITIES
Puc
308.01 E-1 Monthly Report on Voltage
Complaints. Each utility shall on a
monthly basis complete a report of voltage complaints on Form E-1 dated 8/2013
and available at the commission website at www.puc.nh.gov, and file one signed
original and one electronic copy with the commission.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc
308.02 E-2 Quarterly Report on
Interruptions of Service Over 5 Minutes Duration. Each utility shall on a quarterly basis complete
a report of service interruptions of more than 5 minutes on the Form E-2 dated
8/2013 and available at the commission website at www.puc.nh.gov, and file one signed
original and one electronic copy with the commission.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 308.03
E-3 Annual Report of Total Electric Meter Tests. Each utility shall on an annual basis
complete a report of total electric meter tests on Form E-3 dated 10/2013 and
available at the commission website at www.puc.nh.gov, and file one signed
original and one electronic copy with the commission.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 308.04
E-3A Report on Selective Sample Tests of Weighted Average Accuracy on
Self-Contained Single-Phase Meters and Network Meters. Each utility shall on an annual basis
complete a report on selected sample tests of weighted average accuracy on
self-contained single-phase meters and network meters on Form E-3A dated 9/2013
and available at the commission website at www.puc.nh.gov, and file one signed
original and one electronic copy with the commission.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8443, eff
10-18-05; ss by #10603, eff 5-21-14
Puc
308.05 E-4 Monthly Report on Electric
Meter Complaint Tests. Each utility shall
on a monthly basis complete a report of electric meter complaint tests on Form
E-4 dated 8/2013 and available at the commission website at www.puc.nh.gov, and file one signed
original and one electronic copy with the commission.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 308.06 E-5E
Accident Reports. Each
utility shall report any accident or event to the commission by completing an
accident report on Form E-5E dated 8/2013 and available at the commission’s
website at www.puc.nh.gov, and file one signed
original and one electronic copy with the commission.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 308.07
E-22E Report of Proposed Distribution Expenditures for Additions,
Extensions and Capital Improvements to Fixed Capital and Operation and
Maintenance (O&M) Expenses.
(a) When
the probable costs of any addition, extension or capital improvement to its
distribution utility plant or O&M distribution account will equal or exceed
$100,000, a utility shall complete a report on Form E-22E dated 8/2013 and
available at the commission website at www.puc.nh.gov, and file one signed
original and one electronic copy with the commission.
(b) The
commission shall accept construction and O&M budgets if the budgets:
(1) Include highlights of all projects or O&M
distribution accounts in excess of $100,000;
(2) Contain a level of detail sufficient to allow
the commission to assess and understand all costs involved with the proposed
project or O&M distribution accounts; and
(3) Cover a period of no longer than one year.
(c) A utility shall file an original and
duplicate copy with the commission as follows:
(1) An individual form E-22E no fewer than 30
calendar days before starting actual construction or expenditure of funds; or
(2) A construction budget and an O&M budget
no later than 60 calendar days following the end of its fiscal year.
(d) Each utility shall include on form E-22E the
following:
(1) A caption identifying the form;
(2) The name of the utility filing the report;
(3) The full name and title of the utility
employee who supervised the preparation of the report;
(4) The signature of the person identified in (3)
above; and
(5) The information described in (a) and (b)
above.
(e) A utility may provide an additional copy of
its filing and request that it be date-stamped and returned by the commission
to confirm the filing.
(f) If a project highlighted in (b)(1) above is
cancelled or postponed beyond the construction budget year, the utility shall
immediately file form E-22E at the time it becomes apparent that the project
will be cancelled or postponed.
(g) Except for projects highlighted in accordance
with (b)(1) above, if the cost of a project is anticipated to fall below
$100,000 but later exceeds it, the utility shall immediately file form E-22E at
the time or phase of the project it becomes apparent the limit will be
exceeded.
(h) If a change in any O&M distribution
account exceeds the approved expenditure levels by more than $100,000, the
utility shall immediately file form E-22E at the time the change becomes
apparent to the utility.
(i) If a project not included in an approved
construction budget arises which will equal or exceed $100,000, the utility
shall file form E-22E.
(j) A utility shall also file an electronic copy
of the report pursuant to Puc 307.03.
(k) Investigation
or comment on a construction budget, an O&M budget or other Form E-22E
content by the commission or failure of the staff to identify prudence review
issues shall not constitute a final prudence review and the commission shall
not be precluded from analyzing the merits of any expenditure in a future rate
case pursuant to the commission’s authority under RSA 378.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 308.08
E-25E Report of Proposed Changes in Depreciation Rates.
(a) When
it proposes any change in depreciation rates, a utility shall compete Form
E-25E dated 8/2013 and available at the commission website at www.puc.nh.gov, and file one signed
original and one electronic copy with the commission.
(b) A
utility shall not implement any change in depreciation rates until the proposed
change has been approved by the commission pursuant to a proceeding conducted
according to Puc 200.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 308.09
Quarterly Financial Report, FERC Form 3-Q.
(a) Each
utility shall file with the commission, at the same time it files such report
with the Federal Energy Regulatory Commission (FERC), one signed original and
one electronic copy of its completed FERC form 3-Q “Quarterly Financial Report
of Electric Utilities, Licensees, and Natural Gas Companies” as described in 18
C.F.R. § 141.400.
(b) The
quarterly report in (a) above shall be required for the calendar quarters
ending March
31,
June 30 and September 30 of each year.
(c)
Consistent with FERC reporting requirements, the quarterly report in (a)
above shall not be
required
for the calendar quarter ended December 31 of each year as such report is
supplanted by the annual report required pursuant to Puc 308.10.
(d) Each
utility shall, at the time it files the quarterly report required by (a) above,
file a copy of the
quarterly
report with the
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 308.10
Annual Report, FERC Form No. 1.
(a) Each utility shall file with the commission one
signed original and one electronic copy
of its completed FERC form No. 1 "Annual Report of Major Electric
Utilities, Licensees and Others," as described in 18 C.F. R. § 141.1, at
the same time it files such report with the FERC.
(b) Each utility shall, at the time it files the
annual report required by (a) above, file a copy of the annual report with the
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-97, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 308.11 F-1 Supplemental Quarterly Financial and
Sales Information.
(a) In addition to the reports required in Puc
308.09 and Puc 308.10, each utility shall, for each calendar quarter,
simultaneously file the following supplemental information with the commission:
(1) Schedule 1 - “Calculation of Per Books Rate
of Return”;
(2) Schedule 2 - “Current Cost of Capital”; and
(3) Schedule 3 - “Sales by Customer Class”.
(b) Schedule 1 – “Calculation of Per Books Rate
of Return” shall include:
(1) Operating revenues for 12 months;
(2) Operating expenses for 12 months, including:
a. Production expenses;
b. Distribution expenses;
c. Transmission expenses;
d. Customer accounting;
e. General and administrative;
f. Depreciation;
g. Amortization;
h. Federal and state income taxes;
i. Property taxes; and
j. Other taxes; and
(3) Rate base components, computed using a
13-month or 5-quarter average, for:
a. Utility plant in service;
b. Accumulated depreciation;
c. Material and supplies;
d. Cash working capital requirement;
e. Prepayments;
f. Customer deposits;
g. Customer advances; and
h. Any other item properly includible in the
utility’s rate base.
(c) Schedule 1 - “Calculation of Per Books Rate
of Return” shall, in addition to having a company total column, have separate
columns to report the amounts of each of the items in (b) above attributable to
the distribution, transmission and generation segments of the utility’s
operations, respectively.
(d) Schedule 2 - “Current Cost of Capital” shall
include weighted cost of capital components for:
(1) Common stock equity;
(2) Preferred stock;
(3) Long term debt; and
(4) Short term debt.
(e) In computing the weighted cost of capital in
(d) above, the utility shall include the source of the information and calculations
or an explanation supporting its determination of:
(1) The return on common equity;
(2) The cost of preferred stock;
(3) The embedded cost of long term debt, by
issue; and
(4) The cost rate applicable to short term debt.
(f) The utility shall include supporting
calculations and documentation for any of the items required by (b) through (e)
above that are not directly traceable to the quarterly and annual reports
required by Puc 308.09 and Puc 308.10.
(g) Schedule 3 - “Sales by Customer Class” shall
include:
(1) A
breakdown of total revenue, including revenue associated with distribution
service, transmission service, stranded cost recovery, transition service,
default service, and any other item which a utility bills that it classifies as
revenue for financial reporting purposes, earned by class of customer, as
follows:
a. Residential;
b. Small commercial and industrial;
c. Large commercial and industrial;
d.
e. Other sales to public authorities; and
f. Sales for resale;
(2) A breakdown of kilowatt-hours delivered by
class of customer listed in (1) above;
(3) The average number of customers for each of the
classes listed in (1) above for the current quarter and the same quarter of the
prior year; and
(4) For (1)b. and (1)c. above, the definition
used for customer classes and threshold demand.
(h) A utility shall provide figures on each of
the items in (g)(1) and (g)(2) above for the following:
(1)
Totals for the current quarter;
(2)
Cumulative for the current year;
(3)
Totals for the same quarter of the prior year; and
(4)
Cumulative for the prior year.
(i) Each utility shall, at the time it files the
supplemental quarterly information required by (a) above, file a copy of the
supplemental quarterly report with the
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-96, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 308.12 F-4
Authority to Issue Securities.
(a) When a utility seeks authority to issue
securities, a utility shall complete a file Form F-4 dated 9/2012 and available
at the commission’s website at www.puc.nh.gov, and file one signed
original and one electronic copy with the commission.
(b) Each utility shall file with Form F-4:
(1) An application for leave to issue securities
pursuant to RSA 369:3 including a statement in reasonable detail of the purpose
of the security, any proposed additions, construction or working capital
requirements together with, if applicable, any proposed construction budget;
(2) "Estimated Cost of Financing"
showing entries for all items which contribute to the estimated cost of
financing including, but not limited to, legal costs, printing, documentary
tax, trustee services, financial services;
(3) "Balance Sheet" showing the current
balance sheet adjusted for financing with amounts for actual, adjustments and
as adjusted;
(4) "Income Statement" showing current income
statement adjusted for financing including new interest, depreciation and taxes
with amounts for actual, adjustments and as adjusted;
(5) "Source and Application of Funds and
Capitalization" showing a statement of capitalization ratios after giving
effect to the proposed financing, including 3 years of history and 3 years of
forecast data;
(6) Resolution of the petitioner's stockholders,
board of directors, partners or other governing body of petitioner, as
appropriate, authorizing the proposed financing;
(7) Copy of the private placement memorandum for
long term financing including any letter of commitment from a lender stating
details of financing;
(8) Copy of the proposed promissory note and
mortgage;
(9) Copy of terms of new common or preferred
stock;
(10) An original and 5 copies of the petition and
exhibits; and
(11) The full name, title and signature of the
utility employee who supervised the preparation of the report.
(c) By submitting or signing a form F-4 petition,
the persons submitting the form shall agree to comply with the certification
requirement as set forth in (e) below.
(d) Each utility shall provide in connection with
a petition for authority to issue securities a signed certification which shall
provide as follows:
"The petitioner
utility company believes and, therefore, alleges that the securities to be
issued will be consistent with the public good and that it is entitled to issue
said securities under RSA 369 for the purposes set forth in its petition."
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-96, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 308.13 F-22
Information Sheet.
(a) Each utility shall file form F-22 (dated
8/2013) with the commission:
(1) Annually; and
(2) Whenever any changes occur to the information
included in the form F-22 filing.
(b) Each utility shall include on form F-22:
(1) A
caption identifying the report;
(2) Name of utility filing the report;
(3) Person's name and address to receive annual
report form;
(4) Person's name and address to receive the utility
assessment fee notice;
(5) The names and titles of the principal
officers of the company; and
(6) The full name, title and signature of the
employee who supervised the preparation of the report and the date the report
was signed.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-96, EXPIRED: 3-27-97
New. #6605, eff 10-21-97; ss by #8448, eff
10-18-05; ss by #10603, eff 5-21-14
Puc 308.14 E-33 Distribution Crew Reports during Wide
Scale Emergencies. During wide scale
emergencies, a utility shall prepare and shall file Form E-33 dated 8/2013 and
available at the commission’s website at www.puc.nh.gov, and file one
electronic copy with the commission.
Source. #10603, eff 5-21-14
Puc 308.15 E-34 Transmission Crew Reports during Wide
Scale Emergencies. During wide scale
emergencies, a utility shall prepare and shall file Form E-34 dated 8/2013 and available
at the commission’s website at www.puc.nh.gov, and file one
electronic copy with the commission.
Source. #10603, eff 5-21-14
Puc 308.16 E-36A,
E-36B and E-36C Electric
Utility Outage Reports during Wide Scale Emergencies. During wide scale emergencies, each utility
shall prepare and shall file the applicable form E-36 dated 8/2013 and
available at the commission’s website at www.puc.nh.gov, and file one
electronic copy with the commission as follows:
(a) E-36A - Granite State Electric Company d/b/a/
(b) E-36B - Public Service of
(c) E-36C - Unitil Energy Systems, Inc.
Source. #10603, eff 5-21-14
Puc 308.17 Quarterly Report of Equipment Theft,
Sabotage and Breaches of Security.
Each utility shall on a quarterly basis complete a report of equipment
theft, sabotage and breaches of security on Form E-37 dated 1/2015 and
available at the commission website at www.puc.nh.gov, and file one signed
original and one electronic copy with the commission.
Source. #10603, eff 5-21-14
Puc 308.18 Quarterly Reporting of Electric Utility Reliability
Measures. Each utility shall on a
quarterly basis complete a report of electric utility reliability measures on
Form E-38 dated 12/2013 and available at the commission website at www.puc.nh.gov, and file one signed
original and one electronic copy with the commission.
Source. #10603, eff 5-21-14
PART
Puc 309 RESERVED
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-96, EXPIRED: 3-27-97
New. #6592, eff 9-30-97 (from Puc 310); ss by
#8448, eff 10-18-05; rsvd by #10603, eff 5-21-14
PART Puc 310
RULES RELATIVE TO UTILITY ADVERTISING
Puc 310.01
Definitions.
(a)
"Advertising" means the use by a utility of any media in order
to transmit a message to the general public, or to such utility's consumers.
(b)
"Controversial issue of public importance" means a case or
controversy in which a utility is involved before a court, legislative body, or
government agency, including the commission.
(c)
"Institutional activity" means any act or practice conducted
for the purpose of promoting the corporate image or goodwill of a particular
utility or the utility industry in general.
(d)
"Institutional advertising" means any advertising conducted
for the purpose of promoting the corporate image or goodwill of a particular
utility or the utility industry in general.
(e)
"Least cost integrated resource plan (LCIP)” means, in the case of an electric utility,
those standards set forth in RSA 378:38 and a planning and selection process
for new energy resources that evaluates the full range of alternatives,
including new generating capacity, power purchases, energy conservation and efficiency,
cogeneration and district heating and cooling applications, and renewable
energy resources, in order to provide adequate and reliable service to its
customers at the lowest system cost.
(f)
"Political activity" means any act or practice conducted for
the purpose of influencing public opinion with respect to legislative,
administrative or electoral matters or with respect to any controversial issue
of public importance.
(g)
"Political advertising" means any advertising conducted for
the purpose of influencing public opinion with respect to legislative,
administrative, or electoral matters, or with respect to any controversial
issue of public importance.
(h)
"Promotional activity" means any act or practice conducted for
the purpose of encouraging any person to select or use a service or increase
usage of the service of a utility, to select, purchase, install or use any
appliance or equipment designed to use such utility's service, or to use any
other particular service of the utility.
(i)
"Promotional advertising" means any advertising conducted for
the purpose of encouraging any person to select or use a service or increase
usage of the service of a utility, to select, purchase, install, or use any
appliance or equipment designed to use such utility's service or to use any
other particular service of the utility.
Source. #2011, eff 5-4-82; ss by #2912, eff 11-26-84;
ss by #4999, eff 11-26-90; ss by #6381, INTERIM, eff 11-27-96, EXPIRED: 3-27-97
New. #6605, eff 10-21-97 (formerly Puc 311); ss by
#8448, eff 10-18-05; ss by #10603, eff 5-21-14
Puc 310.02
Recovery of Certain Expenses Prohibited. No utility shall recover, in any manner, from
any person other than the shareholders or other owners of such utility any
direct or indirect expenditure by such utility for promotional, political or
institutional advertising, or promotional, political or institutional
activities except as provided for in Puc 310.03.
Source. #6605, eff 10-21-97 (formerly Puc 311); ss by
#8448, eff 10-18-05; ss by #10603, eff 5-21-14
Puc 310.03
Expenditures Subject to Recovery by A Utility.
(a) For
the purpose of this part, the terms political advertising, promotional advertising,
institutional advertising, political activity, promotional activity, and
institutional activity shall not include advertising or activities which:
(1) Inform electric consumers of or provide
electric consumers with information or materials intended to result in energy
conservation;
(2) Are
required by law, federal regulation or state rule, including advertising
required under part 1 of Title II of the National Energy Conservation Policy
Act;
(3)
Inform electric customers how they can improve efficiency in utilizing
the utility's service;
(4)
Involve or relate to service interruptions, safety measures or emergency
conditions;
(5)
Concern employment opportunities with such utility;
(6)
Provide any explanation of existing or proposed rate schedules or
notifications of hearings thereon;
(7) Are
consistent with the utility's approved least cost integrated resource plan; or
(8)
Inform customers of the availability and sources of financial
assistance.
Source. #6605, eff 10-21-97 (formerly Puc 311); ss by
#10603, eff 5-21-14
Puc
310.04 Prudence Review of Expenses. This part shall not restrict or limit the
commission's power to disallow any expense as a charge to ratepayers which the commission
finds to be unjust, unreasonable, excessive, unwarranted or imprudent pursuant
to RSA 378: 5 and RSA 378:7.
Source. #6605, eff 10-21-97 (formerly Puc 311); ss by
#8448, eff 10-18-05; ss by #10603, eff 5-21-14
Puc 310.05
Reports Required. Each
utility shall keep copies of all its advertising on file for inspection by the
commission.
Source. #6605, eff 10-21-97 (formerly Puc 311); ss by
#8448, eff 10-18-05; ss by #10603, eff 5-21-14
Puc 310.06
Accounting.
(a) If a
utility combines an expense prohibited from recovery with an expense eligible
for recovery, and ancillary costs are associated with the combined expense, the
utility shall allocate a portion of the ancillary cost to the expense
prohibited from recovery and shall be prohibited from recovering costs
ancillary to the prohibited expense.
(b) Each
utility shall keep a record with respect to any advertising or activity,
incurred directly or indirectly, prohibited from recovery pursuant to Puc
310.02, of:
(1) Any
expenditure incurred; and
(2) Any
allocation methodology.
Source. #6605, eff 10-21-97 (formerly Puc 311); ss by
#8448, eff 10-18-05; ss by #10603, eff 5-21-14
PART Puc 311
TRANSFER OF SERVICE BY UTILITY OF CUSTOMERS RETURNING TO UTILITY ENERGY
SUPPLY.
Puc 311.01
Requirements.
(a)
Utilities shall submit a change on behalf of a customer from the
customer's selection of a CEPS to the utility’s default energy service upon the
request of a customer or indirectly by a competitive energy supplier on behalf
of the customer.
(b) A
customer may request the change of supply service described in (a) above
verbally or in writing.
(c) Each
utility shall maintain records of verification of customer authorization for a
minimum period of 2 years after obtaining the verification.
(d) All
requests to change supply service to the utility’s default energy service shall
be initiated by the customer.
(e)
Verification of verbal authorization shall be documented via the utility
recording of the conversation between the call center representative and the
customer.
(f)
Verification of written authorization shall be documented by a letter,
e-mail or other form of written communication from the customer to the utility.
(g) A
utility shall provide the commission with proof of valid customer authorization
whenever requested by the commission in connection with the investigation of a
customer complaint.
(h) A utility
who fails to obtain customer authorization in accordance with this section and
initiates a customer change in service to the utility shall:
(1) Be
liable for all charges billed to the customer as a result of the change in
service;
(2) Be
liable for all charges for electricity it billed to the customer; and
(3) Be
subject to the penalty and other enforcement provisions pursuant to RSA
374:28-a.
Source. #10603, eff 5-21-14
Puc 311.02 Obligations. When a utility is notified by ISO-NE that it
must assume the load obligation of a CEPS, customer authorization to transfer
service pursuant to 311.01 shall not be required.
Source. #10603, eff 5-21-14
APPENDIX A
Rule |
Statute |
|
|
Puc 301.01-301.02 |
RSA 365:8, XII;
362:2,II |
Puc 302.01-302.23 |
RSA 365:8, XII |
Puc 303.01 |
RSA 374:15 |
Puc 303.02 |
RSA 365:8, XII |
Puc 303.03 |
RSA 365:8, XII; 370:1 |
Puc 303.04 |
RSA 365:8, XII, 374:1,
374-F:3,I |
Puc 304.01-304.04 |
RSA 365:8, XII; 374:1,
374-F:3,I |
Puc 305.01-305.07 |
RSA 365:8, XII;
370:1-9, 374:1, 374-F:3,I |
Puc 306.01-306.05 |
RSA 365:8, XII |
Puc 306.06 |
RSA 365:8, XII; 365:6;
374:39 |
Puc 306.07 |
RSA 365:8, XII; 374:49 |
Puc 306.08 |
RSA 365:8, XII, 374:1,
374-F:3,I |
Puc 306.09 |
RSA 365:8,XII, 374:50 |
Puc 307.01-307.04 |
RSA 365:8, XII; 374:8 |
Puc 307.05-307.10 |
RSA 365:8, XII |
Puc 308.01-308.13 |
RSA 365:8, XII; 374:15 |
Puc 308.03 |
RSA 365:8, XII,RSA
370:1-9 |
Puc 308.06 |
RSA 365:8, XII, RSA
374:39 |
Puc 308.07 |
RSA 365:8, XII,RSA
374:5 |
Puc 308.14 |
RSA 365:8,XII, 374:4 |
Puc 308.15-308.18 |
RSA 365:8,XII, 374:1,
374-F:3,I |
Puc 310.01-310.06 |
RSA 365:8, XII |
Puc 311.01-311.02 |
RSA 365:8, XII, 374:28-a |
APPENDIX
B: INCORPORATION BY REFERENCE INFORMATION
RULE |
TITLE(DATE) |
SOURCE |
Puc 302.18 Puc 306.01(b)(1) Puc 307.09(a)(5) |
EEE Standard
141-1993. This standard was
promulgated in 1993. IEEE Standard
National Electric Safety Code C2-2012 IEEE Standard
1366-2012 |
Institute of
Electrical and Electronic Hard copy can be
purchased for $199 and downloaded for $174 at: Hard copy and
electronic copy can be purchased for $175 at: Hard copy can be
purchased for $111 and downloaded for $91 at: |
Puc 304.02(h) Puc 305.02(d) Puc 305.02(f)(4) Puc 305.03(a) Puc 305.03(a) Puc 307.10(b)(3) |
ANSI C84.1-2011 Electrical
Power Systems and Equipment-Voltage Ratings (60Hz) ANSI C12.1-2008
American National Standard for Electric Meters Code of Electricity Metering ANSI C12.20-2010
American National Standard for Electric Meters Code for Electricity Metering ANSI A300 Parts 1 Tree
Care Operations – Tree, Shrub and Other Woody Plant Maintenance – Standard
Practices (2008) |
American National
Standards Institute Hard copy and electronic
copy can be purchased for $79 at: www.global.ins.com\ANSI-Standards Hard copy and
electronic copy can be purchased for $171 at: www.global.ins.com\ANSI-Standards Hard copy and
electronic copy can be purchased for $80 at: www.global.ins.com\ANSI-Standards Hard copy and
electronic copy can be purchased for $79 at: |
Puc 306.09(b) |
National Incident
Management System NIMS Document (2008) |
Federal Emergency Management Agency Can be obtained at no cost at: |