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2014-09-05
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Big Bend Electric
Cooperative
Service and Meter
Requirements
Effective February 2013
PO Box 348
Ritzville, WA 99169
(509) 659 – 1700
(866) 844 – 2363
FAX (509) 659 – 1404
www.bbec.org Services >> Service Requests >> Meter Requirements
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page i
BIG BEND ELECTRIC COOPERATIVE RESERVES THE RIGHT TO REFUSE SERVICE TO ANYONE
NOT FOLLOWING THESE SPECIFICATIONS AS SET FORTH.
Big Bend Electric Cooperative, Inc. of Ritzville, Washington, makes no warranty, expressed or implied,
that any wiring or electric equipment located beyond the point where Big Bend Electric Cooperative, Inc.
connects its wiring to a member’s building, structure, or facility, is adequate, safe, fit for the purpose
intended, or that it conforms to any legal code or building code requirements. Nothing herein or in the Big
Bend Electric Cooperative, Inc. service specifications or in any other documents shall be construed as
undertaking or imposing an obligation upon the Big Bend Electric Cooperative, Inc. to inspect or
otherwise insure that a member’s wiring, electrical equipment, or leased appliances are adequate, safe,
or fit for the purpose intended. No employee or representative of Big Bend Electric Cooperative, Inc.
other than the Board of Directors has the authority to alter or to otherwise change the fore-going.
Electric service will be used only for the purpose specified in the service application agreement or rate
schedule. Electric service will not be re-metered, resold, or shared by others. Members will not extend
their electrical facilities outside their premises for service to other members or premises.
Phone Numbers
Big Bend Electric Cooperative ...................................................... 509 - 659 - 1700
Toll-free ................................................................................... 866 - 844 - 2363
Department of Labor and Industries, L & I Electrical Inspection –
http://www.lni.wa.gov/tradeslicensing/electrical/
Kennewick –
4310 W 24th Ave ............................................................................ 509 - 735 - 0100
Fax .......................................................................................... 509 - 735 - 0120
Toll-free ................................................................................... 800 - 547 - 9411
24-hour Inspection Request ................................................... 509 - 735 - 0148
Moses Lake –
3001 W. Broadway ........................................................................ 509 - 764 - 6900
Fax ......................................................................................... 509 - 764 - 6923
Toll-free ................................................................................... 800 - 547 - 2285
24-hour Inspection Request ................................................... 509 - 764 - 6966
One Call – Call Before You Dig
The Member will mark the area where digging will occur in white paint to identify the locations for utility
locators.
Utilities Underground Location Center (Call Before You Dig) ........ 1-800-424-5555
OR www.callbeforeyoudig.org OR 811
To get a locate, call the (UULC) (“Call Before You Dig”) 2 full working days prior to excavation. At no
charge to you, utilities will mark where their facilities are located on your property. It’s required by law.
By failing to call for a locate, you could be held liable for any damages you incur to the utility facilities.
The color markings are designated to identify the following Utilities:
Red ......... Electric
Yellow ..... Gas/Oil
Orange ... Telephone/Cable TV
Blue ........ Water
Green ..... Sewer
Purple ..... Reclaimed Water
Pink ........ Survey
White ...... Proposed Excavation, Area to be located
Washington State requires that any digging within 24 inches on either side of the location markings be
done by hand.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page ii
TABLE OF CONTENTS
1 – General ...................................................................................................................................... 1
Scope
Cooperative Responsibilities
Member Responsibilities
Right-of-Way and Permits ............................................................................................................ 2
2 – Services .................................................................................................................................... 3
Available Service
Cooperative Responsibilities
Member Responsibilities
Temporary Services
Remote Meter Identification
3 – Overhead Service ..................................................................................................................... 5
General
Cooperative Responsibilities
Member Responsibilities
4 – Underground Service ............................................................................................................... 6
General
Cooperative Responsibilities
Member Responsibilities
Trenching ...................................................................................................................................... 6
General
Depth
Bedding
Conduit ......................................................................................................................................... 7
Transformers, Equipment, Vaults ................................................................................................. 7
General
Transformers
5 – Metering .................................................................................................................................... 8
General
Cooperative Responsibilities
Member Responsibilities
Location and Access .................................................................................................................... 8
Location
Access
Access Maintenance
Installation .................................................................................................................................... 9
General
Height
Single-Phase 400-Ampere and Below, Self-Contained Metering .............................................. 10
General
Overhead
Underground
Three-Phase 200-Ampere and Below, Self-Contained Metering ............................................... 10
General
Overhead
Underground
Single and Three Phase, Current Transformer (CT) Metering ................................................... 11
General
CT Enclosure
CT Mounting Bracket
Meter Socket and Conduit
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page iii
CT Metering – Services Over 800 Amperes ............................................................................... 12
Multiple Occupancy .................................................................................................................... 12
General
Single-Phase (120/240)
Network (120/208)
Three-Phase
Identification
Approved Equipment .................................................................................................................. 14
6 – Power Quality ......................................................................................................................... 16
Cooperative Responsibilities
Member Responsibilities
Motors ......................................................................................................................................... 16
Starting Load
Harmonics
Motor Protection
Power Factor-Correction
7 – Emergency and Standby Generators ................................................................................... 18
Member Responsibilities
8 – Net Metering (Generation under 100 kW) ............................................................................ 18
Drawings
MT-C-O General Information, Clearances, Overhead Secondary
MT-C-S General Information, Clearances, Surface Equipment
MT-C-T General Information, Clearances, Trench
MT-P-B General Information, Primary Equipment, Traffic Bollards
MT-P-T General Information, Primary, Trench
MT-S-T General Information, Secondary, Trench
MT1-B Single Phase, Self Contained Metering, Building
MT1-N Single Phase, Self Contained Metering, Network
MT1-P Single Phase, Self Contained Metering, Pole
MT1-R Single Phase, Self Contained Metering, Remote
MT1-T Single Phase, Self Contained Metering, Temporary
MT1-CT-B Single Phase, Current Transformer (CT) Metering, Building
MT1-CT-P Single Phase, Current Transformer (CT) Metering, Pole
MT1-CT-R Single Phase, Current Transformer (CT) Metering, Remote
MT3-B Three Phase, Self Contained Metering, Building
MT3-P Three Phase, Self Contained Metering, Pole
MT3-R Three Phase, Self Contained Metering, Remote
MT3-CT-B Three Phase, Current Transformer (CT) Metering, Building
MT3-CT-P Three Phase, Current Transformer (CT) Metering, Pole
MT3-CT-PL Three Phase, Current Transformer (CT) Metering, Platform
MT3-CT-R Three Phase, Current Transformer (CT) Metering, Remote
MT3-CT-S1 Three Phase, Current Transformer (CT) Metering, Switchgear with Meter
MT3-CT-S2 Three Phase, Current Transformer (CT) Metering, Pad Mounted with Meter Base
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 1 of 18
1 – GENERAL
Big Bend Electric Cooperative (Cooperative) will make every reasonable effort to provide safe, reliable,
and adequate electric service to best meet your requirements. To best accomplish this objective, the
Cooperative should be contacted well in advance of your desired service connection date.
Available service voltage, phase, etc. varies at different locations.
The information contained in this handbook refers primarily to service requirements for lighting and power
installations at the usual secondary distribution voltages. Those voltages are listed in 2 – Services.
Service requirements for an installation requiring higher distribution voltages are subject to negotiations
between member and the Cooperative.
The specifications and requirements contained in this handbook are for the purpose of safeguarding
members and the employees, and providing adequate service to all members. Strict adherence to this
handbook will insure prompt service and connections; and allows the Cooperative to standardize its
equipment, thus affording members with the best possible service at the lowest possible cost.
All services provided by the Cooperative are subject to the Cooperative’s bylaws, policies, rate tariffs, and
member agreements. This handbook does not supersede any of those documents. This handbook
replaces all other standards previously issued and is enforced in all areas served by the Cooperative.
Scope
1. This handbook covers the Cooperative requirements and responsibilities and the member
responsibilities for member service installations.
2. Nothing in this handbook shall be so interpreted as to conflict with the laws and regulations of the
State of Washington or other regulatory bodies having jurisdiction.
3. All references to the member will include the member, member’s agent or contractor.
4. Non-conforming services will not be energized, or, if energized, will be subject to disconnection.
5. Existing non-conforming services will be dealt with on a case-by-case basis.
Cooperative Responsibilities
1. The Cooperative’s Engineer will provide the member with information and interpretations of the
Service & Metering Requirements related to the member’s specific installation.
2. The Cooperative will require installations to conform to applicable laws and regulations, including
the National Electric Code.
3. The Cooperative will require all installations to be inspected and approved by the Washington
State L & I Electrical Inspector prior to energization.
Member Responsibilities
1. If the member is not knowledgeable in electrical work, an electrical contractor should
install equipment.
2. The member will contact the Cooperative’s Engineer before beginning any construction of,
modification of, or addition to an electric service. The member will be responsible for any
changes required to work performed before such consultation.
3. The member will not open any Cooperative seals or locks, or in any way interfere with or tamper
with a Cooperative installation.
4. The member will not make any connection to the Cooperative’s system.
5. The member will contact the L & I Electrical Inspector to determine if a main breaker is required
as part of the metering equipment.
6. Prior to the Cooperative energizing the service, the member will call the office stating they are
ready for connection and the L & I Electrical Inspector has notified the Cooperative that the
installation has been approved. The scheduling of the inspection is between the member and the
L & I Inspector.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 2 of 18
Right-of-Way and Permits
Cooperative Responsibilities
1. The Cooperative will construct, own, operate and maintain lines along public streets, roads,
highways and public lands that the Cooperative has the legal right to occupy or on private
property across which right-of-way, satisfactory to the Cooperative, may be obtained.
2. The Cooperative will provide the forms required to grant necessary easements.
3. The Cooperative will obtain the required permits/licenses from public agencies or entities
(DOT, USBR, Irrigation Districts, BLM, DNR, Railroads, Counties, Cities, etc.) and
coordinate any professional land survey(s), if required, for these permits.
Member Responsibilities
1. The member is responsible to obtain signatures from property owners for all required easements
using Cooperative documents. These documents provide suitable right-of-way for the
construction and maintenance of Cooperative facilities. Any expenses incurred are the member’s
responsibility.
2. In the event there is any challenge to the Cooperative’s right to install facilities on land owned by
others, it will be the obligation of the applicant to resolve such challenge to the Cooperative’s
satisfaction before the Cooperative will have any obligation to make or complete the line
extension.
3. The member will provide and maintain safe and unobstructed access, as determined by the
Cooperative, to all Cooperative facilities for construction, operation and future maintenance.
4. The member will pay for any or all permits/licenses, including but not limited to, those
listed below, and other permits/license as may be required along with any required
professional surveys.
a. Washington State Department of Transportation (WSDOT) – Permits are required if the
Cooperative’s wires cross or parallel a state highway within their right-of-way. The fee for this
permit ranges in cost from $150 to $750. A minimum of one to three months is required.
b. Avista Utilities – Permits may be required when wires cross under or over Avista lines. A
minimum of two weeks’ notice is required.
c. Bonneville Power Administration (BPA) – Permits are required if the Cooperative’s primary or
secondary wires cross under a BPA power line or are located in the BPA easement area. A
minimum of three months is required.
d. United States Bureau of Reclamation (USBR) – Licenses are required if the Cooperative’s
primary or secondary wires cross USBR property. The USBR charges $200 and a
percentage of Fair Market Value for this license. A minimum of six months is required.
e. Department of Natural Resources (DNR) – Easements are required if the Cooperative’s
primary or secondary wires cross DNR property. To obtain this permit a professional survey
is required. DNR charges for utility easements vary and are based upon RCW 79.36.530.
Upon completion of the survey, the survey and application fee will be submitted to DNR for
processing and approval. A minimum of six months is required. DNR tenants will need to
contact the Cooperative for requirements.
f. Bureau of Land Management (BLM) – Easements are required if the Cooperative’s primary or
secondary wires cross BLM property. An application and fee must be submitted to BLM. The
fee ranges from $175 to $1,125. A minimum of three months is required.
g. Railroad – Permits are required if the Cooperative’s primary or secondary wires cross over or
under a railroad track. The cost for a permit from Burlington Northern Santa Fe Railroad is
$3,000 and Union Pacific Railroad is $2,000. A minimum of six weeks is required.
h. County Permits may be required to cross and work in County right-of-way. All County
permits are a minimum of two weeks to obtain.
i. ECBID and SCBID permits are required to cross and work in District right-of-way. Permits
may take up to six weeks to obtain.
* All fees are subject to change and fees quoted are minimum amounts.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 3 of 18
2 – SERVICES
The Cooperative’s Engineering department will develop a design to meet the member’s needs and that of
the Cooperative. We have the best results when the requesting party or representative meets at the job
site to review the request. The Engineer will develop a design and quote a cost following the guidelines
below. The Engineer will not be able to give an accurate cost while meeting on site.
The Cooperative will determine the length, depth, point of delivery, location, phases, primary
voltage, capacity and cost of the line extension. The line extension will be compatible with
present electrical distribution facilities.
The line extension design will be designed and constructed in accordance to the Cooperative’s
minimum standards.
Members must provide the Cooperative with final property specifications as required and
approved by the appropriate government authorities. These specifications may include, but are
not limited to, recorded plat maps, utility easements, final construction grades and installed
property corner pins.
Additional costs will be incurred for unusual labor and/or materials which are requested by the
member but which are not necessary to construct the line extension based on the Cooperative’s
minimum design, construction and operating practices. All Costs in Aid of Construction (C.I.A.C.)
must be paid in full before work begins. Additional costs may include, but are not limited to, the
following:
a. Underground facilities in overhead areas;
b. Facilities longer, deeper or larger than deemed appropriate by the Cooperative;
c. Facilities to provide three-phase service where single-phase is adequate;
d. Relocation of existing facilities; and/or
e. Any unusual condition not typically encountered during normal construction. This
includes, but is not limited to, frost, weather, rock, landscape replacement, boring
charges and equipment.
Available Service
1. The Cooperative offers service at:
Single-phase 120/240 volts
Single-phase 120/208 volts (network)
Single-phase 240/480 volts (Overhead Transformer Only)
Three-phase 120/208 volts
Three-phase 120/240 volts (Overhead Transformers Only)
Three-phase 240/480 volts (Overhead Transformers Only) – New General Service
Accounts only, Effective 2015
Three-phase 277/480 volts (Padmounted Transformer only) – Overhead coming in 2013
2. All three-phase services will be 4-wire connections.
3. In accordance with Cooperative rate schedules, service may be at primary voltages.
Cooperative Responsibilities
1. The Cooperative's Engineer will determine the "point of service" where Cooperative facilities will
connect to member's facilities.
2. The Cooperative will furnish, install and maintain transformers, secondary conductors, and
meters to provide electrical energy to the "point of service".
3. Prior to installation, the Cooperative must approve the meter location and type.
4. The Cooperative will make any and all connections of member's facilities to the Cooperative's
system.
5. The Cooperative reserves the right to refuse service or to disconnect/terminate service whenever
the member’s wiring, equipment, or use of service does not conform to lawful codes and
regulations, or to the rules, terms, and conditions stated herein.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 4 of 18
Member Responsibilities
1. The member will complete a service application complete with the expected electrical load. If the
electrical load changes, the member will provide the Cooperative with the new information in
writing as soon as possible. Service applications will only be valid for 90 days without
forward progress on the project. After the 90 days, a new Service application will need to be
submitted.
2. The member will furnish, install and maintain all facilities beyond the "point of service".
3. The member will use reasonable care in designing electric wiring and circuits so that the loads on
the individual phases, legs, and circuits of the Cooperative's service conductors are properly
balanced at all times.
4. The member will be solely responsible for the electrical and mechanical protection of wiring and
accessories owned and operated by the member including protection against damage caused by
reversal of rotation (phase reversal) on all rotating equipment.
5. The member will install safety and protective equipment in accordance with applicable codes and
regulations.
6. The member will be responsible for repair of any damaged or deteriorated member furnished
facilities (service mast and conductors, point of attachment, meter socket, etc.). Any repaired or
modified facilities must be inspected and approved by the L & I Electrical Inspector before
being re-energized.
7. In the event a member desires to substantially add or to increase the size of his electrical
equipment, it will be the member’s responsibility to notify the Cooperative in writing sufficiently in
advance so that the Cooperative's facilities may be modified to accommodate the increased load.
The Cooperative has forms available for this purpose. If the member fails to so notify the
Cooperative, the member will be held responsible for any damage to the meter or any other
equipment of the Cooperative caused by such increased load.
8. Member-owned metering equipment, switching devices, conduits and conductors will be installed
per the Cooperative requirements shown here-in.
9. Member-owned luminaries and basketball hoops, satellite dishes, antennas, etc., will not be
installed on the Cooperative's poles.
Temporary Services
The Cooperative will provide temporary service, for construction sites and similar purposes, for a
maximum of one year. Meter socket must be L&I approved. See Drawing MT1-T.
Remote Meter Identification
Meters not installed on the structure which it is serving will be identified as described in
5 – Metering, Multiple Occupancy: Identification.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 5 of 18
3 – OVERHEAD SERVICE
General
Overhead services must meet all vertical and horizontal clearance requirements of the NESC,
NEC, WAC 296-46B, and any other applicable standards (DOT, County, City, etc.). Some typical
secondary voltage clearance requirements are illustrated on Drawing MT-C-O.
Cooperative Responsibilities
1. The Cooperative's Engineer will determine the location of the overhead service conductors.
2. The Cooperative's Engineer will determine the requirements for, and the location of, any
necessary poles, guy wires and anchors.
3. The Cooperative will furnish, install and maintain the service conductors to the "point of service".
4. The Cooperative will make any and all connections of member facilities to the Cooperative's
electrical system.
Member Responsibilities
1. The member will furnish and maintain a point of attachment to member's premises (or meter pole)
that provides the necessary clearances.
2. The member will furnish, install and maintain the necessary service equipment (mast and
conductors, weatherhead, meter socket, guy wires and bracing, etc.).
3. Construction of service masts will conform to NEC, WAC 296-46B and Drawings MT1-B,
MT1-P, MT1-CT-B, MT1-CT-P, MT3-B, MT3-P, MT3-CT-B, MT3-CT-P or MT3-CT-PL and be of
the specified length.
4. All conduits will be attached to the pole on one set of stand-off brackets in the area indicated on
the applicable drawing.
5. Service masts will support only power conductors. Communication wire is not permitted.
6. The Cooperative will furnish and maintain meter poles.
7. The Cooperative prefers that the service drop is in clear space. However, if the service drop will
pass through trees or brush, the member must clear and maintain a three-foot path to allow
service personnel to access the line, and allow lines to hang without contacting trees or limbs.
8. Metering requirements are listed in 5 – Meters.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 6 of 18
4 – UNDERGROUND SERVICE
General
1. Prior to any construction of underground service facilities, the member will contact the
Cooperative's Engineer for specifications and approval.
2. The member will be responsible for any changes necessary to work begun without Cooperative
Engineering approval.
Cooperative Responsibilities
1. The Cooperative's Engineer will determine the location of underground facilities.
2. The Cooperative's Engineer will determine the need for easements and access.
Member Responsibilities
1. The member will furnish all required secondary trenches and conduit to Cooperative
specifications. See Drawings MT-C-T and MT-S-T.
2. The member may furnish all required primary trenches and conduit to Cooperative specifications.
See Drawings MT-C-T and MT-P-T.
3. The member will furnish, install and maintain all required service equipment (meter socket,
disconnect, pedestal, etc.). See Drawing MT1-B, MT1-N, MT1-R, MT1-CT-B, MT1-CT-R, MT3-B,
MT3-R, MT3-CT-B, MT3-CT-R, MT3-CT-S1 or MT3-CT-S2.
4. Metering requirements are listed in 5 – Meters.
Trenching
General
1. The member will contact the One-Call Locating service (1-800-424-5555 or 811) at least 48 hours
prior to any excavation. This is in accordance with RCW 19.122.
2. All excavation within 24 inches of any locate marking will be done by hand.
3. A Cooperative representative will inspect all trenches before backfill. Trenches covered before
inspection will not be used for electrical service.
4. Joint use of trenches for other utilities such as telephone, cable TV, other electrical conductors
and water lines is generally permitted. The Cooperative's Engineer will be consulted prior to such
joint use to insure conformance to Cooperative requirements.
Depth
1. Trenches on the Cooperative side of the "point of service" will be deep enough to provide a
minimum of 36" of cover for the conduit. This applies to both primary and secondary conduits.
See Drawings MT-C-T, MT-P-T and MT-S-T.
2. In rocky soil conditions, where bedding is required, the trench will be an additional 6" deeper to
allow placement of proper bedding under the conduit.
Bedding
1. Backfill material will be a maximum 1" minus for a minimum of 6" above and below the conduit.
The backfill material will contain no sharp or foreign objects. Bedding sand would be the
preferred material.
2. If the native backfill does not meet these requirements, member will be responsible for furnishing
and installing appropriate backfill for a minimum of 6" above and below the conduit.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 7 of 18
Conduit
1. "Conduit" means listed, labeled, UL-approved electrical conduit, typically Schedule 40 or
Schedule 80 PVC. Conduit is grey in color. Water pipe, sewer pipe and other round stock is not
acceptable for electrical use.
2. "Sweep" means a large-radius conduit bend (as noted on drawing), typically either 90 degrees or
45 degrees.
3. All secondary conductors will be in conduit.
4. In general, primary (high-voltage) conductors will be installed in conduit. The Cooperative's
Engineer may approve the use of CIC (Cable in Conduit) or other installations in specific cases.
5. The Cooperative's Engineer will determine the size and number of conduits to be placed.
6. A conduit run should contain no more than 270 degrees of total bend, including at transformers
and metering equipment. Any conduit run with more than 270 degrees of total bend must have
prior Engineering approval.
Transformers, Equipment, Vaults
General
1. The Cooperative's Engineer will determine the need for, and the location of, all transformers,
vaults, and other primary-voltage equipment necessary to furnish underground service.
3. The Cooperative will furnish, install and maintain all necessary transformers, vaults and other
equipment with the exception that members may install vaults.
See Drawings MT-P-T and MT-S-T.
4. Where necessary to protect above-ground equipment, the member will furnish, install and
maintain bollards. See Drawing MT-P-B.
Transformers
1. The member must maintain a clear working space around the transformer free from vegetation,
landscaping, structures of any sort, or anything that would restrict Cooperative access for
maintenance or repair. This is shown in the sketch below.
2. The member will insure that nothing is placed within the clear working space that would impede
the free flow of cooling air over the transformer.
CLEARANCE ENVELOPE:
KEEP SHRUBS, TREES AND STRUCTURES 15' AWAY FROM
THE SIDE WITH DOORS AND 5' AWAY FROM OTHER SIDES.
OBSTRUCTIONS WILL BE REMOVED WHEN NECESSARY
.
PADMOUNT
EQUIPMENT
5 ft
5 ft5 ft
15 ft
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 8 of 18
5 – METERING
General
1. Nothing in this handbook shall be so interpreted as to conflict with the regulations of the State of
Washington or other regulatory bodies having jurisdiction.
2. All references to the member will include the member’s agent or contractor.
Cooperative Responsibilities
1. The Cooperative’s Engineer will provide the member with information and interpretations of these
Requirements related to the member’s specific installation.
2. The Cooperative will require installations to conform to applicable laws and regulations.
3. The Cooperative will require all installations to be inspected and approved by the State Electrical
Inspector prior to energization.
Member Responsibilities
1. The member will contact the Cooperative’s Engineer before beginning any construction of, or
modification or addition to, an electric service. The member will be responsible for any changes
required to work performed before such consultation.
2. The member will provide the Cooperative Engineer with load information on Cooperative forms
OR calculations per NEC to allow proper sizing of service equipment.
3. The member will provide and install, in accordance with the following requirements, the
necessary equipment for the Cooperative’s metering.
4. The member will provide all necessary maintenance and repairs to the metering installation.
5. The member will not break any Cooperative seals or locks, or in any way interfere with or tamper
with a Cooperative metering installation.
6. Prior to installation, the Cooperative must approve the meter location and type.
7. The member will not make any connection to the Cooperative’s system.
Location and Access
Location
1. Metering must be installed in an acceptable location and approved by the Cooperative’s
Engineer. An example is shown below.
2. If the meter location is unacceptable to the Cooperative’s Engineer, it will be relocated at the
member’s expense to an acceptable location.
3. Metering must be installed on the outside wall of a structure.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 9 of 18
4. Metering equipment installed in alleys or other exposed locations will be protected from damage.
5. Metering equipment will not be located in carports, breezeways, porches or other similar
locations. In the event that building construction, alteration, or repair, (i.e. construction of a porch
or other structure) in the opinion of the Cooperative, makes a meter inaccessible, the member will
at member’s expense, relocate the meter socket and/or service entrance conductor to an outside
location which is accessible to Cooperative personnel.
6. Metering equipment will be surface mounted, or, if recessed, will project at least 1” from the final
building finish. Recessed metering equipment will be listed and labeled for recessed installation.
Access
1. The member will provide, as a condition of service, access to Cooperative facilities located on
member’s premises.
2. The member will provide access, as required by WISHA, “free from recognized hazard”.
Examples of hazards might include (but are not limited to) animals, traffic, machinery or industrial
environments, height, chemicals, vegetation, unstable work surfaces, falling trees or rocks, etc.
3. The member will provide, as required by the National Electrical Code and WAC 296-46B, clear
working space in front of the metering equipment, 36” deep, 30” (or the width of the equipment if
greater) wide, and 6’8” high. This space will be maintained clear of all other equipment,
vegetation, etc.
4. The working surface in front of metering equipment will be reasonably level and graded to drain
away from the equipment.
5. Members with security requirements will provide for the installation of a Cooperative lock to allow
Cooperative access.
Access Maintenance
1. The member will maintain the required access to and clear working space about Cooperative
facilities on member’s property.
2. When Cooperative facilities on member’s property are not readily accessible, in the opinion of the
Cooperative, the member will be responsible for necessary corrections.
3. When, in the opinion of the Cooperative, alterations on the member’s property (remodeling,
landscaping, etc.) interfere with ready access to Cooperative facilities, member will be
responsible for the cost of remedy.
4. When, in the opinion of the Cooperative, pets, livestock, or other animals interfere with ready
access to Cooperative facilities, member will be responsible for installation of necessary barriers
to remedy the problem. If relocation of Cooperative facilities becomes necessary, member will be
responsible for all costs.
Installation
General
1. All installations must conform to the requirements of the National Electric Code, WAC 296-46B,
and these Service & Meter Requirements.
2. Equipment to be installed will be listed, labeled, manufactured in accordance with all applicable
standards, and suitable for the purpose in which it is utilized.
3. Metering enclosures, switchgear, disconnects and other equipment which allows access to
unmetered conductors will be capable of being sealed using the Cooperative’s normal seals and
locks.
4. All metering connections will be made in sealed enclosures.
5. Equipment will be installed level, plumb and securely fastened to a rigid surface not subject to
excessive vibration. Meter sockets must be installed to withstand the forces imposed by
installation and removal of meters.
6. Where used to support metering equipment, wood posts, dimensional lumber and plywood will be
pressure-treated lumber. Posts will be a minimum 6” x 6” x 8’. Dimensional lumber will be a
minimum of 2”x 4”, and plywood will be a minimum of ¾”. Metal channel may also be used.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 10 of 18
7. Meters will not be covered. The Cooperative may install covers where necessary to prevent
vandalism.
8. Meter sockets will not be used as a raceway.
9. Service conduits passing from the outside to the inside of a structure will be sealed in accordance
with the NEC 300.7 to prevent condensation in the meter socket.
Height
1. Meter sockets will be installed at a height of 4’ to 6’ from the center of the meter to finished grade
in front of the meter. See the Drawing(s) applicable to your installation.
2. Mobile home pedestals will be installed at a height of 4’ to 6’ from the center of the meter to
finished grade in front of the meter. See Drawing MT1-R.
3. Multiple-occupancy metering equipment will be installed with the lowest meter no lower than 3’
from the center of the meter to finished grade, and the highest meter no higher than 7’ from the
center of the meter to finished grade in front of the meter.
4. Current transformer enclosures will be installed at a height of 6’ from the top of the enclosure to
finished grade in front of the enclosure.
Single-Phase 400-Ampere and Below, Self-Contained Metering
General
1. The meter socket will be 4-jaw.
2. The meter socket may be ring-type or ringless.
3. Lever bypasses are recommended for non-residential services. Automatic bypasses are not
permitted.
4. Locking-jaw meter sockets are permitted but not required.
5. The service conductors will be color coded per the applicable drawing.
Overhead
1. The member will leave a minimum of 36” of service conductor at the weatherhead for connection
to Cooperative’s wires.
2. The weatherhead will be above the point of attachment of the service drop.
Underground
1. The supply conduit will be installed in the bottom left knockout of the meter socket.
2. Where the service conductor length makes larger conductors necessary, the member will furnish
a socket capable of accepting a 3” conduit, and with lugs that will accept 350 MCM aluminum
conductors. The Cooperative’s Engineer will advise the member of this situation.
Three-Phase 200-Ampere and Below, Self-Contained Metering
General
1. The meter socket will be 7-jaw.
2. The meter socket may be ring-type or ringless.
3. Lever bypasses are required. Automatic bypasses are not permitted.
4. Locking-jaw meter sockets are permitted but not required.
5. Where a service has a high leg (delta connection), the high leg will be connected to the
right-hand lugs in the meter socket, and taped orange.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 11 of 18
6. For services with motor load, the following chart will be used.
VOLTAGE HORSEPOWER TYPE OF SOCKET
240 14 or less 100 amp self-contained
240 15 to 39 200 amp self-contained
240 40 and above CT
480 45 or less 100 amp self-contained
480 45 to 75 (110*) 200 amp self-contained
480 76 (111*) and above CT
* Consulting Engineering regarding your installation.
Overhead
1. The member will leave a minimum of 36” of service conductor at the weatherhead for connection.
2. The weatherhead will be above the point of attachment of the service drop.
Underground
1. The supply conduit will be installed in the bottom left knockout of the meter socket.
2. The Cooperative’s Engineer will advise the member of the service conductor size and material, if
larger than the manufacturer’s advertised range, to insure the member provides a socket with
appropriate lugs.
Single and Three Phase, Current Transformer (CT) Metering
General
1. Services from 401-800 amperes single-phase and 201-800 amperes three-phase will be metered
using current transformers (CTs).
2. CTs will be installed using a member furnished CT mounting bracket in a listed CT enclosure.
3. CTs will be mounted, by the Cooperative, on the pole or in a listed CT enclosure. The
Cooperative’s Engineer will make the determination of the CT location.
4. The Cooperative will furnish and install the CTs, CT wiring, test switch and meter. The member
will be responsible for the cost of the test switch.
5. Equipment location and mounting heights will be per 5 – Metering, Locations and 5 – Metering,
Installation sections. This information is also shown on the applicable drawings.
6. See Drawings MT1-CT-B, MT1-CT-P, MT1-CT-R, MT3-CT-B, MT3-CT-P, MT3-CT-PL or
MT3-CT-R for details.
CT Enclosure
1. The member will furnish and install a listed CT enclosure.
2. The minimum size will be 24” x 48” x 11” for single phase and 36” x 48” x 11” for three phase.
Larger sizes are permitted.
3. Enclosures will have a hinged cover. Piano hinges are not permitted.
4. Cooperative service conduits will enter the enclosure from the top or bottom, grouped at either
the left or right side.
5. The member will bond the CT enclosure to the grounded service conductor, per NEC.
6. Member conduits will enter the enclosure through the top, bottom, or top ¼ or bottom ¼ of the
back or sides of the enclosure. The middle ½ of the enclosure will have no member conduits.
7. The meter socket conduit may enter the CT enclosure opposite the CTs.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 12 of 18
CT Mounting Bracket
1. The member will furnish and install a CT mounting bracket. Lugs come on mounting bracket.
2. The mounting bracket may be either top- or bottom-fed. The standard will be Cooperative
conductors on the top of the mounting bracket.
3. The member will furnish and connect conductors from the mounting bracket to the main service
disconnect(s).
4. The Cooperative will furnish and connect service conductors from the transformer to the mounting
bracket.
5. Conductors will not be routed through the area of the mounting bracket; conductors will follow the
walls of the CT enclosure.
Meter Socket and Conduit for CT Metering
1. The member will furnish and install an approved meter socket.
2. The member will install a 1 ½” metallic conduit between the CT enclosure and the meter socket.
3. This conduit will be continuous from the enclosure to the socket, with no junction boxes,
condulets or other fittings allowing access to the conductors.
4. This conduit will have a maximum of 360 degrees of bend.
5. This conduit will have a maximum length of 50 feet. (Contact the Cooperative’s Engineer for
exceptional circumstances.) Preferred installations are shown in the applicable drawings.
6. Grounding and bonding of this raceway will be per NEC.
CT Metering—Services Over 800 Amperes
1. Services rated over 800 amperes will be metered with current transformers mounted in
switchgear, unless an alternative is approved by Engineering.
2. Cooperative requirements are detailed in Drawings MT3-CT-S1 and MT3-CT-S2.
3. The member will furnish and install an approved 13-jaw meter socket.
4. The Cooperative will approve the meter location. Under Special Approval, the switchgear may be
installed inside a building. In that case, conduit will extend no more than 15 feet inside the
building lines (unfused conductors per NEC and WAC 296-46B). Grounding and bonding of this
raceway will be per NEC.
Multiple Occupancy
General
1. Metering equipment for multiple-occupancy installations will be factory-manufactured solid-busbar
switchgear. (Field installations of a wireway and multiple individual meter sockets will not be
acceptable.)
2. The member will submit manufacturer’s drawings or cut sheets to the Cooperative for approval
before installing the metering equipment.
3. All compartments and disconnects allowing access to unmetered conductors will be capable of
being sealed using the Cooperative’s standard seal.
4. Meter sockets will be ring-type, to accept locking rings.
5. Lever bypasses are recommended for non-residential services. Automatic bypasses are not
permitted.
Single-Phase (120/240 volts)
The socket will be 4-jaw.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 13 of 18
Network (120/208 volts)
1. The socket will be 5-jaw, with the 5th jaw in the 9-o’clock position.
2. All load will be balanced between phases within 10%.
Three-Phase
The socket will be 7-jaw.
Identification
1. The member will permanently identify each meter socket. Meters will not be installed nor
services energized until identification is complete.
2. Sockets will be identified by address and/or unit number permanently affixed to the entrance door
of the unit. Occupant or business name is not sufficient.
3. Satisfactory permanent identification means include engraved plastic or metal tags attached with
screws, bolts or rivets. Permanent ink markers, label makers, etc. are not permitted as
permanent identification. Adhesives may be used, but screws, bolts or rivets are still required.
4. Engraved lettering will be at least ½” high.
5. If unit identification changes, the member will notify the Cooperative in writing immediately.
6. The Cooperative will record consumption and issue billings according to the member’s
identification of the units. Proper identification of a unit is the member’s responsibility.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 14 of 18
Approved Equipment
The following is a list of meter equipment that will comply with the Cooperative’s standards. Other
manufacture’s equivalent equipment is acceptable.
SinglePhase‐Self‐ContainedMeterSockets,400AmperesandBelow
Lockingjawpermitted. NoBy‐pass.LeverBy‐pass.
Milbank100/125Amp200Amp320/400Amp
120/240V,4‐jaw,Meter
Only
OH ‐‐ U4517‐DL‐M4U1079‐R
UG ‐‐ U4518‐O‐WU1129‐O‐K3L‐K2L
OH/UGU7490‐RL*U1211‐RXL ‐‐
120/240V,4‐jaw,
Meter/mainCombination**
OH ‐‐ U3574‐RL‐200 ‐‐
UG ‐‐ U3584‐O‐200U4031‐O‐2/200
OH/UGU5168‐XTL‐100U5168‐XTL‐200U5059‐X‐2/200
*AddA7551ClosingCapforunderground.**CallfactoryifMainBreakersarerequired.
CooperB‐Line(CircleAW)100/125Amp200Amp320/400Amp
120/240V,4‐jaw,Meter
Only
OH ‐‐ 204MS68EL32T45GR1N
UG ‐‐ U204EL32T44GRST
OH/UG011EL20L43GR2N ‐‐
120/240V,4‐jaw,
Meter/mainCombination
OH ‐‐ 2M2R ‐‐
UG ‐‐ U2M2RELCB32C24A4AGRST
OH/UGU214MTBL*U224MTBL*ELCB32C24A5GR1N
*AvailableinotherAICratingsonrequest.
SinglePhase‐CTMetering,401to800Amperes
ProvisionsforCooperativetestswitch.
Milbank
400Amp800Amp
Enclosure‐24"x48"x11" CT244811‐HCCT244811‐HC
CTMountingBaseK4903K4729
MeterBase,600Vac,6‐jawOH/UGUC3436‐XLUC3436‐XL
Notes:1.Mountingracksare50kAICandhavelugsinstalledonbothLine&Load.
2.CTcansarehinged.
CooperB‐Line(CircleAW)400Amp800Amp
Enclosure‐24"x48"x11" 244811HRTCT244811HRTCT
CTMountingBase6019HAL6019HEL
MeterBase,600Vac,6‐jawOH/UG1214612146
Notes:1.Mountingracksare50kAICandhavelugsinstalledonbothLine&Load.
2.CTcansarehinged.
Equivalentequipmentisacceptable.Requirementsaresubjecttochangewithoutnotice.
ContactBBECEngineeringat(509)659‐1700or866‐844‐2363withanyquestions.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 15 of 18
ThreePhase‐Self‐ContainedMeterSockets,200AmperesandBelow
Leverby‐passrequired.Lockingjawpermitted.
Milbank 125Amp200Amp
120/240V,120/208V,
240/480V,277/480V,
7‐jaw,MeterOnly
OH/UGU9320‐RXLU7423‐RXL
OHU1681‐RL
120/240V,120/208V,
7‐jaw,MeterCombination*
200Amp
OH/UGU227MTB(10KAIC)**
240/480V,277/480V,
7‐jaw,MeterCombination*
200Amp
OH/UGU227MTB‐48(35KAIC)**
*CallfactoryifMainBreakersarerequired.**OtherAICratingsareavailable&acceptable.
CooperB‐Line(CircleAW)125Amp200Amp
120/240V,120/208V,
240/480V,277/480V,
7‐jaw,MeterOnly
OH/UGEC12L71GRSTEL20L73GR2N
OH927
120/240V,120/208V,
7‐jaw,MeterCombination*
200Amp
OH/UGU227MTBL(10KAIC)*
240/480V,277/480V,
7‐jaw,MeterCombination*
200Amp
OH/UGU227MTBHMS15(22kAIC)
*Availablein42kAIConrequest.
ThreePhase‐CTMetering,201to800Amperes
ProvisionsforCooperativetestswitch.
Milbank 400Amp800Amp
Enclosure‐36"x48"x11";48”x48"x14" CT364811‐HCCT484814‐HC
CTMountingBase K4904K4722
MeterBase,600Vac,13‐jawOH/UGUC3433‐XLUC3433‐XL
Notes:1.Mountingracksare50kAICandhavelugsinstalledonbothLine&Load.
2.CTcansarehinged.
CooperB‐Line(CircleAW)400Amp800Amp
Enclosure‐36"x48"x11";48”x48"x14" 364811HRTCT484814HRTCT
CTMountingBase 6067HAL6067HEEL
MeterBase,600Vac,13‐jawOH/UG121413121413
Notes:1.Mountingracksare50kAICandhavelugsinstalledonbothLine&Load.
2.CTcansarehinged.
ThreePhase‐CTMetering,over800Amperes
ProvisionsforCooperativetestswitch.OptionsforSpecificationMT3‐CT‐S2.
EricksonElectric1200‐2000Amp 1200,1600or2000Amps
PMCT‐07C(Padmounted)CT124,CT164,CT204CT‐07A(Wall‐mounted)
Equivalentequipmentisacceptable.Requirementsaresubjecttochangewithoutnotice.
ContactBBECEngineeringat(509)659‐1700or866‐844‐2363withanyquestions.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 16 of 18
6 – POWER QUALITY
This section will cover Cooperative requirements that assure suitable power quality, and prevent
interference with Cooperative service to other members.
Cooperative Responsibilities
1. Insofar as is practical, as determined by the Cooperative, the Cooperative will endeavor to
maintain standard voltages and frequency on its distribution systems, subject to variations within
reasonable limits.
2. Upon request, the Cooperative will furnish, in writing, information on the available fault current at
the serving transformer under normal operating conditions.
Member Responsibilities
1. The member's equipment will be designed to perform satisfactorily within the standard voltage
ranges and frequency provided on the Cooperative's system.
2. The member's system will be rated to withstand the fault current available at the serving
transformer.
3. The member will, upon request, provide the Cooperative with information regarding any
equipment that might cause interference with service to other members.
4. The member will be responsible for mitigating, at member's expense, any interference to the
Cooperative's service to other members caused by member's equipment. Examples of such
interference would include, but not be limited to, flicker, harmonic distortion, radio frequency
interference, etc.
5. The member will be responsible for providing any power conditioning or protective devices
required by their particular equipment (uninterruptible power supplies, filters, power factor
correction, harmonic suppression, etc.).
6. Where the member installs equipment/appliances with sensitive electronic components such as
computers and other devices containing programmable controllers, it is understood that it is
impossible for the Cooperative to provide "computer grade" voltage and power at all times. It will
be the responsibility of the member to install, own, operate, and maintain appropriate protection
equipment in order to protect such devices from damage including power line noise, voltage
fluctuations, power outages, spikes, transient surges or other power deviations.
Motors
Maximum single phase motor load is 10 horsepower. Maximum open-delta (V-phase) motor load is 25
horsepower. Phase converters may be permitted (where 3-phase distribution facilities are not available
or not feasible for member to afford) by special arrangement with the Cooperative.
Starting Load
1. The Cooperative's Engineer may require reduced-voltage starting on motors to reduce voltage
fluctuations on the Cooperative's system caused by motor starting.
2. Any 100 horsepower or larger motor will be analyzed by the Cooperative’s Engineer for motor
starting requirements. The Cooperative will notify the member of the motor starting requirements.
3. The member will need to acknowledge receipt of the motor start letter by signing the document
and returning it to the Cooperative. The service will not be energized until the motor start
letter is received.
4. A motor start test performed by Cooperative personnel may also be required. At the time of
testing, the Cooperative will verify the size and nameplate rating of the motor. If there are any
discrepancies, a delay in energizing the service could occur.
Harmonics
1. The Cooperative has adopted IEEE 519 - 1992 Standard as a guide to mitigate harmonic
distortion. Variable Frequency Drive (VFD) motors are a major source of harmonic distortion.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 17 of 18
This harmonic distortion causes heating of equipment and system disturbances on the
Cooperative’s distribution system.
2. The member will design the service so that harmonic distortion falls within the IEEE Standard.
This may require harmonic filters or various types of motors designed to reduce harmonics. The
service will not be energized until the VFD Approval Form is approved by the Cooperative.
3. If the Cooperative determines that the harmonic distortion is outside the standard, the service will
not be energized until satisfactory mitigation has been completed by the member. Energized
services will be subject to disconnection if distortion falls outside the IEEE standards.
Current Distortion – IEEE Std 519-1992, Table 10-3
Maximum Harmonic Current Distortion in Percent of IL
Individual Harmonic Order (Odd Harmonics)
(For 6-Pulse Rectifiers)
Isc/IL <11 11-15 17-23 23-35 >35 TDD
< 20* 4.0 2.0 1.5 0.6 0.3 5.0
20 - 50 7.0 3.5 2.5 1.0 0.5 8.0
50 - 100 10.0 4.5 4.0 1.5 0.7 12.0
100 - 1000 12.0 5.5 5.0 2.0 1.0 15.0
> 1000 15.0 7.0 6.0 2.5 1.4 20.0
Even harmonics are limited to 25% of the odd harmonic limits above.
Current distortions that result in a dc offset, e.g., half wave converters, are not allowed.
* All power generation equipment is limited to these values of current distortion, regardless of
actual Isc/IL.
These limits are for normal operation, not start-up conditions.
For 12 pulse rectifiers, increase above harmonic limits by 1.4142. For 18 pulse rectifiers,
increase above harmonic limits by 1.732.
WHERE
PCC = Point of Common Coupling
ISC = Maximum short-circuit current at PCC. Available by request from the Cooperative.
IL = Maximum demand load current (fundamental frequency component) at PCC. It is
recommended that the load current, IL, be calculated as the average current of the maximum
demand for the preceding 12 months.
TDD = Total Demand Distortion is Harmonic Current in percent of maximum demand load current
(15 or 30 minute demand).
Motor Protection
It will be the member’s responsibility to provide all necessary protective devices for all motors to
protect the motor from overload, under-voltage, over-voltage, phase loss or reversal, etc.
Power Factor Correction
The Cooperative recommends that the member install power factor correction equipment for
three-phase motors.
The Cooperative reserves the right to require the member to install, at the member's expense,
such power factor corrective and/or load limiting equipment as is necessary to limit load and
voltage fluctuations so that it is not necessary for the Cooperative to supply excess capacity and
facilities. Where the member installs such power factor corrective equipment, the Cooperative
reserves the right to require the member to install such controls as are necessary, in the
Cooperative's opinion, to prevent voltage or other disturbances on the Cooperative's system that
would be detrimental to service furnished to other members.
Big Bend Electric Cooperative
Service & Meter Requirements, February 2013 Page 18 of 18
7 – Emergency and Standby Generators
Member Responsibilities
1. Permanently-installed emergency or standby generators will be connected to the Cooperative's
system and the member's wiring system by a permanently-installed transfer switch installed in
accordance with the requirements of the NEC and WAC 296-46B.
2. All transfer switch installations must meet all applicable codes and be approved by the L & I
Electrical Inspector.
3. The transfer switch will disconnect all Cooperative conductors, including the neutral wire, from the
member's system prior to connecting the generator to the conductors supplying the load.
4. Portable generators will not be connected to a member's permanent wiring system at any time,
unless the interconnection is also made with a permanently installed transfer switch
8 – Net Metering (Under 100 kW)
Net Metering is the measurement of the difference between the electricity supplied by the Cooperative
and the electricity generated by a member-generator that is fed back to the Cooperative over the
applicable billing period.
A Net Metering System is a fuel cell, a facility that produces electricity and useful thermal energy from a
common fuel source, or a facility for the production of electrical energy that:
a. Uses either water, wind, solar energy, or biogas from animal waste as a fuel;
b. Has an electrical generating capacity of not more than one hundred kilowatts;
c. Is located on the member-generator’s premises and for which the Cooperative has, at the time of
application as member-generator, an active account in the member-generator’s name;
d. Operates in parallel with the Cooperative’s distribution facilities; and
e. Is intended to offset part or all of the member-generator’s requirements for electricity.
The Cooperative will require a written application from member-generators for all Net Metering Systems,
clearly detailing member-generators' proposals before any action will be taken by the Cooperative.
Such application will include the size, location, fuel source and equipment configuration of such proposed
installation. Applications will be processed in the order received by the Cooperative, and on a first-come
first-served basis. An application fee does apply.
Call the Cooperative for more information in regards to your project.
