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 New Hampshire public utilities commission.

 

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 New England’s bulk power system or any successor system as named by the Federal Energy Regulatory Commission (FERC).

 

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 Institute of Electrical and Electronic Engineers (IEEE), standard 141-1993, section 8.2.1, available as noted in Appendix B.

 

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 Reading.

 

(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 New Hampshire.

 

(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 New Hampshire at the office or offices of the utility; and

 

(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:

 

New Hampshire Public Utilities Commission

21 South Fruit Street

Concord, New Hampshire 03301

 

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 New Hampshire office of the consumer advocate.

 

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 New Hampshire office of the consumer advocate.

 

 

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.  Public street and highway lighting;

 

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 New Hampshire office of the consumer advocate.

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/ Liberty;

 

(b)  E-36B - Public Service of New Hampshire; and

 

(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 Engineers Operation Center

445 Hoes Lane

Piscataway, NJ  08854-4141

 

Hard copy can be purchased for $199 and downloaded for $174 at:

www.standards.ieee.org

 

Hard copy and electronic copy can be purchased for $175 at:

www.standards.ieee.org

 

 

 

Hard copy can be purchased for $111 and downloaded for $91 at:

www.standards.ieee.org

 

 

 

 

 

 

 

 

 

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

25 West 43rd Street, 4th Floor

New York, NY  10036

 

 

 

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:

www.global.ins.com\ANSI-Standards

 

 

 

 

 

 

 

Puc 306.09(b)

 

 

 

 

 

 

 

National Incident Management System NIMS Document (2008)

Federal Emergency Management Agency

U.S. Dept. of Homeland Security

500 C Street SW

Washington, DC 20472

 

Can be obtained at no cost at:

http://www.fema.gov/national-incident-management-system