807 KAR 5:022. Gas safety and service.
RELATES TO: KRS 278.485, 278.502
STATUTORY AUTHORITY: KRS 278.280(2)
NECESSITY, FUNCTION, AND CONFORMITY: KRS 278.280(2) provides that the commission shall prescribe rules for the performance of any service or the furnishing of any commodity by any utility. This administrative regulation establishes general rules which apply to gas utilities.
Section 1. General. (1) Definitions. As used in this administrative regulation:
(a) "British thermal unit (BTU)" means quantity of heat that must be added to one (1) pound of pure water to raise its temperature from fifty-eight and one-half (58.5) degrees Fahrenheit to fifty-nine and one-half (59.5) degrees Fahrenheit at the absolute pressure of a column of pure mercury thirty (30) inches high at thirty-two (32) degrees Fahrenheit under standard gravity (32.174 ft. per sec-sec).
(b) "Commission" means the Public Service Commission.
(c) "Cubic foot of gas" means the following:
1. If gas is supplied and metered to customers at standard distribution pressure, a cubic foot of gas shall be defined as that volume of gas which, at the temperature and pressure existing in the meter, occupies one (1) cubic foot.
2. If gas is supplied to customers through turbine, orifice or positive displacement meters at other than standard distribution pressure, a cubic foot of gas shall be defined as that volume of gas which, at sixty (60) degrees Fahrenheit and at absolute pressure of 14.73 pounds per square inch, (thirty (30) inches of mercury), occupies one (1) cubic foot; except that in cases where different bases that are considered by the commission to be fair and reasonable are provided for in gas sales contracts or in rules or practices of a utility, such different bases shall be effective.
3. The standard cubic foot of gas for testing the gas itself for heating value shall be that volume of gas which, when saturated with water vapor and at temperature of sixty (60) degrees Fahrenheit, and under pressure equivalent to that of thirty (30) inches of mercury (mercury at thirty-two (32) degrees Fahrenheit and under standard gravity) occupies one (1) cubic foot.
(d) "Customer piping" means all approved equipment and material required for natural gas service downstream from the property line except for the service tap including saddle (tapping tee) and first service valve and meter (service regulator where required).
(e) "Distribution line" means a pipeline other than a gathering or transmission line.
(f) "Gathering line" means a pipeline that transports gas from a current production facility to a transmission line or main.
(g) "High pressure distribution system" means a distribution system in which gas pressure in the main is higher than pressure provided to the customer.
(h) "Listed specification" means a specification listed in Section 1 of Appendix B of this administrative regulation.
(i) "Low-pressure distribution system" means a distribution system in which gas pressure in the main is substantially the same as pressure provided to the customer.
(j) "Main" means a distribution line that serves as a common source of supply for more than one (1) service line.
(k) "Maximum actual operating pressure" means the maximum pressure that occurs during normal operations over a period of one (1) year.
(l) "Maximum allowable operating pressure (MAOP)" means the maximum pressure at which a pipeline or segment of a pipeline may be operated under this administrative regulation.
(m) "Meter" means any device used to measure the quantity of gas delivered by utility to a customer.
(n) "Operator" means a utility as defined in KRS 278.010.
(o) "Pipe" means any pipe or tubing used in transportation of gas, including pipe-type holders.
(p) "Pipeline" means all parts of those physical facilities through which gas moves in transportation, including pipe, valves, and other appurtenances attached to pipe, compressor units, metering stations, regulator stations, delivery stations, holders, and fabricated assemblies.
(q) "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.
(r) "Pressure, absolute" means total gas pressure, which is the sum of barometric pressure plus line gas pressure (gauge), abbreviated as psia.
(s) "Pressure, gauge" means pounds per square inch above atmospheric pressure, abbreviated as psig.
(t) "Secretary" means the Secretary of the U.S. Department of Transportation or any person to whom he has delegated authority.
(u) "Service line" means a distribution line that transports gas from a common source of supply to: customer meter or connection to a customer's piping, whichever is farther downstream; or connection to a customer's piping if there is no customer meter.
(v) "SMYS" means specified minimum yield strength and is defined as:
1. For steel pipe manufactured in accordance with a listed specification, the yield strength specified as a minimum in that specification; or
2. For steel pipe manufactured in accordance with an unknown or unlisted specification, the yield strength determined in accordance with Section 3(4)(b) of this administrative regulation.
(w) "State" means Commonwealth of Kentucky.
(x) "Therm" means the unit of heating value equivalent to 100,000 British thermal units.
(y) "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 (20) percent or more of SMYS; or
3. Transports gas within a storage field.
(2) Scope. This administrative regulation prescribes minimum safety and service standards for natural gas utilities operating under the jurisdiction of the commission.
(a) Utilities serving customers under KRS 278.485 or other retail customers, under the jurisdiction of the commission, directly from transmission or gathering lines are exempt from the following sections of this administrative regulation insofar as they apply to these customers:
1. Section 9, subsections (2)(b) through (f), (16) and (17);
2. Section 13, subsections (14), (15), and (16);
3. Section 14, subsection (22);
4. Section 15; and
5. Section 16.
(b) Each utility shall make all reasonable efforts to prevent interruptions of service and if interruptions occur, shall endeavor to reestablish service with the shortest possible delay consistent with the safety of its consumers and the general public. Planned interruptions shall always be preceded by adequate notice to all affected customers.
(3) Class locations.
(a) Class location is determined by applying criteria set forth in this section: class location unit is an area that extends 220 yards on either side of the centerline of any continuous one (1) mile length of pipeline. Except as provided in paragraphs (d) and (f) of this section, class location is determined by buildings in the class location unit. For the purpose 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 (10) or less buildings intended for human occupancy.
(c) A Class 2 location is any class location unit that has more than ten (10) but less than forty-six (46) buildings intended for human occupancy.
(d) A Class 3 location is any class location unit that has forty-six (46) or more buildings intended for human occupancy; or an area where the pipeline lies within 100 yards of either a building or a small, well-defined outside area (such as playground, recreation area, outdoor theater, or other place of public assembly) that is occupied by twenty (20) or more persons on at least five (5) days a week for ten (10) weeks in any twelve (12) month period. (The days and weeks need not be consecutive.)
(e) A Class 4 location is any class location unit where buildings with four (4) or more stories above ground are prevalent.
(f) Boundaries of class locations determined in accordance with paragraphs (a) through (e) of this section may be adjusted as follows:
1. Class 4 location ends 220 yards from the nearest building with four (4) or more stories above ground.
2. When a cluster of buildings intended for human occupancy requires a Class 3 location, 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, Class 2 location ends 220 yards from the nearest building in the cluster.
(4) Incorporation by reference.
(a) Any documents or parts thereof incorporated by reference in this section are a part of this administrative regulation as though set out in full.
(b) All incorporated documents are available for inspection in the offices of the Public Service Commission, Frankfort, Kentucky. These materials have been approved for incorporation by reference by the Legislative Research Commission. These documents are also available at the addresses provided in Appendix A to this administrative regulation.
(c) Full titles for publications incorporated by reference in this section are provided in Appendix A to this administrative regulation. Numbers in parenthesis indicate applicable editions.
(5) Gathering lines. Each gathering line must comply with requirements of this administrative regulation applicable to transmission lines except as exempted in Section 1(1)(a) of this administrative regulation.
(6) Petroleum gas systems.
(a) No utility shall transport petroleum gas in a system that serves ten (10) 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 administrative regulation and of NFPA Standards No. 58 and 59. In the event of a conflict, the requirements of this administrative regulation prevail.
(b) Each petroleum gas system covered by paragraph (a) of this subsection shall comply with the following:
1. Aboveground structures shall have open vents near floor level.
2. Below-ground structures shall have forced ventilation that will prevent any accumulation of gas.
3. Relief valve discharge vents shall be located to prevent any accumulation of gas at or below ground level.
4. Special precautions shall be taken to provide adequate ventilation when excavations are made to repair an underground system.
(c) For the purpose of this subsection, petroleum gas means propane, butane, or mixtures of these gases, other than a gas mixture used to supplement supplies in a natural gas distribution system.
(7) General.
(a) No person may operate a pipeline segment readied for service after March 12, 1971, unless:
1. The pipeline has been designed, installed, constructed, initially inspected, and initially tested in accordance with this administrative regulation; and
2. The pipeline qualifies for use under this administrative regulation in accordance with Section 1(8) of this administrative regulation.
(b) No person may operate a pipeline segment replaced, relocated, or otherwise changed after November 12, 1970, unless that replacement, relocation, or change has been made in accordance with this administrative regulation.
(c) Each utility shall establish and then maintain plans, procedures and programs as required under this administrative regulation.
(8) Conversion to service subject to this administrative regulation. Steel pipeline previously used in service not subject to this administrative regulation qualifies for use under this administrative regulation if the utility prepares and follows a written procedure to carry out the following requirements:
1. The design, construction, operation, and maintenance history of the pipeline shall be reviewed and, where sufficient historical records are not available, appropriate tests shall 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 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 shall be corrected in accordance with this administrative regulation.
4. The pipeline must be tested in accordance with Section 11 of this administrative regulation to substantiate maximum allowable operating pressure permitted by Section 13 of this administrative regulation.
5. Each utility must keep for the life of the pipeline a record of investigations, tests, repairs, replacements, and alterations made under the requirements of paragraph (a) of this subsection.
Section 2. Materials. (1) Scope. This section prescribes minimum requirements for selection and qualification of pipe and components for use in pipelines.
(2) General. Materials for pipe and components shall be:
(a) Able to maintain the structural integrity of the pipeline under temperature and other anticipated environmental conditions;
(b) Chemically compatible with any gas that they transport and with any other material in the pipeline with which they are in contact; and
(c) Qualified in accordance with applicable requirements of this section.
(3) Steel pipe.
(a) New steel pipe is qualified for use under this administrative regulation if:
1. It was manufactured in accordance with a listed specification;
2. It meets the requirements of:
a. Section II of Appendix B to this administrative regulation; or
b. If it was manufactured before November 12, 1970, either Section II or III of Appendix B to this administrative regulation; or
3. It is used in accordance with paragraph (c) or (d) of this subsection.
(b) Used steel pipe is qualified for use under this administrative regulation if:
1. It was manufactured in accordance with a listed specification and it meets the requirements of Section II-C of Appendix B to this administrative regulation;
2. It meets the requirements of:
a. Section II of Appendix B to this administrative regulation;
b. If it was manufactured before November 12, 1970, either Section II or III of Appendix B to this administrative regulation;
3. It has been used in an existing line of same or higher pressure and meets the requirements of Section II-C of Appendix B to this administrative regulation; or
4. It is used in accordance with paragraph (c) of this subsection.
(c) New or used pipe may be used at a pressure resulting in a hoop stress of less than 6,000 psi where no close coiling of close bending is to be done, if visual examination indicates that the pipe is in good condition and is free of split seams and other defects that would cause leakage. If it is to be welded, steel pipe not manufactured to a listed specification shall also pass the weldability tests prescribed in Section II-B of Appendix B to this administrative regulation.
(d) Unused steel pipe manufactured before November 12, 1970, may be used as replacement pipe if it meets the same specifications as the pipe used in constructing that segment of pipeline.
(e) New steel pipe that has been cold expanded shall comply with the mandatory provisions of API Standard 5L.
(f) New or used pipe of unknown specifications and all used pipe, the strength of which is impaired by corrosion or other deterioration, shall be retested hydrostatically either length by length in a mill type test or in the field after installation before placed in service, and the test pressure used shall establish maximum allowable operating pressure.
(4) Plastic pipe.
(a) New plastic pipe is qualified for use under this administrative regulation 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 administrative regulation if:
1. It is 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 tolerance of the specification to which it was manufactured; and
5. It is free of visible defects.
(c) For the purpose of paragraphs (a)1 and (b)1 of this subsection, 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 strength and design criteria required of pipe included in that listed specification; and
2. Is manufactured from plastic compounds which meet criteria for material required of pipe included in that listed specification.
(5) Marking of materials.
(a) Except as provided in paragraph (d) of this subsection, each valve, fitting, length of pipe, and other components shall be marked as prescribed in:
1. The specification or standard to which it was manufactured; or
2. To indicate size, material, manufacturer, pressure rating, temperature rating and, as appropriate, type, grade and model.
(b) Surfaces of pipe and components that are subject to stress from internal pressure shall not be field die stamped.
(c) If any item is marked by die stamping, the die shall have blunt or rounded edges that will minimize stress concentrations.
(d) Paragraph (a) of this subsection does not apply to items manufactured before November 12, 1970, that meet all of the following:
1. Item is identifiable as to type, manufacturer, and model.
2. Specifications or standards giving pressure, temperature, and other appropriate criteria for use of items are readily available.
(6) Transportation of pipe. In a pipeline to be operated at a hoop stress of twenty (20) percent or more of SMYS, operator shall not use pipe having outer diameter to wall thickness ratio of seventy to one (70 to 1), or more, which is transported by railroad unless:
(a) Transportation is performed in accordance with the most recent edition of API RP5L1, except that before February 25, 1975, transportation may have been performed in accordance with the 1967 edition of API RP5L1.
(b) In the case of pipe transported before November 12, 1970, the pipe is tested in accordance with Section 11 of this administrative regulation to at least one and one-fourth (1.25) times maximum allowable operating pressure if it is to be installed in a Class 1 location, and to at least one and one-half (1.5) times 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 Section 11 of this administrative regulation, test pressure must be maintained for at least eight (8) hours.
Section 3. Pipe Design. (1) Scope. This section prescribes minimum requirements for design of pipe.
(2) General. Pipe shall be designed with sufficient wall thickness, or shall be installed with adequate protection, to withstand anticipated external pressures and loads that will be imposed on pipe after installation.
(3) Design formula for steel pipe.
(a) Design pressure for steel pipe is determined in accordance with the following formula:
P = Design pressure in pounds per square inch gauge.
S = Yield strength in pounds per square inch determined in accordance with subsection (4) of this section.
D = Nominal outside diameter of pipe in inches.
t = Nominal wall thickness of pipe in inches. If this is unknown, it is determined in accordance with subsection (5) of this section. Additional wall thickness required for concurrent external loads in accordance with subsection (2) of this section shall not be included in computing design pressure.
F = Design factor determined in accordance with subsection (6) of this section.
E = Longitudinal joint factor determined in accordance with subsection (7) of this section.
T = Temperature derating factor determined in accordance with subsection (8) of this section.
(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 part of welding design pressure is limited to seventy-five (75) percent of the pressure determined under paragraph (a) of this subsection if temperature of pipe exceeds 900°F (482°C) at any time or is held above 600°F (316°C) for more than one (1) hour.
(4) Yield strength (s) for steel pipe.
(a) For pipe manufactured in accordance with a specification listed in Section I of Appendix B of this administrative regulation, yield strength to be used in the design formula in subsection (3) of this section is the SMYS stated in the listed specification, if that value is known.
(b) For pipe manufactured in accordance with a specification not listed in Section I of Appendix B to this administrative regulation or whose specification or tensile properties are unknown, yield strength to be used in the design formula in subsection (3) of this section is one of the following:
1. If pipe is tensile tested in accordance with Section II-D of Appendix B to this administrative regulation, the lower of the following:
a. Eighty (80) percent of average yield strength determined by tensile tests; or
b. The lowest yield strength determined by tensile tests, but no more than 52,000 psig.
2. If pipe is not tensile tested as provided in paragraph (b)1 of this subsection, 24,000 psig.
(5) Nominal wall thickness (t) for steel pipe.
(a) If 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 (1) end.
(b) However, if pipe is of uniform grade, size and thickness and there are more than ten (10) lengths, only ten (10) percent of the individual lengths, but not less than ten (10) lengths, need be measured. Thickness of lengths not measured shall be verified by applying a gauge set to the minimum thickness found by measurement. Nominal wall thickness to be used in the design formula in subsection (3) of this section is the next wall thickness found in commercial specifications that is below the average of all measurements taken. However, nominal wall thickness used shall not be more than 1.14 times the smallest measurement taken on pipe less than twenty (20) inches in outside diameter, nor more than 1.11 times the smallest measurement taken on pipe twenty (20) inches or more in outside diameter.
(6) Design factor (F) for steel pipe.
(a) Except as otherwise provided in paragraphs (b), (c), and (d) of this subsection, the design factor to be used in the design formula in subsection (3) of this section 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 six-tenths (0.60) or less shall be used in the design formula in subsection (3) of this section, for steel pipe in Class 1 locations that:
1. Cross the right-of-way of an unimproved public road, without a casing;
2. Cross without a casing, or makes a parallel encroachment on, the right-of-way of either a hard surfaced road, highway, public street, or railroad;
3. Are supported by a vehicular, pedestrian, railroad, or pipeline bridge; or
4. Are used in a fabricated assembly (including separators, mainline valve assemblies, cross-connections, and river crossing headers) or are used within five (5) pipe diameters in any direction from the last fitting of a fabricated assembly, other than a transition piece of an elbow used in place of a pipe bend not associated with a fabricated assembly.
(c) For Class 2 locations, a design factor of five-tenths (0.50) or less shall be used in the design formula in subsection (3) of this section for uncased steel pipe that crosses the right-of-way of a hard surfaced road, highway, public street, or railroad.
(d) For Class 1 and Class 2 locations, a design factor of five-tenths (0.50) or less shall be used in the design formula in subsection (3) of this section 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.
(7) Longitudinal joint factor (E) for steel pipe. Longitudinal joint factor to be used in the design formula in subsection (3) of this section is determined in accordance with the following table:
|
Specification |
Pipe Class |
Longitudinal Joint Factor (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 |
|
|
Other |
Pipe over 4 inches |
.80 |
|
Other |
Pipe 4 inches or less |
.60 |
If the type of longitudinal joint cannot be determined, the joint factor to be used shall not exceed that designated for "Other."
(8) Temperature derating factor (T) for steel pipe. Temperature derating factor to be used in the design formula in subsection (3) of this section is determined as follows:
|
Gas temperature in degrees Fahrenheit |
Temperature derating factor (T) |
|
250 or less |
1.000 |
|
300 |
0.967 |
|
350 |
0.933 |
|
400 |
0.900 |
|
450 |
0.867 |
For intermediate gas temperatures, derating factor is determined by interpolation.
(9) Design of plastic pipe. Design pressure for plastic pipe is determined in accordance with the following formula, subject to the limitations of subsection (10) of this section:
P = Design pressure, gauge, kPa (psi).
S = For thermoplastic pipe the long-term hydrostatic strength determined in accordance with the listed specification at a temperature equal to twenty-three (23) degrees Centigrade (seventy-three (73) degrees Fahrenheit), thirty-eight (38) degrees Centigrade (100 degrees Fahrenheit), forty-nine (49) degrees Centigrade (120 degrees Fahrenheit), or sixty (60) degrees Centigrade (140 degrees Fahrenheit): for reinforced thermosetting plastic pipe, 75,800 kPa (11,000 psig).
t = Specified wall thickness, mm (in.).
D = Specified outside diameter, mm (in.).
(10) Design limitations for plastic pipe.
(a) Design pressure shall not exceed gauge pressure of 689 kPa (100 psig) for plastic pipe used in:
1. Distribution systems; or
2. Classes 3 and 4 locations.
(b) Plastic pipe shall not be used where operating temperature of pipe will be:
1. Below minus twenty-nine (29) degrees Centigrade (minus twenty (20) degrees Fahrenheit); or
2. In the case of thermoplastic pipe, above the temperature at which the long-term hydrostatic strength used in the design formula under subsection (9) of this section is determined, except that pipe manufactured before May 18, 1978, may be used at temperatures up to thirty-eight (38) degrees Centigrade (100°F); or in the case of reinforced thermosetting plastic pipe, above sixty-six (66) degrees Centigrade (150°F).
(c) Wall thickness for thermoplastic pipe shall not be less than 1.57 millimeters (0.062 in.).
(d) Wall thickness for reinforced thermosetting plastic pipe shall not be less than that listed in the following table:
|
Nominal size in inches: |
Minimum wall thickness millimeters (inches) |
|
2 |
1.52 (0.060) |
|
3 |
1.52 (0.060) |
|
4 |
1.78 (0.070) |
|
5 |
2.54 (0.100) |
(11) Design of copper pipe.
(a) Copper pipe used in mains shall have a minimum wall thickness of 0.065 inches and shall be hard drawn.
(b) Copper pipe used in service lines shall have a wall thickness not less than that indicated in the following table:
|
Standard size (inch) |
Nominal O.D. (inch) |
Wall thickness (inch) |
|
|
Nominal |
Tolerance |
||
|
1/2 |
.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 |
(c) Copper pipe used in mains and service lines shall not be used at pressures in excess of 100 psig.
(d) Copper pipe that does not have an internal corrosion resistant lining shall not be used to carry gas that has an average hydrogen sulfide content of more than three-tenths (0.3) grains per 100 standard cubic feet of gas.
Section 4. Design of Pipeline Components. (1) Scope. This section prescribes minimum requirements for design and installation of pipeline components and facilities, and it prescribes requirements relating to protection against accidental overpressuring.
(2) General requirements. Each component of a pipeline shall withstand operating pressures and other anticipated loadings without impairment of 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 stress 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.
(3) Qualifying metallic components. Notwithstanding any requirement of this section which incorporates by reference an edition of a document listed in Appendix A of this administrative regulation, a metallic component manufactured in accordance with any other edition of that document is qualified for use under this administrative regulation if:
(a) 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
(b) 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:
1. Pressure testing;
2. Materials; and
3. Pressure and temperature ratings.
(4) Valves.
(a) Except for cast iron and plastic valves, each valve shall meet the minimum requirements, or equivalent, of API 6D. A valve shall not be used under operating conditions that exceed the applicable pressure-temperature ratings contained in those requirements.
(b) Each cast iron and plastic valve shall comply with the following:
1. The valve shall have a maximum service pressure rating for temperatures that equal or exceed maximum service temperature.
2. The valve shall be tested as part of the manufacturing, as follows:
a. With the valve fully open, the shell shall be tested with no leakage to a pressure at least one and one-half (1.5) times the maximum service rating.
b. After the shell test, the seat shall be tested to a pressure not less than one and one-half (1.5) times the maximum service pressure rating. Except for swing check valves, test pressure during the seat test shall 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 shall be operated through its full travel to demonstrate freedom from interference.
(c) Each valve shall be able to meet anticipated operating conditions.
(d) No valve having shell components made of ductile iron may be used at pressures exceeding eighty (80) percent of pressure ratings for comparable steel valves at their listed temperatures. However, a valve having shell components made of ductile iron may be used at pressures up to eighty (80) percent of pressure ratings for comparable steel valves at their listed temperatures, if:
1. Temperature-adjusted service pressure does not exceed 1,000 psig; and
2. Welding is not used on any ductile iron component in the fabrication of the valve shells or their assembly.
(e) No valve having pressure containing parts made of ductile iron may be used in gas pipe components of compressor stations.
(5) Flanges and flange accessories.
(a) Each flange or flange accessory (other than cast iron) shall meet the minimum requirements of ANSI B16.5, MSS SP-44, or equivalent.
(b) Each flange assembly shall withstand the maximum pressure at which the pipeline is to be operated and maintain its physical and chemical properties at any anticipated temperature.
(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.
(6) Standard fittings.
(a) Minimum metal thickness of threaded fittings shall not be less than specified for pressures and temperatures in applicable standards referenced in this administrative regulation, or their equivalent.
(b) Each steel butt-welding fitting shall have pressure and temperature ratings based on stresses for pipe of same or equivalent material. 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 tested to at least the pressure required for the pipeline to which it is being added.
(7) Tapping.
(a) Each mechanical fitting used to make a hot tap shall be designed for at least operating pressure of the pipeline.
(b) Where ductile iron pipe is tapped, the extent of full-threaded engagement and need for use of outside-sealing service connections, tapping saddles, or other fixtures shall be determined by service conditions.
(c) Where a threaded tap is made in cast iron or ductile iron pipe, diameter of the tapped hole shall not be more than twenty-five (25) 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 one and one-fourth (1 1/4) inch tap may be made in a four (4) 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 (6) inch or larger pipes.
(8) Components fabricated by welding.
(a) Except for branch connections and assemblies of standard pipe and fittings joined by circumferential welds, design pressure of each component fabricated by welding, whose strength cannot be determined, shall 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 shall be designed, constructed, and tested in accordance with ASME Boiler and Pressure Vessel Code, except for the following:
1. Regularly manufactured butt-welding fittings.
2. Pipe produced and tested under a specification listed in Appendix B to this administrative regulation.
3. Partial assemblies such as split rings or collars.
4. Prefabricated units that the manufacturer certifies have been tested to at least twice the anticipated maximum pressure under operating conditions.
(c) Orange peel bull plugs and orange peel swages shall not be used on pipelines that are to operate at hoop stress of twenty (20) percent or more of SMYS of the pipe.
(d) Except for flat closures designed in accordance with section VIII of the ASME Boiler and Pressure Vessel Code, flat closures and fish tails shall not be used on pipe that either operates at 100 psig, or more, or is more than three (3) inches nominal diameter.
(9) 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, shall be designed to ensure that strength of the pipeline system is not reduced, taking into account stresses in the remaining pipe wall due to the opening in the pipe or header, shear stresses produced by pressure acting on the area of the branch opening, and any external loadings due to thermal movement, weight, and vibration.
(10) Extruded outlets. Each extruded outlet shall be suitable for anticipated service conditions and shall be at least equal to design strength of the pipe and other fittings in the pipeline to which it is attached.
(11) Flexibility. Each pipeline shall be designed with enough flexibility to prevent thermal expansion or contraction from causing excessive stresses in 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.
(12) Supports and anchors.
(a) Each pipeline and its associated equipment shall 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 shall have enough supports or anchors to protect the exposed pipe joints from maximum end force caused by internal pressure and any additional forces caused by temperature expansion or contraction or by weight of the pipe and its contents.
(c) Each support or anchor on an exposed pipeline shall be made of durable, noncombustible material and shall be designed and installed as follows:
1. Free expansion and contraction of the pipeline between supports or anchors shall not be restricted.
2. Provision shall be made for service conditions involved.
3. Movement of the pipeline shall not cause disengagement of support equipment.
(d) Each support on an exposed pipeline operated at a stress level of fifty (50) percent of more of SMYS shall comply with the following:
1. A structural support shall not be welded directly to the pipe.
2. The support shall be provided by a member that completely encircles the pipe.
3. If an encircling member is welded to a pipe, the weld shall be continuous and cover the entire circumference.
(e) Each underground pipeline connected to a relatively unyielding line or other fixed object shall have enough flexibility to provide for possible movement, or it shall have an anchor that will limit movement of the pipeline.
(f) Except for offshore pipelines each underground pipeline being connected to new branches shall have firm foundation for both the header and branch to prevent detrimental lateral and vertical movement.
(13) Compressor stations: design and construction.
(a) Location of compressor building. Except for a compressor building on a platform in inland navigable waters, each main compressor building of a compressor station shall be located on property under the operator's control. It shall be far enough away from adjacent property, not under control of the operator, to minimize the possibility of fire being transferred to the compressor building from structures on adjacent property. There shall be enough open space around the main compressor building to allow free movement of firefighting equipment.
(b) Building construction. Each building on a compressor station site shall be made of noncombustible materials if it contains either:
1. Pipe that is more than two (2) inches in diameter and carrying gas under pressure; and
2. Gas handling equipment other than gas utilization equipment used for domestic purposes.
(c) Exits. Each operating floor of a main compressor building shall have at least two (2) separated and unobstructed exits located to provide a convenient possibility of escape and unobstructed passage to safety. Each exit door latch shall be of a type which can be readily opened from inside without a key. Each swinging door located in an exterior wall shall be mounted to swing outward.
(d) Fenced areas. Each fence around a compressor station shall have at least two (2) gates located to provide convenient opportunity for escape to safety, or have other facilities affording a similarly convenient exit from the area. Each gate located within 200 feet of any compressor plant building shall open outward and, when occupied, shall be of a type that can be readily opened from inside without a key.
(e) Electrical areas. Electrical equipment and wiring installed in compressor stations shall conform to the National Electrical Code, NFPA-70(ANSI), so far as that code is applicable.
(f) Air piping system.
1. All air piping within gas compressing stations shall be constructed in accordance with Section 2 of the USAS B31.1 Code for Pressure Piping.
2. Starting air pressure, storage volume and size of connection piping shall be adequate to rotate the engine at cranking speed and for the number of revolutions necessary to purge fuel gas from the power cylinder and muffler. Recommendations of the engine manufacturer may be used as a guide in determining these factors. Consideration should be given to the number of engines installed and to the possibility of starting several of these engines within a short period of time.
3. A check valve shall be installed in the starting air line near each engine to prevent backflow from the engine into the piping system. A check valve shall also be placed in the main air line on the immediate outlet side of the air tank or tanks. It is recommended that equipment for cooling air and removing moisture and entrained oil be installed between the starting air compressor and air storage tanks.
4. Suitable provision shall be made to prevent starting air from entering power cylinders of an engine and activating moving parts while work is in progress on the engine or on equipment driven by the engines. Acceptable means of accomplishing this are installation of a blind flange, removal of a portion of the air supply piping or locking closed a stop valve and locking open a vent downstream from it.
(g) Air receivers. Air receivers or air storage bottles, for use in compressor stations, shall be constructed and equipped in accordance with Section VII, Unfired Pressure Vessels, of the ASME Boiler and Pressure Vessel Code.
(h) Lubricating oil piping. All lubricating oil piping with gas compressing stations shall be constructed in accordance with USA Standard Code for Pressure Piping, Petroleum Refinery Piping, USAS B 31.3.
(i) Water and steam piping. All water and steam piping within gas compressing stations shall be constructed in accordance with USA Standard Code for Pressure Piping, Power Piping, USAS B31.0.0.
(j) Hydraulic piping. All hydraulic power piping within gas compressing stations shall be constructed in accordance with USA Standard Code for Pressure Piping, Petroleum Refinery Piping, USAS B31.3.
(14) Compressor stations; liquid removal.
(a) Where entrained vapors in gas may liquefy under anticipated pressure and temperature conditions, the compressor shall be protected against introduction of those liquids in damaging quantities.
(b) Each liquid separator used to remove entrained liquids at a compressor station shall:
1. Have a manually operable means of removing these liquids.
2. Where slugs of liquid could be carried into the compressors, have either automatic liquid removal facilities, automatic compressor shutdown device, or 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 shall be fabricated with a design factor of four-tenths (0.4) or less.
(15) Compressor stations: emergency shutdowns.
(a) Except for unattended field compressor stations of 1,000 horsepower or less, each compressor station shall have an emergency shutdown system that can do the following:
1. Block gas out of the station and blow down the station piping.
2. Discharge gas from the blowdown piping at a location where gas will not create a hazard.
3. Provide means for shutdown of gas compressing equipment, gas fires, and electrical facilities in the vicinity of gas headers and in the compressor building, except, that:
a. Electric 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 shall remain energized; and
b. Electrical circuits needed to protect equipment from damage may remain energized.
4. It shall be operable from at least two (2) locations, each of which is:
a. Outside the gas area of the station;
b. Near the exit gates, if station is fenced; or near emergency exits, if not fenced; and
c. Not more than 500 feet from the limits of the stations.
(b) If a compressor station supplies gas directly to a distribution system with no other adequate source of gas available, the emergency shutdown system shall be designed to prevent function at the wrong time and unintended outage on the distribution system.
(c) On a platform located in inland navigable waters, the emergency shutdown system shall be designed and installed to actuate automatically by each of the following events:
1. In the case of an unattended compressor station:
a. When gas pressure equals maximum allowable operating pressure plus fifteen (15) percent; or
b. When uncontrolled fire occurs on the platform; and
2. In the case of a compressor station in a building:
a. When uncontrolled fire occurs in the building; or
b. When the concentration of gas in air reaches fifty (50) percent or more of the lower explosive limit in a building which has a source of ignition.
For the purpose of paragraph (c)2 of this subsection, an electrical facility which conforms to Class 1, Group D of the National Electrical Code is not a source of ignition.
3. All emergency valves and controls shall be identified by signs. All important gas pressure piping shall be identified by signs or color codes as to their function.
(16) Compressor stations: pressure limiting devices.
(a) Each compressor station shall have pressure relief or other suitable protective d