HAR Title 6, Chapter 77, PUC - Transportation of Gas by Pipeline

HAWAII ADMINISTRATIVE RULES

TITLE 6

DEPARTMENT OF BUDGET AND FINANCE

PUBLIC UTILITIES COMMISSION

TRANSPORTATION OF NATURAL AND OTHER GAS BY

PIPELINE: MINIMUM SAFETY STANDARDS

Subchapter 1 General

'6-77-1 Scope of chapter

'6-77-2 Definitions

'6-77-3 Incorporation by reference

Subchapter 2 Annual Reports, Incident Reports, and Safety-Related Condition Reports

'6-77-4 Telephonic notice of certain

incidents

'6-77-5 Addressee for written reports

'6-77-6 Distribution system: incident report

'6-77-7 Distribution system: annual report

'6-77-8 Distribution systems reporting:

transmission pipelines,

transmission, or gathering systems

reporting distribution pipelines

'6-77-9 Transmission and gathering systems:

incident report

'6-77-10 Transmission and gathering systems:

annual report

'6-77-11 Report forms

'6-77-12 Reporting safety-related conditions

'6-77-13 Filing safety-related condition

reports

Subchapter 3 Minimum Safety Standards - General

'6-77-14 Class locations

'6-77-15 Gathering lines

'6-77-16 Petroleum gas systems

'6-77-17 General

'6-77-18 Conversion to service subject to this chapter

Subchapter 4 Minimum Safety Standards - Materials

'6-77-19 Scope

'6-77-20 General

'6-77-21 Steel pipe

'6-77-22 (Reserved)

'6-77-23 Plastic pipe

'6-77-24 (Reserved)

'6-77-25 Marking of materials

'6-77-26 Transportation of pipe

Subchapter 5 Minimum Safety Standards - Pipe Design

'6-77-27 Scope

'6-77-28 General

'6-77-29 Design formula for steel pipe

'6-77-30 Yield strength (S) for steel pipe

'6-77-31 Nominal wall thickness (t) for steel

pipe

'6-77-32 Design factor (F) for steel pipe

'6-77-33 Longitudinal joint factor (E) for

steel pipe

'6-77-34 Temperature derating factor (T) for

steel pipe

'6-77-35 (Reserved)

'6-77-36 (Reserved)

'6-77-37 Design of plastic pipe

'6-77-38 Design limitations for plastic pipe

'6-77-39 Design of copper pipe

Subchapter 6 Minimum Safety Standards - Design of Pipeline Components

'6-77-40 Scope

'6-77-41 General requirements

'6-77-42 Qualifying metallic components

'6-77-43 Valves

'6-77-44 Flanges and flange accessories

'6-77-45 Standard fittings

'6-77-46 Tapping

'6-77-47 Components fabricated by welding

'6-77-48 Welded branch connections

'6-77-49 Extruded outlets

'6-77-50 Flexibility

'6-77-51 Supports and anchors

'6-77-52 Compressor stations: design

and construction

'6-77-53 Compressor stations: liquid removal

'6-77-54 Compressor stations: emergency

shutdown

'6-77-55 Compressor stations: pressure

limiting devices

'6-77-56 Compressor stations: additional

safety equipment

'6-77-57 Compressor stations: ventilation

'6-77-58 Pipe-type and bottle-type holders

'6-77-59 Additional provisions for bottle-type

holders

'6-77-60 Transmission line valves

'6-77-61 Distribution line valves

'6-77-62 Vaults: structural design

requirements

'6-77-63 Vaults: accessibility

'6-77-64 Vaults: sealing, venting, and

ventilation

'6-77-65 Vaults: drainage and waterproofing

'6-77-66 Design pressure of plastic fillings

'6-77-67 Valve installation in plastic pipe

'6-77-68 Protection against accidental

overpressuring

'6-77-69 Control of the pressure of gas

delivered from high-pressure

distribution systems

'6-77-70 Requirements for design of pressure

relief and limiting devices

'6-77-71 Required capacity of pressure

relieving and limiting stations

'6-77-72 Instrument, control, and sampling

pipe and components

Subchapter 7 Minimum Safety Standards - Welding of Steel in Pipelines

'6-77-73 Scope

'6-77-74 Welding-general

'6-77-75 Qualification of welders

'6-77-76 Limitations on welders

'6-77-77 Protection from weather

'6-77-78 Miter joints

'6-77-79 Preparation for welding

'6-77-80 Inspection and test of welds

'6-77-81 Nondestructive testing

'6-77-82 Repair or removal of defects

Subchapter 8 Minimum Safety Standards - Joining of Materials Other Than By Welding

'6-77-83 Scope

'6-77-84 General

'6-77-85 Cast iron pipe

'6-77-86 Ductile iron pipe

'6-77-87 Copper pipe

'6-77-88 Plastic pipe

'6-77-89 Plastic pipe; qualifying joining

procedures

'6-77-90 Plastic pipe; qualifying persons to

make joints

'6-77-91 Plastic pipe; inspection of joints

Subchapter 9 Minimum Safety Standards - General Construction Requirements for Transmission Lines and Mains

'6-77-92 Scope

'6-77-93 Compliance with specifications

or standards

'6-77-94 Inspection: general

'6-77-95 Inspection of materials

'6-77-96 Repair of steel pipe

'6-77-97 Repair of plastic pipe

'6-77-98 Bends and elbows

'6-77-99 Wrinkle bends in steel pipe

'6-77-100 Protection from hazards

'6-77-101 Installation of pipe in a ditch

'6-77-102 Installation of plastic pipe

'6-77-103 Casing

'6-77-104 Underground clearance

'6-77-105 Cover

Subchapter 10 Customer Meters, Service Regulators, and Service Lines

'6-77-106 Scope

'6-77-107 Customer meters and regulators:

location

'6-77-108 Customer meters and regulators:

protection from damage

'6-77-109 Customer meters and regulators:

installation

'6-77-110 Customer meter installations:

operating pressure

'6-77-111 Service lines: installation

'6-77-112 Service lines: valve requirements

'6-77-113 Service lines: location of valves

'6-77-114 Service lines: general requirements

for connections to main piping

'6-77-115 Service lines: connections to cast

iron or ductile iron mains

'6-77-116 Service lines: steel

'6-77-117 Service lines: cast iron and ductile

iron

'6-77-118 Service lines: plastic

'6-77-119 Service lines: copper

'6-77-120 New service lines not in use

Subchapter 11 Minimum Safety Standards - Requirements for Corrosion Control

'6-77-121 Scope

'6-77-122 Applicability to converted pipelines

'6-77-123 General

'6-77-124 External corrosion control: buried

or submerged pipelines installed

after July 31, 1971

'6-77-125 External corrosion control: buried

or submerged pipelines installed

before August 1, 1971

'6-77-126 External corrosion control:

examination of buried pipeline when

exposed

'6-77-127 External corrosion control:

protective coating

'6-77-128 External corrosion control: cathodic

protection

'6-77-129 External corrosion control:

monitoring

'6-77-130 External corrosion control:

electrical isolation

'6-77-131 External corrosion control: test

stations

'6-77-132 External corrosion control: test

leads

'6-77-133 External corrosion control:

interference currents

'6-77-134 Internal corrosion control: general

'6-77-135 Internal corrosion control:

monitoring

'6-77-136 Atmospheric corrosion control:

general

'6-77-137 Atmospheric corrosion control:

monitoring

'6-77-138 Remedial measures: general

'6-77-139 Remedial measures: transmission

lines

'6-77-140 Remedial measures: distribution

lines other than cast iron or

ductile iron lines

'6-77-141 Remedial measures: cast iron and

ductile iron pipelines

'6-77-142 Corrosion control records

Subchapter 12 Test Requirements

'6-77-143 Scope

'6-77-144 General requirements

'6-77-145 Strength test requirements for steel

pipeline to operate at a hoop

stress of thirty percent or more of

SMYS

'6-77-146 Test requirements for pipelines to

operate at a hoop stress less than

thirty percent of SMYS and at or

above 100 p.s.i.g.

'6-77-147 Test requirements for pipelines to

operate below 100 p.s.i.g.

'6-77-148 Test requirements for service lines

'6-77-149 Test requirements for plastic

pipelines

'6-77-150 Environmental protection and safety

requirements

'6-77-151 Records

Subchapter 13 Uprating

'6-77-152 Scope

'6-77-153 General requirements

'6-77-154 Uprating to a pressure that will

produce a hoop stress of thirty

percent or more of SMYS in steel

pipelines

'6-77-155 Uprating: steel pipelines to a

pressure that will produce a hoop

stress less than thirty percent of

SMYS: plastic, cast iron, and

ductile iron pipelines

Subchapter 14 Operations

'6-77-156 Scope

'6-77-157 General provisions

'6-77-158 Essentials of operating and

maintenance plan

'6-77-159 Initial determination of class

location and confirmation or

establishment of maximum allowable

operating pressure

'6-77-160 Change in class location: required

study

'6-77-161 Change in class location:

confirmation or revision of maximum

allowable operating pressure

'6-77-162 Continuing surveillance

'6-77-163 Damage prevention program

'6-77-164 Emergency plans

'6-77-165 Investigation of failures

'6-77-166 Maximum allowable operating

pressure: steel or plastic

pipelines

'6-77-167 Maximum allowable operating pressure:

high-pressure distribution systems

'6-77-168 Maximum and minimum allowable

operating pressure: low-pressure

distribution systems

'6-77-169 Odorization of gas

'6-77-170 Tapping pipelines under pressure

'6-77-171 Purging of pipelines

Subchapter 15 Maintenance

'6-77-172 Scope

'6-77-173 General

'6-77-174 Transmission lines: patrolling

'6-77-175 Transmission lines: leakage surveys

'6-77-176 Line markers for mains and

transmission lines

'6-77-177 Transmission lines: record keeping

'6-77-178 Transmission lines: general

requirements for repair procedures '6-77-179 Transmission lines: permanent field

repair of imperfections and damages

'6-77-180 Transmission lines: permanent field

repair of welds

'6-77-181 Transmission lines: permanent field

repair of leaks

'6-77-182 Transmission lines: testing of

repairs

'6-77-183 Distribution systems: patrolling

'6-77-184 Distribution systems: leakage

surveys and procedures

'6-77-185 Test requirements for reinstating

service lines

'6-77-186 Abandonment or inactivation of

facilities

'6-77-187 Compressor stations: procedures for

gas compressor units

'6-77-188 Compressor stations: inspection and

testing of relief devices

'6-77-189 Compressor stations: isolation of

equipment for maintenance or

alterations

'6-77-190 Compressor stations: storage of

combustible materials

'6-77-191 Pipe-type and bottle-type holders:

plan for inspection and testing

'6-77-192 Pressure limiting and regulating

stations: inspection and testing

'6-77-193 Pressure limiting and regulating

stations: telemetering or

recording gauges

'6-77-194 Pressure limiting and regulating

stations: testing of relief

devices

'6-77-195 Valve maintenance: transmission

lines

'6-77-196 Valve maintenance: distribution

systems

'6-77-197 Vault maintenance

'6-77-198 Prevention of accidental ignition

'6-77-199 Caulked bell and spigot joints

'6-77-200 Protecting cast-iron pipelines

Appendix A Incorporated by Reference

Appendix B Qualification of Pipe

Appendix C Qualification of Welders for Low

Stress Level Pipe

Appendix D Criteria for Cathodic Protection

and Determination of Measurements

'6-77-1

Historical note: This chapter is substantially based upon Parts 191 and 192, 49 Code of Federal Regulations (October 1, 1990 edition).

Subchapter 1

General

'6-77-1 Scope of chapter. (a) This chapter prescribes minimum safety requirements for pipeline facilities and the transportation of gas, including pipeline facilities and the transportation of gas within the limits of the outer continental shelf as that term is defined in the Outer Continental Shelf Lands Act (43 U.S.C. 1331).

(b) This chapter does not apply to:

(1) Offshore gathering of gas upstream from the outlet flange of each facility on the outer continental shelf where hydrocarbons are produced or where produced hydrocarbons are first separated, dehydrated, or otherwise processed, whichever facility is farther downstream; and

(2) Onshore gathering of gas outside of the following areas:

(A) An area within the limits of any incorporated or unincorporated city, town, or village;

(B) Any designated residential or commercial area such as a subdivision, business or shopping center, or community development. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '191.1, October 1, 1990 edition)

'6-77-2

'6-77-2 Definitions.

"Commission" means the public utilities commission of the State or any person to whom it has delegated authority in the matter concerned.

"Distribution line" means a pipeline other than a gathering or transmission line.

"Gas" means natural gas, flammable gas, or gas which is toxic or corrosive.

"Gathering line" means a pipeline that transports gas from a current production facility to a transmission line or main.

"High pressure distribution system" means a distribution system in which the gas pressure in the main is higher than the pressure provided to the customer.

"Incident" means any of the following events:

(1) An event that involves a release of gas from a pipeline or of liquefied natural gas or gas from an LNG facility and

(A) A death, or personal injury necessitating in-patient hospitalization; or

(B) Estimated property damage, including cost of gas lost, of the operator or others, or both, of $50,000 or more.

(2) An event that results in an emergency shutdown of an LNG facility;

(3) An event that is significant, in the judgement of the operator, even though it did not meet the criteria of paragraphs (1) or (2).

"Listed specification" means a specification listed in section I of Appendix B of this chapter.

"LNG facility" means a liquefied natural gas facility as defined in section 193.2007 of Part 193 of the Code of Federal Regulations (C.F.R.).

"Low-pressure distribution system" means a distribution system in which the gas pressure in the main is substantially the same as the pressure provided to the customer.

'6-77-2

"Main" means a distribution line that serves as a common source of supply for more than one service line.

"Master meter system" means a pipeline system for distributing gas within, but not limited to, a definable area, such as a mobile home park, housing project, or apartment complex, where the operator purchases metered gas from an outside source for resale through a gas distribution pipeline system. The gas distribution pipeline system supplies the ultimate consumer who either purchases the gas directly through a meter or by other means, such as by rents.

"Maximum actual operating pressure" means the maximum pressure that occurs during normal operations over a period of one year.

"Maximum allowable operating pressure (MAOP)" means the maximum pressure at which a pipeline may be operated under this chapter.

"Municipality" means a city, county, or any other political subdivision of a state.

"Offshore" means beyond the line of ordinary low water along that portion of the coast of the United States that is in direct contact with the open seas and beyond the line marking the seaward limit of inland waters.

"Operator" means a person who engages in the transportation of gas.

"Person" means any individual, firm, joint venture, partnership, corporation, association, state, municipality, cooperative association, or joint stock association, and including any trustee, receiver, assignee, or personal representative thereof.

"Pipe" means any pipe or tubing used in the transportation of gas, including pipe-type holders.

"Pipeline" or "pipeline system" means all parts of those physical facilities through which gas moves in transportation, including, but not limited to, pipe, valves, and other appurtenances attached to pipes, compressor units, metering stations,

'6-77-2

regulator stations, delivery stations, holders, and fabricated assemblies.

"Pipeline facility" means new and existing pipelines, rights-of-way, and any equipment, facility, or building used in the transportation of gas or in the treatment of gas during the course of transportation.

"Service line" means a distribution line that transports gas from a common source of supply to

(1) A customer meter or the connection to a customer's piping, whichever is farther downstream; or

(2) The connection to a customer's piping if there is no customer meter. A customer meter is the meter that measures the transfer of gas from an operator to a consumer.

"SMYS" means specified minimum yield strength is:

(1) For steel pipe manufactured in accordance with an unknown or unlisted specification, the yield strength determined in accordance with section 6-77-30(b);

(2) For steel pipe manufactured in accordance with an unknown or unlisted specification, the yield strength determined in accordance with section 6-77-30(b).

"State" means the State of Hawaii.

"Transmission line" means a pipeline, other than a gathering line, that:

(1) Transports gas from a gathering line or storage facility to a distribution center or storage facility;

(2) Operates at a hoop stress of twenty percent or more SMYS; or

(3) Transports gas within a storage field.

"Transportation of gas" means the gathering, transmission, or distribution of gas by pipeline or the storage of gas, in or affecting interstate or foreign commerce. [Eff ] (Auth:

'6-77-2

HRS '269-6) (Imp: 49 C.F.R. ''191.3, 192.3; October 1, 1990)

'6-77-3 Incorporation by reference. (a) Any documents or parts thereof incorporated by reference in this chapter are a part of this chapter as though set out in full.

(b) All incorporated documents are available for inspection at the commission's office at 465 South King Street, Room 103, Honolulu, HI, in the Research and Special Programs Administration, Washington, D.C., or at the Office of the Federal Register, 1100 L Street, N.W., Washington, D.C. In addition, the documents are available at the addresses provided in Appendix A.

(c) The full titles for the publications incorporated by reference are provided in Appendix A. Numbers in parentheses indicate applicable editions. Earlier editions of documents listed in Appendix A or documents formerly listed in the commission's General Order No. 9 may be used for materials and components manufactured, designed, or installed in accordance with those earlier editions or earlier documents at the time they were listed. The appropriate previous edition of 49 C.F.R. shall be referred to for a listing of the earlier listed editions or documents in Appendix A. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.7, October 1, 1990)

'6-77-5

Subchapter 2

Annual Reports, Incident Reports and

Safety-Related Condition Reports

'6-77-4 Telephonic notice of certain incidents. (a) At the earliest practicable moment following discovery, each operator shall give notice in accordance with subsection (b) of each incident as defined in section 6-77-2.

(b) Each notice required by subsection (a) shall be made by telephone to the commission at (808) 586-2020 and to the U.S. Department of Transportation at (800) 424-8802. Both notices shall include the following information:

(1) Names of operator and person making report and their telephone numbers;

(2) The location of the incident;

(3) The time of the incident;

(4) The number of fatalities and personal injuries, if any;

(5) All other significant facts that are known by the operator that are relevant to the cause of the incident or extent of the damages. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '191.5, October 1, 1990)

'6-77-5 Addressee for written reports. Each written report required by this chapter must be made to the commission with further transmittal of a copy within ten days for incident reports and not later than March 15 for annual reports to the Information Resources Manager, Office of Pipeline Safety, Research and Special Programs Administration, U.S. Department of Transportation, Room 8417, 400 Seventh Street S.W., Washington, DC 20590.

'6-77-5

Safety‑related condition reports required by section 6‑77-12 and 49 C.F.R. '191.23 for intrastate pipeline transportation must be submitted concurrently to the commission, and to the Information Resources Manager, Office of Pipeline Safety, Research and Special Programs Administration, U.S. Department of Transportation, at the address stated above. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '191.7, October 1, 1990)

'6-77-6 Distribution system: incident report. (a) Except as provided in subsection (c), each operator of a distribution pipeline system shall submit Department of Transportation Form RSPA F 7100.1 as soon as practicable but not more than thirty days after detection of an incident required to be reported under section 6‑77-4 and 49 C.F.R. '191.5.

(b) When additional relevant information is obtained after the report is submitted under subsection (a), the operator shall make supplementary reports as deemed necessary with a clear reference by date and subject to the original report.

(c) The incident report required by this section need not be submitted with respect to master meter systems or LNG facilities. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '191.9, October 1, 1990)

'6-77-7 Distribution system: annual report. (a) Except as provided in subsection (b), each operator of a distribution pipeline system shall submit an annual report for that system on Department of Transportation Form RSPA F 7100.1-1. This report must be submitted each year, not later than March 15, for the preceding calendar year.

'6-77-9

(b) The annual report required by this section need not be submitted with respect to:

(1) Petroleum gas systems which serve fewer than 100 customers from a single source;

(2) Master meter systems; or

(3) LNG facilities. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '191.11, October 1, 1990)

'6-77-8 Distribution systems reporting: transmission pipelines, transmission or gathering systems reporting distribution pipelines. Each operator, primarily engaged in gas distribution, who also operates gas transmission or gathering pipelines shall submit separate reports for these pipelines as required by sections 6-77-9 and 6‑77‑10 and 49 C.F.R. ''191.15 and 191.17. Each operator, primarily engaged in gas transmission or gathering, who also operates gas distribution pipelines, shall submit separate reports for these pipelines as required by sections 6-77-6 and 6-77-7 and 49 C.F.R. ''191.9 and 191.11. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '191.13, October 1, 1990)

'6-77-9 Transmission and gathering systems: incident report. (a) Except as provided in subsection (c), each operator of a transmission or a gathering pipeline system shall submit Department of Transportation Form RSPA F 7100.2 as soon as practicable but not more than thirty days after detection of an incident required to be reported under section 6-77-4 and 49 C.F.R. '191.5.

(b) Where additional related information is obtained after a report is submitted under subsection (a), the operator shall make a

'6-77-9

supplemental report as soon as practicable with a clear reference by date and subject to the original report.

(c) The incident report required by subsection (a) need not be submitted with respect to LNG facilities. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '191.15, October 1, 1990)

'6-77-10 Transmission and gathering systems: annual report. (a) Except as provided in subsection (b), each operator of a transmission or a gathering pipeline system shall submit an annual report to the commission and the U.S. Department of Transportation for that system on Department of Transportation Form RSPA 7100.2‑1. This report must be submitted each year, not later than March 15, for the preceding calendar year.

(b) The annual report required by subsection (a) need not be submitted with respect to LNG facilities. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '191.17, October 1, 1990)

'6-77-11 Report forms. Copies of the prescribed report forms are available without charge upon request from the commission. Additional copies in this prescribed format may be reproduced and used if the same size and kind of paper is used. In addition, the information required by these forms may be submitted by any other means that is acceptable to the commission. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '191.19, October 1, 1990)

'6-77-12 Reporting safety-related conditions. (a) Except as provided in subsection (b), each

'6-77-12

operator shall report in accordance with section 6‑77‑13 and 49 C.F.R. '191.25 the existence of any of the following safety-related conditions involving facilities in service:

(1) In the case of a pipeline (other than an LNG facility) that operates at a hoop stress of twenty percent or more of its specified minimum yield strength, general corrosion that has reduced the wall thickness to less than that required for the maximum allowable operating pressure, and localized corrosion pitting to a degree where leakage might result;

(2) Unintended movement or abnormal loading by environmental causes, such as an earthquake, landslide, or flood, that impairs the serviceability of a pipeline or the structural integrity or reliability of an LNG facility that contains, controls, or processes gas or LNG;

(3) Any crack or other material defect that impairs the structural integrity or reliability of an LNG facility that contains, controls, or processes gas or LNG;

(4) Any material defect or physical damage that impairs the serviceability of a pipeline that operates at a hoop stress of twenty percent or more of its specified minimum yield strength;

(5) Any malfunction or operating error that causes the pressure of a pipeline or LNG facility that contains or processes gas or LNG to rise above its maximum allowable operating pressure (or working pressure for LNG facilities) plus the build-up allowed for operation of pressure limiting or control devices;

(6) A leak in a pipeline or LNG facility that contains or processes gas or LNG that constitutes an emergency;

'6-77-12

(7) Inner tank leakage, ineffective insulation, or frost heave that impairs the structural integrity of an LNG storage tank;

(8) Any safety-related condition that could lead to an imminent hazard and causes (either directly or indirectly by remedial action of the operator), for purposes other than abandonment, a twenty percent or more reduction in operating pressure or shutdown of operation of a pipeline or an LNG facility that contains or processes gas or LNG.

(b) A report is not required for any safety‑related condition that:

(1) Exists on a master meter system or a customer‑owned service line;

(2) Is an incident or results in an incident before the deadline for filing the safety‑related condition report;

(3) Exists on a pipeline (other than an LNG facility) that is more than 220 yards from any building intended for human occupancy or outdoor place of assembly, except that reports are required for conditions within the right‑of-way of an active railroad, paved road, street, or highway; or

(4) Is corrected by repair or replacement in accordance with applicable safety standards before the deadline for filing the safety‑related condition report, except that reports are required for conditions under subsection (a)(1) other than localized corrosion pitting on an effectively coated and cathodically protected pipeline. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '191.23, October 1, 1990)

'6-77-13

'6-77-13 Filing safety-related condition reports. (a) Each report of safety-related condition under section 6-77-12(a) must be filed (received by the commission) in writing within five working days (not including Saturdays, Sundays, or federal holidays) after the day a representative of the operator first determines that the condition exists, but not later than ten working days after the day a representative of the operator discovers the condition. Separate conditions may be described in a single report if they are closely related.

(b) The report must be headed "Safety-Related Condition Report" and provide the following information:

(1) Name and principal address of operator;

(2) Date of report;

(3) Name, job title, and business telephone number of person submitting the report;

(4) Name, job title, and business telephone number of person who determined that the condition exists;

(5) Date condition was discovered and date condition was first determined to exist;

(6) Location of condition, with reference to the State (and town, city, or county) or offshore site, and as appropriate, nearest street address, offshore platform, survey station number, milepost, landmark, or name of pipeline;

(7) Description of the condition, including circumstances leading to its discovery, any significant effects of the condition on safety, and the name of the commodity transported or stored;

(8) The corrective action taken (including reduction of pressure or shutdown) before the report is submitted and the planned follow-up or future corrective action, including the anticipated schedule for starting and concluding such action.

'6-77-13

[Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '191.25, October 1, 1990)

Subchapter 3

Minimum Safety Standards - General

'6-77-14 Class locations. (a) Offshore is Class 1 location. The class location onshore is determined by applying the criteria set forth in this section: The class location unit is an area that extends 220 yards on either side of the centerline of any continuous one-mile length of pipeline. Except as provided in subsections (d)(2) and (f), the class location is determined by the buildings in the class location unit. For the purposes of this section, each separate dwelling unit in a multiple dwelling unit building is counted as a separate building intended for human occupancy.

(b) A Class 1 location is any class location unit that has ten or less buildings intended for human occupancy.

(c) A Class 2 location is any class location unit that has more than ten but less than forty‑six buildings intended for human occupancy.

(d) A Class 3 location is:

(1) Any class location unit that has forty‑six or more buildings intended for human occupancy;

(2) An area where the pipeline lies within 100 yards of either a building or a small, well‑defined outside area (such as a playground, recreation area, outdoor theater, or other place of public assembly) that is occupied by twenty or more persons on at least five days a week for ten weeks in any twelve‑month period.

'6-77-16

(The days and weeks need not be consecutive.)

(e) A Class 4 location is any class location unit where buildings with four or more stories above ground are prevalent.

(f) The boundaries of the class locations determined in accordance with subsections (a) through (e) may be adjusted as follows:

(1) A Class 4 location ends 220 yards from the nearest building with four or more stories above ground;

(2) When a cluster of buildings intended for human occupancy requires a Class 3 location, the Class 3 location ends 220 yards from the nearest building in the cluster;

(3) When a cluster of buildings intended for human occupancy requires a Class 2 location, the Class 2 location ends 220 yards from the nearest building in the cluster. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.5, October 1, 1990)

'6-77-15 Gathering lines. Each gathering line must comply with the requirements of this chapter applicable to transmission lines. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.9, October 1, 1990)

'6-77-16 Petroleum gas systems. (a) No operator may transport petroleum gas in a system that services ten or more customers, or in a system, any portion of which is located in a public place (such as a highway), unless that system meets the requirements of this chapter and of NFPA Standards No. 58 and No. 59. In the event of a conflict, the requirements of this chapter prevail.

'6-77-16

(b) Each petroleum gas system covered by subsection (a) must comply with the following:

(1) Aboveground structures must have open vents near the floor level;

(2) Belowground structures must have forced ventilation that will prevent any accumulation of gas;

(3) Relief valve discharge vents must be located so as to prevent any accumulation of gas at or below ground level;

(4) Special precautions must be taken to provide adequate ventilation where excavations are made to repair an underground system.

(c) For the purpose of this section, petroleum gas means propane, butane, or mixtures of these gases, other than a gas air mixture that is used to supplement supplies in a natural gas distribution system. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.11, October 1, 1990)

'6-77-17 General. (a) No person may operate a segment of pipeline that is readied for service after March 12, 1971, or in the case of an offshore gathering line, after July 31, 1977, unless:

(1) The pipeline has been designed, installed, constructed; initially inspected, and initially tested in accordance with this chapter; or

(2) The pipeline qualifies for use under this chapter in accordance with section 6‑77‑18.

(b) No person may operate a segment of pipeline that is replaced, relocated, or otherwise changed after November 12, 1970, or in the case of an offshore gathering line, after July 31, 1977, unless that replacement, relocation, or change has been made in accordance with this chapter.

'6-77-18

programs that it is required to establish under this chapter. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.13, October 1, 1990)

'6-77-18 Conversion to service subject to this chapter. (a) A steel pipeline previously used in service not subject to this chapter qualifies for use under this chapter if the operator prepares and follows a written procedure to carry out the following requirements:

(1) The design, construction, operation, and maintenance history of the pipeline must be reviewed and, where sufficient historical records are not available, appropriate tests must be performed to determine if the pipeline is in a satisfactory condition for safe operation;

(2) The pipeline right-of-way, all aboveground segments of the pipeline, and appropriately selected underground segments must be visually inspected for physical defects and operating conditions which reasonably could be expected to impair the strength or tightness of the pipeline;

(3) All known unsafe defects and conditions must be corrected in accordance with this chapter;

(4) The pipeline must be tested in accordance with subchapter 12 to substantiate the maximum allowable operating pressure permitted by subchapter 14.

(b) Each operator must keep for the life of the pipeline a record of the investigations, tests, repairs, replacements, and alterations made under the requirements of subsection (a). [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.14, October 1, 1990)

'6-77-19

Subchapter 4

Minimum Safety Standards - Materials

'6-77-19 Scope. This subchapter prescribes minimum requirements for the selection and qualification of pipe and components for use in pipelines. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.51, October 1, 1990)

'6-77-20 General. Materials for pipe and components must be:

(1) Able to maintain the structural integrity of the pipeline under temperature and other conditions that may be anticipated;

(2) Chemically compatible with any gas that they transport and with any other material in the pipeline with which they are in contact; and

(3) Qualified in accordance with the applicable requirements of this subchapter. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.53, October 1, 1990)

'6-77-21 Steel pipe. (a) New steel pipe is qualified for use under this chapter if:

(1) It was manufactured in accordance with a listed specification;

(2) It meets the requirements of:

(A) Section II of Appendix B; or

(B) If it was manufactured before November 12, 1970, either section II or III of Appendix B;

(3) It is used in accordance with subsection (c) or (d).

'6-77-22

(b) Used steel pipe is qualified for use under this chapter if:

(1) It was manufactured in accordance with a listed specification and it meets the requirements of paragraph II-C of Appendix B; or

(2) It meets the requirements of:

(A) Section II of Appendix B; or

(B) If it was manufactured before November 12, 1970, either section II or III of Appendix B;

(3) It has been used in an existing line of the same or higher pressure and meets the requirements of paragraph II-C of Appendix B; or

(4) It is used in accordance with subsection (c).

(c) New or used steel pipe may be used at a pressure resulting in a hoop stress of less than 6,000 p.s.i. where no close coiling or close bending is to be done, if visual examination indicates that the pipe is in good condition and that it is free of split seams and other defects that would cause leakage. If it is to be welded, steel pipe that has not been manufactured to a listed specification must also pass the weldability tests prescribed in paragraph II-B of Appendix B.

(d) Steel pipe that has not been previously used may be used as replacement pipe in a segment of pipeline if it has been manufactured prior to November 12, 1970, in accordance with the same specifications as the pipe used in constructing that segment of pipeline.

(e) New steel pipe that has been cold expanded must comply with the mandatory provisions of API Standard 5L. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.55, October 1, 1990)

'6-77-22 (Reserved)

'6-77-23

'6-77-23 Plastic pipe. (a) New plastic pipe is qualified for use under this chapter if:

(1) It is manufactured in accordance with a listed specification; and

(2) It is resistant to chemicals with which contact may be anticipated.

(b) Used plastic pipe is qualified for use under this chapter if:

(1) It was manufactured in accordance with a listed specification;

(2) It is resistant to chemicals with which contact may be anticipated;

(3) It has been used only in natural gas service;

(4) Its dimensions are still within the tolerances of the specification to which it was manufactured; and

(5) It is free of visible defects.

(c) For the purpose of subsections (a)(1) and (b)(1), where pipe of a diameter included in a listed specification is impractical to use, pipe of a diameter between the sizes included in a listed specification may be used if it:

(1) Meets the strength and design criteria required of pipe included in that listed specification; and

(2) Is manufactured from plastic compounds which meet the criteria for material required of pipe included in that listed specification. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.59, October 1, 1990)

'6-77-24 (Reserved)

'6-77-25 Marking of materials. (a) Except as provided in subsection (d), each valve, fitting, length of pipe, and other component must be marked:

'6-77-26

(1) As prescribed in the specification or standard to which it was manufactured; or

(2) To indicate size, material, manufacturer, pressure rating, and temperature rating, and as appropriate, type, grade, and model.

(b) Surfaces of pipe and components that are subject to stress from internal pressure may not be field die stamped.

(c) If any item is marked by die stamping, the die must have blunt or rounded edges that will minimize stress concentrations.

(d) Subsection (a) does not apply to items manufactured before November 12, 1970, that meet all of the following:

(1) The item is identifiable as to type, manufacturer, and model.

(2) Specifications or standards giving pressure, temperature, and other appropriate criteria for the use of items are readily available.

[Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.63, October 1, 1990)

'6-77-26 Transportation of pipe. In a pipeline to be operated at a hoop stress of twenty percent or more of SMYS, an operator may not use pipe having an outer diameter to wall thickness ratio of seventy to one, or more, that is transported by railroad unless:

(1) The transportation is performed in accordance with the 1972 edition of API RP5L1, except that before February 25, 1975, the transportation may be performed in accordance with the 1967 edition of API RP5L1.

(2) In the case of pipe transported before November 12, 1970, the pipe is tested in accordance with subchapter 12 to at least

'6-77-26

1.25 times the maximum allowable operating pressure if it is to be installed in a Class 1 location and to at least 1.5 times the maximum allowable operating pressure if it is to be installed in a Class 2, 3, or 4 location. Notwithstanding any shorter time period permitted under subchapter 12, the test pressure must be maintained for at least eight hours. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.65, October 1, 1990)

Subchapter 5

Minimum Safety Standards - Pipe Design

'6-77-27 Scope. This subchapter prescribes the minimum requirements for the design of pipe. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.101, October 1, 1990)

'6-77-28 General. Pipe must be designed with sufficient wall thickness, or must be installed with adequate protection, to withstand anticipated external pressures and loads that will be imposed on the pipe after installation. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.103, October 1, 1990)

'6-77-29 Design formula for steel pipe. (a) The design pressure for steel pipe is determined in accordance with the following formula:

'6-77-30

P=(2 St/D) x F x E x T

P = Design pressure in pounds per square inch gauge.

S = Yield strength in pounds per square inch determined in accordance with section 6-77-30.

D = Nominal outside diameter of the pipe in inches.

t = Nominal wall thickness of the pipe in inches. If this is unknown, it is determined in accordance with section 6-77-31. Additional wall thickness required for concurrent external loads in accordance with section 6-77-28 may not be included in computing design pressure.

F = Design factor determined in accordance with section 6-77-32.

E = Longitudinal joint factor determined in accordance with section 6-77-33.

T = Temperature derating factor determined in accordance with section 6-77-34.

(b) If steel pipe that has been subjected to cold expansion to meet the SMYS is subsequently heated, other than by welding or stress relieving as a part of welding, the design pressure is limited to seventy-five percent of the pressure determined under subsection (a) if the temperature of the pipe exceeds 900E F (482E C) at any time or is held above 600E F (316E C) for more than one hour. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.105, October 1, 1990)

'6-77-30 Yield strength (S) for steel pipe. (a) For pipe that is manufactured in accordance with a specification listed in section I of Appendix B, the yield strength to be used in the design formula in section 6-77-29 is the SMYS stated in the listed specification, if that value is known.

(b) For pipe that is manufactured in accordance with a specification not listed in

'6-77-30

section I of Appendix B or whose specification or tensile properties are unknown, the yield strength to be used in the design formula in section 6-77-29 is one of the following:

(1) If the pipe is tensile tested in accordance with section II.D. of Appendix B, the lower of the following:

(A) Eighty percent of the average yield strength determined by the tensile tests;

(B) The lowest yield strength determined by the tensile tests, but not more than 52,000 p.s.i.

(2) If the pipe is not tensile tested as provided in subsection (b)(1) 24,000 p.s.i. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.107, October 1, 1990)

'6-77-31 Nominal wall thickness (t) for steel pipe. (a) If the nominal wall thickness for steel pipe is not known, it is determined by measuring the thickness of each piece of pipe at quarter points on one end.

(b) However, if the pipe is of uniform grade, size, and thickness and there are more than ten lengths, only ten percent of the individual lengths, but not less than ten lengths, need be measured. The thickness of the lengths that are not measured must be verified by applying a gauge set to the minimum thickness found by the measurement. The nominal wall thickness to be used in the design formula in section 6-77-29 is the next wall thickness found in commercial specifications that is below the average of all the measurements taken. However, the nominal wall thickness used may not be more than 1.14 times the smallest measurement taken on pipe less than twenty inches in outside diameter, nor more than 1.11 times the smallest measurement taken on pipe twenty inches or more in outside

'6-77-32

diameter. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.109, October 1, 1990)

'6-77-32 Design factor (F) for steel pipe. (a) Except as otherwise provided in subsections (b), (c), and (d), the design factor to be used in the design formula in section 6-77-29 is determined in accordance with the following table:

________________________________________________________

Class location │ Design factor (F)

│

1 ................................│ 0.72

2 ................................│ 0.60

3 ................................│ 0.50

4 ................................│ 0.40

│

(b) A design factor of 0.60 or less must be used in the design formula in section 6-77-29 for steel pipe in Class 1 locations that:

(1) Crosses the right-of-way of an unimproved public road, without a casing;

(2) Crosses without a casing, or makes a parallel encroachment on the right-of-way of either a hard surfaced road, a highway, a public street, or a railroad;

(3) Is supported by a vehicular, pedestrian, railroad, or pipeline bridge; or

(4) Is used in a fabricated assembly, (including separators, mainline valve assemblies, cross‑connections, and river crossing headers) or is used within five pipe diameters in any direction from the last fitting of a fabricated assembly, other than a transition piece or an elbow used in place of a pipe bend which is not associated with a fabricated assembly.

(c) For Class 2 locations, a design factor of 0.50, or less, must be used in the design formula in section 6‑77-29 for uncased steel pipe that crosses

'6-77-32

the right‑of‑way of a hard surfaced road, a highway, a public street, or a railroad.

(d) For Class 1 and Class 2 locations, a design factor of 0.50, or less, must be used in the design formula in section 6-77-29 for:

(1) Steel pipe in a compressor station, regulating station, or measuring station; and

(2) Steel pipe, including a pipe riser, on a platform located offshore or in inland navigable waters. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.111, October 1, 1990)

'6-77-33 Longitudinal joint factor (E) for steel pipe. The longitudinal joint factor to be used in the design formula in section 6-77-29 is determined in accordance with the following table:

_________________________________________________________________________________

│ │ Longitudinal

│ │ Joint Factor

Specification │ Pipe class │ (E)

________________│______________________________________________│_____________

│ │

ASTM A 53 ......│ Seamless ....................................│ 1.00

│ Electric resistance welded ..................│ 1.00

│ Furnace butt welded .........................│ .60

ASTM A 106 .....│ Seamless ....................................│ 1.00

ASTM A 333 .....│ Seamless ....................................│ 1.00

│ Electric resistance welded ..................│ 1.00

ASTM A 381 .....│ Double submerged arc welded .................│ 1.00

ASTM A 671 .....│ Electric-fusion-welded ......................│ 1.00

ASTM A 672 .....│ Electric-fusion-welded ......................│ 1.00

ASTM A 691 .....│ Electric-fusion-welded ......................│ 1.00

API 5L .........│ Seamless ....................................│ 1.00

│ Electric resistance welded ..................│ 1.00

│ Electric flash welded .......................│ 1.00

│ Submerged arc welded ........................│ 1.00

│ Furnace butt welded .........................│ .60

Other ..........│ Pipe over 14 inches .........................│ .80

Other ..........│ Pipe 4 inches or less .......................│ .60

│ │

'6-77-37

If the type of longitudinal joint cannot be determined, the joint factor to be used must not exceed that designated for "Other." [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.113, October 1, 1990)

'6-77-34 Temperature derating factor (T) for steel pipe. The temperature derating factor to be used in the design formula in section 6-77-29 is determined as follows:

_____________________________________________________________________

│Temperature

│derating

Gas temperature in degrees Fahrenheit │factor (T)

│

250 or less .............................................│ 1.000

300 .....................................................│ 0.967

350 .....................................................│ 0.933

400 .....................................................│ 0.900

450 .....................................................│ 0.867

│

For intermediate gas temperatures, the derating factor is determined by interpolation. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.115, October 1, 1990)

'6-77-35 (Reserved)

'6-77-36 (Reserved)

'6-77-37 Design of plastic pipe. The design pressure for plastic pipe is determined in accordance with the following formula, subject to the limitations of section 6-77-38:

'6-77-37

P = 2S x 0.32

D-t

P = Design pressure, gage, kPa (psi).

S = For thermoplastic pipe the long-term hydrostatic strength determined in accordance with the listed specification at a temperature equal to 23E C (73E F), 38E C (100E F), 49E C (120E F), or 60E C (140E F) for reinforced thermosetting plastic pipe, 75,800 kPa (11,000 p.s.i.).

t = Specified wall thickness, mm (in.).

D = Specified outside diameter, mm (in.).

[Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.121, October 1, 1990)

'6-77-38 Design limitations for plastic pipe. (a) The design pressure may not exceed a gauge pressure of 689 kPa (100 p.s.i.g.) for plastic pipe used in:

(1) Distribution systems; or

(2) Class 3 and 4 locations.

(b) Plastic pipe may not be used where operating temperatures of the pipe will be:

(1) Below minus 29E C (-20E F); or

(2) In the case of thermoplastic pipe, above the temperature at which the long-term hydrostatic strength used in the design formula under '6‑77-34 is determined, except that pipe manufactured before May 18, 1978, may be used at temperatures up to 38E C (100E F); or in the case of reinforced thermosetting plastic pipe, above 66E C (150E F).

(d) The wall thickness for reinforced thermosetting plastic pipe may not be less than that listed in the following table:

'6-77-39

__________________________________________________________________

│ Minimum wall thickness

Nominal size in inches │ in millimeters (inches)

│

2 .......................................│ 1.52 (0.060)

3 .......................................│ 1.52 (0.060)

4 .......................................│ 1.78 (0.070)

6 .......................................│ 2.54 (0.100)

│

[Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.123, October 1, 1990)

'6-77-39 Design of copper pipe. (a) Copper pipe used in mains must have a minimum wall thickness of 0.065 inch and must be hard drawn.

(b) Copper pipe used in service lines must have wall thickness not less than that indicated in the following table:

____________________________________________________________________

│ │ Wall thickness (inch)

Standard │ Nominal O.D. │_________________________________

size (inch) │ (inch) │ Nominal │ Tolerance

│ │ │

2 │ .625 │ .040 │ .0035

5/8 │ .750 │ .042 │ .0035

3/4 │ .875 │ .045 │ .004

1 │ 1.125 │ .050 │ .004

1-1/4 │ 1.375 │ .055 │ .0045

1-1/2 │ 1.625 │ .060 │ .0045

│ │ │

(d) Copper pipe that does not have an internal corrosion resistant lining may not be used to carry gas that has an average hydrogen sulfide content of more than 0.3 grains per 100 standard cubic feet of gas. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.125, October 1, 1990)

'6-77-40

Subchapter 6

Minimum Safety Standards - Design of

Pipeline Components

'6-77-40 Scope. This subchapter prescribes minimum requirements for the design and installation of pipeline components and facilities. In addition, it prescribes requirements relating to protection against accidental overpressuring. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.141, October 1, 1990)

'6-77-41 General requirements. Each component of a pipeline must be able to withstand operating pressures and other anticipated loadings without impairment of its serviceability with unit stresses equivalent to those allowed for comparable material in pipe in the same location and kind of service. However, if design based upon unit stresses is impractical for a particular component, design may be based upon a pressure rating established by the manufacturer by pressure testing that component or a prototype of the component. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.143, October 1, 1990)

'6-77-42 Qualifying metallic components. Notwithstanding any requirement of this subchapter which incorporates by reference an edition of a document listed in Appendix A, a metallic component manufactured in accordance with any other edition of that document is qualified for use under this chapter if:

'6-77-43

(1) It can be shown through visual inspection of the cleaned component that no defect exists which might impair the strength or tightness of the component; and

(2) The edition of the document under which the component was manufactured has equal or more stringent requirements for the following as an edition of that document currently or previously listed in Appendix A:

(A) Pressure testing;

(B) Materials; and

[Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.144, October 1, 1990)

'6-77-43 Valves. (a) Except for cast iron and plastic valves, each valve must meet the minimum requirements, or equivalent of API 6D. A valve may not be used under operating conditions that exceed the applicable pressure-temperature ratings contained in those requirements.

(b) Each cast iron and plastic valve must comply with the following:

(1) The valve must have a maximum service pressure rating for temperatures that equal or exceed the maximum service temperature;

(2) The valve must be tested as part of the manufacturing, as follows:

(A) With the valve in the fully open position, the shell must be tested with no leakage to a pressure at least 1.5 times the maximum service rating;

(B) After the shell test, the seat must be tested to a pressure not less than 1.5 times the maximum service pressure rating. Except for swing

'6-77-43

check valves, test pressure during the seat test must be applied successively on each side of the closed valve with the opposite side open. No visible leakage is permitted;

(C) After the last pressure test is completed, the valve must be operated through its full travel to demonstrate freedom from interference;

(3) Each valve must be able to meet the anticipated operating conditions;

(4) No valve having shell components made of ductile iron may be used at pressures exceeding eighty percent of the pressure ratings for comparable steel valves at their listed temperature. However, a valve having shell components made of ductile iron may be used at pressures up to eighty percent of the pressure ratings for comparable steel valves at their listed temperature, if:

(A) The temperature-adjusted service pressure does not exceed 1,000 p.s.i.g.; and

(B) Welding is not used on any ductile iron component in the fabrication of the valve shells or their assembly;

(5) No valve having pressure containing parts made of ductile iron may be used in the gas pipe components of compressor stations. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.147, October 1, 1990)

'6-77-44 Flanges and flange accessories. (a) Each flange or flange accessory (other than cast iron) must meet the minimum requirements of ANSI B16.5 MSS SP-44, or the equivalent.

'6-77-46

(b) Each flange assembly must be able to withstand the maximum pressure at which the pipeline is to be operated and to maintain its physical and chemical properties at any temperature to which it is anticipated that it might be subjected in service.

(c) Each flange on a flanged joint in cast iron pipe must conform in dimensions, drilling, face and gasket design to ANSI B16.1 and be cast integrally with the pipe, valve, or fitting. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.147, October 1, 1990)

'6-77-45 Standard fittings. (a) The minimum metal thickness of threaded fittings may not be less than specified for the pressures and temperatures in the applicable standards referenced in this chapter, or their equivalent.

(b) Each steel butt-welding fitting must have pressure and temperature ratings based on stresses for pipe of the same or equivalent material. The actual bursting strength of the fitting must at least equal the computed bursting strength of pipe of the designated material and wall thickness, as determined by a prototype that was tested to at least the pressure required for the pipeline to which it is being added. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.149, October 1, 1990)

'6-77-46 Tapping. (a) Each mechanical fitting used to make a hot tap must be designed for at least the operating pressure of the pipeline.

(b) Where a ductile iron pipe is tapped, the extent of full-thread engagement and the need for the use of outside-sealing service connections, tapping saddles, or other fixtures must be determined by service conditions.

'6-77-46

(c) Where a threaded tap is made in cast iron or ductile iron pipe, the diameter of the tapped hole may not be more than twenty-five percent of the nominal diameter of the pipe unless the pipe is reinforced, except that:

(1) Existing taps may be used for replacement service, if they are free of cracks and have good threads; and

(2) A 1-1/4-inch tap may be made in a four‑inch cast iron or ductile iron pipe, without reinforcement.

However, in areas where climate, soil, and service conditions may create unusual external stresses on cast iron pipe, unreinforced taps may be used only on six inch or larger pipe. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.151, October 1, 1990)

'6-77-47 Components fabricated by welding. (a) Except for branch connections and assemblies of standard pipe and fittings jointed by circumferential welds, the design pressure of each component fabricated by welding, whose strength cannot be determined, must be established in accordance with paragraph UG-101 of section VIII of the ASME Boiler and Pressure Vessel Code.

(b) Each prefabricated unit that uses plate and longitudinal seams must be designated, constructed, and tested in accordance with the ASME Boiler and Pressure Vessel Code, except for the following:

(1) Regularly manufactured butt-welding fittings;

(2) Pipe that has been produced and tested under a specification listed in Appendix B;

(3) Partial assemblies such as split rings or collars;

'6-77-49

(4) Prefabricated units that the manufacturer certifies have been tested to at least twice the maximum pressure to which they will be subjected under the anticipated operating conditions.

(c) Orange-peel bull plugs and orange-peel swages may not be used on pipelines that are to operate at a hoop stress of twenty percent or more of the SMYS of the pipe.

(d) Except for flat closures designed in accordance with section VIII of the SME Boiler and Pressure Code, flat closures and fish tails may not be used on pipe that either operates at 100 p.s.i.g., or more, or is more than three inches nominal diameter. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.153, October 1, 1990)

'6-77-48 Welded branch connections. Each welded branch connection made to pipe in the form of a single connection, or in a header or manifold as a series of connections, must be designed to ensure that the strength of the pipeline system is not reduced, taking into account the stresses in the remaining pipe wall due to the opening in the pipe or header, the shear stresses produced by the pressure acting on the area of the branch opening, and any external loadings due to thermal movement, weight, and vibration. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.155, October 1, 1990)

'6-77-49 Extruded outlets. Each extruded outlet must be suitable for anticipated service conditions and must be at least equal to the design strength of the pipe and other fittings in the pipeline to which it is attached.

'6-77-49

[Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.157, October 1, 1990)

'6-77-50 Flexibility. Each pipeline must be designed with enough flexibility to prevent thermal expansion or contraction from causing excessive stresses in the pipe or components, excessive bending or unusual loads at joints, or undesirable forces or moments at points of connection to equipment, or at anchorage or guide points. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.159, October 1, 1990)

'6-77-51 Supports and anchors. (a) Each pipeline and its associated equipment must have enough anchors or supports to:

(1) Prevent undue strain on connected equipment;

(2) Resist longitudinal forces caused by a bend or offset in the pipe; and

(3) Prevent or damp out excessive vibration.

(b) Each exposed pipeline must have enough supports or anchors to protect the exposed pipe joints from the maximum end force caused by internal pressure and any additional forces caused by temperature expansion or contraction or by the weight of the pipe and its contents.

(c) Each support or anchor on an exposed pipeline must be made of durable, noncombustible material and must be designed and installed as follows:

(1) Free expansion and contraction of the pipeline between supports or anchors may not be restricted;

(2) Provision must be made for the service conditions involved; and

(3) Movement of the pipeline may not cause disengagement of the support equipment.

'6-77-52

(d) Each support on an exposed pipeline operated at a stress level of fifty percent or more of SMYS must comply with the following:

(1) A structural support may not be welded directly to the pipe;

(2) The support must be provided by a member that completely encircles the pipe; and

(3) If an encircling member is welded to a pipe, the weld must be continuous and cover the entire circumference;

(e) Each underground pipeline that is connected to a relatively unyielding line or other fixed object must have enough flexibility to provide for possible movement, or it must have an anchor that will limit the movement of the pipeline.

(f) Except for offshore pipelines, each underground pipeline that is being connected to new branches must have a firm foundation for both the header and the branch to prevent detrimental lateral and vertical movement. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.161, October 1, 1990)

'6-77-52 Compressor stations: design and construction. (a) Location of compressor building. Except for a compressor building on a platform located offshore or in inland navigable waters, each main compressor building of a compressor station must be located on property under the control of the operator. It must be far enough away from adjacent property, not under control of the operator, to minimize the possibility of fire being communicated to the compressor building from structures on adjacent property. There must be enough open space around the main compressor building to allow the free movement of fire-fighting equipment.

(b) Building construction. Each building on a compressor station site must be made of noncombustible materials if it contains either:

'6-77-52

(1) Pipe more than two inches in diameter that is carrying gas under pressure; or

(2) Gas handling equipment other than gas utilization equipment used for domestic purposes.

(c) Exits. Each operating floor of a main compressor building must have at least two separated and unobstructed exits located so as to provide a convenient possibility of escape and an unobstructed passage to a place of safety. Each door latch on an exit must be of a type which can be readily opened from the inside without a key. Each swinging door located in an exterior wall must be mounted to swing outward.

(d) Fenced areas. Each fence around a compressor station must have at least two gates located so as to provide a convenient opportunity for escape to a place of safety, or have other facilities affording a similarly convenient exit from the area. Each gate located within 200 feet of any compressor plant building must open outward and, when occupied, must be openable from the inside without a key.

(e) Electrical facilities. Electrical equipment and wiring installed in compressor stations must conform to the National Electrical Code, NFPA-70 (ANSI), so far as that code is applicable. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.163, October 1, 1990)

'6-77-53 Compressor stations: liquid removal. (a) Where entrained vapors in gas may liquefy under the anticipated pressure and temperature conditions, the compressor must be protected against the introduction of those liquids in quantities that could cause damage.

(b) Each liquid separator used to remove entrained liquids at a compressor station must:

(1) Have a manually operable means of removing these liquids;

'6-77-54

(2) Where slugs of liquid could be carried into the compressors, have either automatic liquid removal facilities, an automatic compressor shutdown device, or a high liquid level alarm; and

(3) Be manufactured in accordance with section VIII of the ASME Boiler and Pressure Vessel Code, except that liquid separators constructed of pipe and fittings without internal welding must be fabricated with a design factor 0.4, or less. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.165, October 1, 1990)

'6-77-54 Compressor stations: emergency shutdown. (a) Except for unattended field compressor stations of 1,000 horsepower or less, each compressor station must have an emergency shutdown system that meets the following:

(1) It must be able to block gas out of the station and blow down the station piping;

(2) It must discharge gas from the blowdown piping at a location where the gas will not create a hazard;

(3) It must provide means for the shutdown of gas compressing equipment, gas fires, and electrical facilities in the vicinity of gas headers and in the compressor building, except, that:

(A) Electrical circuits that supply emergency lighting required to assist station personnel in evacuating the compressor building and the area in the vicinity of the gas headers must remain energized; and

(B) Electrical circuits needed to protect equipment from damage may remain energized;

'6-77-54

(4) It must be operable from at least two locations, each of which is:

(A) Outside the gas area of the station;

(B) Near the exit gates, if the station is fenced, or near emergency exits, if not fenced; and

(b) If a compressor station supplies gas directly to a distribution system with no other adequate source of gas available, the emergency shutdown system must be designed so that it will not function at the wrong time and cause an unintended outage on the distribution system.

(c) On a platform located offshore or in inland navigable waters, the emergency shutdown system must be designed and installed to actuate automatically by each of the following events:

(1) In the case of an unattended compressor station:

(A) When the gas pressure equals the maximum allowable operating pressure plus fifteen percent; or

(B) When an uncontrolled fire occurs on the platform; and

(2) In the case of a compressor station in a building:

(A) When an uncontrolled fire occurs in the building; or

(B) When the concentration of gas in air reaches fifty percent or more of the lower explosive limit in a building which has a source of ignition.

(d) For the purpose of subsection (c)(2)(B), an electrical facility which conforms to Class 1, Group D of the National Electrical Code is not a source of ignition. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.167, October 1, 1990)

'6-77-56

'6-77-55 Compressor stations: pressure limiting devices. (a) Each compressor station must have pressure relief or other suitable protective devices of sufficient capacity and sensitivity to ensure that the maximum allowable operating pressure of the station piping and equipment is not exceeded by more than ten percent.

(b) Each vent line that exhausts gas from the pressure relief valves of a compressor station must extend to a location where the gas may be discharged without hazard. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.169, October 1, 1990)

'6-77-56 Compressor stations: additional safety equipment. (a) Each compressor station must have adequate fire protection facilities. If fire pumps are a part of these facilities, their operation may not be affected by the emergency shutdown system.

(b) Each compressor station prime mover, other than an electrical induction or synchronous motor, must have an automatic device to shut down the unit before the speed of either the prime mover or the driven unit exceeds a maximum safe speed.

(c) Each compressor unit in a compressor station must have a shutdown or alarm device that operates in the event of inadequate cooling or lubrication of the unit.

(d) Each compressor station gas engine that operates with pressure gas injection must be equipped so that stoppage of the engine automatically shuts off the fuel and vents the engine distribution manifold.

(e) Each muffler for a gas engine in a compressor station must have vent slots or holes in the baffles of each compartment to prevent gas from being trapped in the muffler. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.171, October 1, 1990)

'6-77-57

'6-77-57 Compressor stations: ventilation. Each compressor station building must be ventilated to ensure that employees are not endangered by the accumulation of gas in rooms, sumps, attics, pits, or other enclosed places. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.173, October 1, 1990)

'6-77-58 Pipe-type and bottle-type holders. (a) Each pipe-type and bottle-type holder must be designated so as to prevent the accumulation of liquids in the holder, in connecting pipe, or in auxiliary equipment, that might cause corrosion or interfere with the safe operation of the holder.

(b) Each pipe-type or bottle-type holder must have minimum clearance from other holders in accordance with the following formula:

C = (3D X P X F)/1,000

in which:

C = Minimum clearance between pipe containers or bottles in inches.

D = Outside diameter of pipe containers or bottles in inches.

P = Maximum allowable operating pressure, p.s.i.g.

F = Design factor as set forth in section 6-77-32.

[Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.175, October 1, 1990)

'6-77-59 Additional provisions for bottle-type holders. (a) Each bottle-type holder must be:

(1) Located on a site entirely surrounded by fencing that prevents access by unauthorized persons and with minimum clearance from the fence as follows:

'6-77-60

_______________________________________________________________

│

Maximum allowable operating pressure │ Minimum clearance (feet)

_____________________________________│_________________________

│

Less than 1,000 p.s.i.g. ............│ 25

1,000 p.s.i.g. or more ..............│ 100

_____________________________________│_________________________

(2) Designed using the design factors set forth in section 6-77-32; and

(3) Buried with a minimum cover in accordance with section 6-77-105.

(b) Each bottle-type holder manufactured from steel that is not weldable under field conditions must comply with the following:

(1) A bottle-type holder made from alloy steel must meet the chemical and tensile requirements for the various grades of steel in ASTM A 372;

(2) The actual yield-tensile ratio of the steel may not exceed 0.85;

(3) Welding may not be performed on the holder after it has been heat treated or stress relieved, except that copper wires may be attached to the small diameter portion of the bottle end closure for cathodic protection if a localized thermit welding process is used;

(4) The holder must be given a mill hydrostatic test at a pressure that produces a hoop stress at least equal to eighty-five percent of the SMYS;

(5) The holder, connection pipe, and components must be leak tested after installation as required by subchapter 12. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.177, October 1, 1990)

'6-77-60 Transmission line valves. (a) Each transmission line, other than offshore segments,

'6-77-60

must have sectionalizing block valves spaced as follows:

(1) Each point on the pipeline in a Class 4 location must be within 2 2 miles of a valve;

(2) Each point on the pipeline in a Class 3 location must be within four miles of a valve;

(3) Each point on the pipeline in a Class 2 location must be within 7 2 miles of a valve;

(4) Each point on the pipeline in a Class 1 location must be within ten miles of a valve.

(b) Each sectionalizing block valve on a transmission line, other than offshore segments, must comply with the following:

(1) The valve and the operating device to open or close the valve must be readily accessible and protected from tampering and damage;

(2) The valve must be supported to prevent settling of the valve or movement of the pipe to which it is attached.

(c) Each section of a transmission line, other than offshore segments, between main line valves must have a low-downvalve with enough capacity to allow the transmission line to be blown down as rapidly as practicable. Each blowdown discharge must be located so the gas can be blown to the atmosphere without hazard and, if the transmission line is adjacent to an overhead electric line, so that the gas is directed away from the electrical conductors.

(d) Offshore segments of transmission lines must be equipped with valves or other components to shut off the flow of gas to an offshore platform in an emergency. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.179, October 1, 1990)

'6-77-62

'6-77-61 Distribution line valves. (a) Each high‑pressure distribution system must have valves spaced so as to reduce the time to shut down a section of main in an emergency. The valve spacing is determined by the operating pressure, the size of the mains, and the local physical conditions.

(b) Each regulator station controlling the flow or pressure of gas in a distribution system must have a valve installed on the inlet piping at a distance from the regulator station sufficient to permit the operation of the valve during an emergency that might preclude access to the station.

(1) The valve must be placed in a readily accessible location so as to facilitate its operation in an emergency;

(2) The operating stem or mechanism must be readily accessible; and

(3) If the valve is installed in a buried box or enclosure, the box or enclosure must be installed so as to avoid transmitting external loads to the main. [Eff ] (Auth: HRS '269‑6) (Imp: 49 C.F.R. '192.181, October 1, 1990)

'6-77-62 Vaults: structural design requirements. (a) Each underground vault or pit for valves, pressure relieving, pressure limiting, or pressure regulating stations, must be able to meet the loads which may be imposed upon it, and to protect installed equipment.

(b) There must be enough working space so that all of the equipment required in the vault or pit can be properly installed, operated, and maintained.

(c) Each pipe entering, or within, a regulator vault or pit must be steel for sizes ten inches, and less, except that control and gage piping may be

'6-77-62

copper. Where pipe extends through the vault or pit structure, provision must be made to prevent the passage of gasses or liquids through the opening and to avert strains in the pipe. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.183, October 1, 1990)

'6-77-63 Vaults: accessibility. Each vault must be located in an accessible location and, so far as practical, away from:

(1) Street intersections or points where traffic is heavy or dense;

(2) Points of minimum elevation, catch basins, or places where the access cover will be in the course of surface waters; and

(3) Water, electric, steam, or other facilities. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.185, October 1, 1990)

'6-77-64 Vaults: sealing, venting, and ventilation. Each underground vault or closed top pit containing either a pressure regulating or reducing station, or a pressure limiting or relieving station, must be sealed, vented or ventilated, as follows:

(1) When the internal volume exceeds 200 cubic feet:

(A) The vault or pit must be ventilated with two ducts, each having at least the ventilating effect of a pipe four inches in diameter;

(B) The ventilation must be enough to minimize the formation of combustible atmosphere in the vault or pit; and

'6-77-65

(2) When the internal volume is more than seventy‑five cubic feet but less than 200 cubic feet:

(A) If the vault or pit is sealed, each opening must have a tight fitting cover without open holes through which an explosive mixture might be ignited, and there must be a means for testing the internal atmosphere before removing the cover;

(B) If the vault or pit is vented, there must be a means of preventing external sources of ignition from reaching the vault atmosphere; or

(3) If a vault or pit covered by paragraph (2) is ventilated by openings in the covers or gratings and the ratio of the internal volume, in cubic feet, to the effective ventilating area of the cover or grating, in square feet, is less than twenty to one, no additional ventilation is required. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.187, October 1, 1990)

'6-77-65 Vaults: drainage and waterproofing. (a) Each vault must be designed so as to minimize the entrance of water.

(b) A vault containing gas piping may not be connected by means of a drain connection to any other underground structure.

(c) All electrical equipment in vaults must conform to the applicable requirements of Class 1, Group D, of the National Electrical Code, ANSI Standard C1. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.189, October 1, 1990)

'6-77-66

'6-77-66 Design pressure of plastic fittings. (a) Thermosetting fittings for plastic pipe must conform to ASTM D 2517.

(b) Thermoplastic fittings for plastic pipe must conform to ASTM D 2513. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.191, October 1, 1990)

'6-77-67 Valve installation in plastic pipe.

Each valve installed in plastic pipe must be designed so as to protect the plastic material against excessive torsional or shearing loads when the valve or shutoff is operated, and from any other secondary stresses that might be exerted through the valve or its enclosure. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.193, October 1, 1990)

'6-77-68 Protection against accidental overpressuring. (a) General requirements. Except as provided in section 6-77-69, each pipeline that is connected to a gas source so that the maximum allowable operating pressure could be exceeded as the result of pressure control failure or of some other type of failure, must have pressure relieving or pressure limiting devices that meet the requirements of sections 6-77-70 and 6-77-71.

(b) Additional requirements for distribution systems. Each distribution system that is supplied from a source of gas that is at a higher pressure than the maximum allowable operating pressure for the system must:

(1) Have pressure regulation devices capable of meeting the pressure, load, and other service conditions that will be experienced in normal operation of the system, and that could be activated in the

'6-77-69

event of failure of some portion of the system; and

(2) Be designed so as to prevent accidental overpressuring. [Eff ] (Auth: HRS '269-6) (Imp: 49 C.F.R. '192.195, October 1, 1990)

'6-77-69 Control of the pressure of gas delivered from high-pressure distribution systems. (a) If the maximum actual operating pressure of the distribution system is under 60 p.s.i.g. and a service regulator having the following characteristics is used, no other pressure limiting device is required:

(1) A regulator capable of reducing distribution line pressure to pressures recommended for household appliances;

(2) A single port valve with proper orifice for the maximum gas pressure at the regulator inlet;

(3) A valve seat made of resilient material designed to withstand abrasion of the gas, impurities in gas, cutting by the valve, and to resist permanent deformation when it is pressed against the valve port;