49 CFR-192 Transportation of Natural and Other Gas By Pipeline Subpart G, J, N.

Recommended practice for basic inspection requirements
- new pipeline construction
49 CFR-192 The Code of Federal Regulations
Transportation of Natural and Other Gas By Pipeline Subpart G, J, N.
2014-October
My Self Study Exam Preparatory Notes
49
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Expert at Works
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Make it easy to read for foreign candidates like myself for API ICP exam:
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Experts at Works
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Charlie Chong/ Fion Zhang

Fion Zhang
2014/October
http://meilishouxihu.blog.163.com/
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THE REFERENCES BELOW WILL BE AVAILABLE TO APPLICANTS ON
THE COMPUTER SCREEN DURING THE EXAM:
Code of Federal Regulations (CFR)
• 29 CFR 1910, Occupational Safety and Health Standards,
Subparts H Article 119,
Subpart I (Excluding Subpart I Appendices) and
Subpart J Articles 145-147 (Excluding Appendices)
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• 29 CFR 1926, Safety and Health Regulations for Construction:
Subpart C Articles 20-29 and 32-35,
Subpart D Article 62 (Excluding Appendices),
Subpart F Article 152,
Subpart H Articles 250-251,
Subpart J Article 351-354, Subpart L Article 451,
Subpart M Article 500-501,
Subpart O 600, Subpart P,
Subpart U Article 900-902 and 914 and
Subpart CC Article 1417.
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• 40 CFR 112, Oil Pollution Prevention, Subpart A
• 40 CFR 122, EPA Administered Permit
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• 40 CFR 112, Oil Pollution Prevention, Subpart A
• 40 CFR 122, EPA Administered Permit Programs: The National Pollutant
Discharge Elimination System: Subpart A
• 49 CFR 192, Transportation of Natural and Other Gas by Pipeline:
Minimum Federal Safety Standards: Subparts G, J & N
• 49 CFR 195, Transportation of Hazardous Liquids by Pipeline: Subpart D
and Subpart E
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Environmental Protection Agency (EPA), National Pollutant Discharge
Elimination System General Permit for Discharges from Construction
Activities 2012
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49 CFR - Transportation
http://www.law.cornell.edu/cfr/text/49
Charlie Chong/ Fion Zhang
http://www.49cfr.info/index.html

Priority in the text
• (a), (b).....
• (1), (2)…..
• (i), (ii)…..
• (A), (B)…..
At works
Charlie Chong/ Fion Zhang

49 CFR 192 Subpart G, J, N.
Transportation of Natural and Other Gas By
Pipeline: Minimum Federal Safety Standards
THIS DOCUMENT CONTAINS ONLY THE SECTIONS
NEEDED FOR THE API 1169 ICP EXAMS
Formatted for My Self Study Exam Preparatory Notes
Charlie Chong/ Fion Zhang

Subpart G -
General Construction Requirements for
Transmission Lines and Mains
§192.301 Scope.
This subpart prescribes minimum requirements for constructing
transmission lines and mains.
§192.303 Compliance with specifications or standards.
Each transmission line or main must be constructed in accordance with
comprehensive written specifications or standards that are consistent with
this part.
Keywords:
■ Minimum;
■ Compliance with specifications;
■ Specifications Consistence with 49CFR;
Charlie Chong/ Fion Zhang

12333 Each transmission line or main must be constructed in accordance with
comprehensive written specifications or standards that are consistent with this
part.
Keywords:
• Compliance with specifications or standards;
• Specifications and standards in consistence with 49CFR;
Charlie Chong/ Fion Zhang

§192.305 Inspection: General.
Each transmission line or main must be inspected to ensure that it is
constructed in accordance with this part.
§192.307 Inspection of materials.
Each length of pipe and each other component must be visually inspected at
the site of installation to ensure that it has not sustained any visually
determinable damage that could impair its serviceability.
§192.309 Repair of steel pipe.
(a) Each imperfection or damage that impairs the serviceability of a length of
steel pipe must be repaired or removed. If a repair is made by grinding, the
remaining wall thickness must at least be equal to either:
(1) The minimum thickness required by the tolerances in the specification to
which the pipe was manufactured; or
(2) The nominal wall thickness required for the design pressure of the pipeline.
Charlie Chong/ Fion Zhang

Discussion
Topic: Differentiate the following:
(1) The minimum thickness required by the tolerances in the specification to
which the pipe was manufactured; or
(2) The nominal wall thickness required for the design pressure of the pipeline.
Charlie Chong/ Fion Zhang

(2) A dent that affects the longitudinal weld or a circumferential weld.
(3) In pipe to be operated at a pressure that produces a hoop stress of 40
percent or more of SMYS, a dent that has a depth of:
(i) More than ¼ inch (6.4 millimeters) in pipe 12 ¾ inches (324 millimeters) or
less in outer diameter; or
(ii) More than 2 percent of the nominal pipe diameter in pipe over 12 ¾
inches (324 millimeters) in outer diameter.
For the purpose of this section a “dent” is a depression that produces a gross
disturbance in the curvature of the pipe wall without reducing the pipe-wall
thickness. The depth of a dent is measured as the gap between the lowest
point of the dent and a prolongation of the original contour of the pipe.
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(c) Each arc burn on steel pipe to be operated at a pressure that produces a
hoop stress of 40 percent, or more, of SMYS must be repaired or removed. If
a repair is made by grinding, the arc burn must be completely removed and
the remaining wall thickness must be at least equal to either:
(1) The minimum wall thickness required by the tolerances in the specification
to which the pipe was manufactured; or
(2) The nominal wall thickness required for the design pressure of the pipeline.
(d) A gouge, groove, arc burn, or dent may not be repaired by insert patching
or by pounding out.
(e) Each gouge, groove, arc burn, or dent that is removed from a length of
pipe must be removed by cutting out the damaged portion as a cylinder.
[35 FR 13257, Aug. 19, 1970, as amended by Amdt. 192-1, 35 FR 17660,
Nov. 17, 1970; Amdt. 192-85, 63 FR 37503, July 13, 1998; Amdt. 192-88, 64
FR 69664, Dec. 14, 1999]
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Arc Burn
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Arc Burn
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Arc Strike- Arc Burn
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http://kriznoy.wordpress.com/2013/08/30/arc-strike/

Arc Strike- Arc Burn
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http://kriznoy.wordpress.com/2013/08/30/arc-strike/

Arc Strike- Arc Burn
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Arc Strike- Arc Burn
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http://met-tech.com/failure-analysis-of-ball-bearings.html

Arc Strike- Arc Burn
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Arc Strike- Arc Burn
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Discussion 1
Topic: How to ensure total removal of Arc Burn.
§192.309 (c) Each arc burn on steel pipe to be operated at a pressure that
produces a hoop stress of 40 percent, or more, of SMYS must be repaired or
removed. If a repair is made by grinding, the arc burn must be completely
removed and the remaining wall thickness must be at least equal to either:
Hints: Nitric acid 硝 酸
Topic: Defines; a gouge, groove, arc burn and dent.
(d) A gouge, groove, arc burn, or dent may not be repaired by insert patching
or by pounding out.
Charlie Chong/ Fion Zhang

Discussion 2
Topic: Why is arc strike is an important issue in pipeline welding?
§192.309 (e) Each gouge, groove, arc burn, or dent that is removed from a
length of pipe must be removed by cutting out the damaged portion as a
cylinder.
Hint: High strength API 5LX material grade.
Charlie Chong/ Fion Zhang

APL 5LX Pipe Technical Information.
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§192.311 Repair of plastic pipe.
Each imperfection or damage that would impair the serviceability of plastic
pipe must be repaired or removed.
[Amdt. 192-93, 68 FR 53900, Sept. 15, 2003]
Keywords:
■
Plastid Pipe
Charlie Chong/ Fion Zhang

Plastid Pipeline
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http://www.chings.co.nz/operations_pe_welding-1.html

Plastid Pipe
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§192.313 Bends and elbows.
Each field bend in steel pipe, other than a wrinkle bend made in accordance
with §192.315, must comply with the following:
(1) A bend must not impair the serviceability of the pipe.
(2) Each bend must have a smooth contour and be free from buckling, cracks,
or any other mechanical damage.
Keywords:
■
■
■
Wrinkle bend
Buckling
Crack
Charlie Chong/ Fion Zhang

Bend & Wrinkle Bend
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(3) On pipe containing a longitudinal weld, the longitudinal weld must be as
near as practicable to the neutral axis of the bend unless:
(i) The bend is made with an internal bending mandrel; or
(ii) The pipe is 12 inches (305 millimeters) or less in outside diameter or has a
diameter to wall thickness ratio less than 70.
Keywords:
• longitudinal weld must be as near as practicable to the neutral axis of the
bend
• Internal bend mandrel
• Diameter/ Wall thickness ratio ˂ 70
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Internal bending mandrel
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(b) Each circumferential weld of steel pipe which is located where the stress
during bending causes a permanent deformation in the pipe must be
nondestructively tested either before or after the bending process.
(c) Wrought-steel welding elbows and transverse segments of these elbows
may not be used for changes in direction on steel pipe that is 2 inches (51
millimeters) or more in diameter unless the arc length, as measured along the
crotch, is at least 1 inch (25 millimeters).
[Amdt. No. 192-26, 41 FR 26018, June 24, 1976, as amended by Amdt. 192-
29, 42 FR 42866, Aug. 25, 1977; Amdt. 192-29, 42 FR 60148, Nov. 25, 1977;
Amdt. 192-49, 50 FR 13225, Apr. 3, 1985; Amdt. 192-85, 63 FR 37503, July
13, 1998]
Charlie Chong/ Fion Zhang

Discussion
Topic: What is Wrought-steel welding elbows and transverse segments?
§§192.313 (c) Wrought-steel ( 锻 的 / 加 工 的 ) welding elbows (mitered bend?)
and transverse segments of these elbows may not be used for changes in
direction on steel pipe that is 2 inches (51 millimeters) or more in diameter
unless the arc length, as measured along the crotch, is at least 1 inch (25
millimeters).
Charlie Chong/ Fion Zhang

Discussion
Topic: How to perform NDT on the field pipe bended.
§§192.313 (b) Each circumferential weld of steel pipe which is located
where the stress during bending causes a permanent deformation in the pipe
must be nondestructively tested either before or after the bending process.
Charlie Chong/ Fion Zhang

§192.315 Wrinkle bends in steel pipe.
(a) A wrinkle bend may not be made on steel pipe to be operated at a
pressure that produces a hoop stress of 30 percent, or more, of SMYS.
(b) Each wrinkle bend on steel pipe must comply with the following:
(1) The bend must not have any sharp kinks.
(2) When measured along the crotch of the bend, the wrinkles must be a
distance of at least one pipe diameter.
(3) On pipe 16 inches (406 millimeters) or larger in diameter, the bend may
not have a deflection of more than 1 ½° for each wrinkle.
(4) On pipe containing a longitudinal weld the longitudinal seam must be as
near as practicable to the neutral axis of the bend.
[35 FR 13257, Aug. 19, 1970, as amended by Amdt. 192-85, 63 FR 37503,
July 13, 1998]
Charlie Chong/ Fion Zhang

Wrinkle bends
Charlie Chong/ Fion Zhang

§192.317 Protection from hazards.
(a) The operator must take all practicable steps to protect each transmission
line or main from washouts, floods, unstable soil, landslides, or other
hazards that may cause the pipeline to move or to sustain abnormal loads.
In addition, the operator must take all practicable steps to protect offshore
pipelines from damage by mud slides, water currents, hurricanes, ship
anchors, and fishing operations.
(b) Each aboveground transmission line or main, not located offshore or in
inland navigable water areas, must be protected from accidental damage
by vehicular traffic or other similar causes, either by being placed at a safe
distance from the traffic or by installing barricades.
(c) Pipelines, including pipe risers, on each platform located offshore or in
inland navigable waters must be protected from accidental damage by
vessels.
[Amdt. 192-27, 41 FR 34606, Aug. 16, 1976, as amended by Amdt. 192-78,
61 FR 28784, June 6, 1996]
Charlie Chong/ Fion Zhang

Remark: Each aboveground transmission line or main, not located
offshore or in inland navigable water areas, must be protected from accidental
damage by vehicular traffic or other similar causes, either by being placed at
a safe distance from the traffic or by installing barricades.
Charlie Chong/ Fion Zhang

Subsea Pipeline Trencher
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Subsea Pull Trencher
Charlie Chong/ Fion Zhang

Subsea Pipeline Trencher
Charlie Chong/ Fion Zhang
http://www.geocean.fr/2014/02/17/kalinda-shallow-water-pipelay-barge-support-mcdermott-safaniya-field/

Inland Pipeline Trencher
Charlie Chong/ Fion Zhang

§192.319 Installation of pipe in a ditch.
(a) When installed in a ditch, each transmission line that is to be operated at a
pressure producing a hoop stress of 20 percent or more of SMYS must be
installed so that the pipe fits the ditch so as to minimize stresses and
protect the pipe coating from damage.
(b) When a ditch for a transmission line or main is backfilled, it must be
backfilled in a manner that:
(1) Provides firm support under the pipe; and
(2) Prevents damage to the pipe and pipe coating from equipment or from the
backfill material.
Charlie Chong/ Fion Zhang

Pipe Bending: Pipeline operating at hoop stress of 20 percent or more of
SMYS must be installed so that the pipe fits the ditch so as to minimize
stresses and protect the pipe coating from damage.
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Pipe Bending: Pipeline operating at hoop stress of 20 percent or more of
SMYS must be installed so that the pipe fits the ditch so as to minimize
stresses and protect the pipe coating from damage.
Charlie Chong/ Fion Zhang

Field Pipe Bending
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§192.321 Installation of plastic pipe.
(a) Plastic pipe must be installed below ground level except as provided by
paragraphs (g) and (h) of this section.
(b) Plastic pipe that is installed in a vault ( 库 ) or any other below grade
enclosure must be completely encased in gas-tight metal pipe and fittings
that are adequately protected from corrosion.
(c) Plastic pipe must be installed so as to minimize shear or tensile stresses.
(d) Thermoplastic pipe that is not encased must have a minimum wall
thickness of 0.090 inch (2.29 millimeters), except that pipe with an outside
diameter of 0.875 inch (22.3 millimeters) or less may have a minimum wall
thickness of 0.062 inch (1.58 millimeters).
Charlie Chong/ Fion Zhang

(e) Plastic pipe that is not encased must have an electrically conducting wire
or other means of locating the pipe while it is underground. Tracer wire
may not be wrapped around the pipe and contact with the pipe must be
minimized but is not prohibited. Tracer wire or other metallic elements
installed for pipe locating purposes must be resistant to corrosion damage,
either by use of coated copper wire or by other means
(f) Plastic pipe that is being encased must be inserted into the casing pipe in
a manner that will protect the plastic. The leading end of the plastic must
be closed before insertion.
Charlie Chong/ Fion Zhang

(g) Uncased plastic pipe may be temporarily installed above ground level
under the following conditions:
(1) The operator must be able to demonstrate that the cumulative
aboveground exposure of the pipe does not exceed the manufacturer's
recommended maximum period of exposure or 2 years, whichever is less.
(2) The pipe either is located where damage by external forces is unlikely or is
otherwise protected against such damage.
(3) The pipe adequately resists exposure to ultraviolet light and high and low
temperatures.
Keywords:
• Period: Manufacturer recommendation or 2 years Maximum
• Damages from external mechanical source: Unlikely
• Damages from environments: UV, high & low temperature.
Charlie Chong/ Fion Zhang

h) Plastic pipe may be installed on bridges provided that it is:
(1) Installed with protection from mechanical damage, such as installation in a
metallic casing;
(2) Protected from ultraviolet radiation; and
(3) Not allowed to exceed the pipe temperature limits specified in §192.123.
[35 FR 13257, Aug. 19, 1970, as amended by Amdt. 192-78, 61 FR 28784,
June 6, 1996; Amdt. 192-85, 63 FR 37503, July 13, 1998; Amdt. 192-93, 68
FR 53900, Sept. 15, 2003; Amdt. 192-94, 69 FR 32895, June 14, 2004]
Charlie Chong/ Fion Zhang

§192.323 Casing.
Each casing used on a transmission line or main under a railroad or highway
must comply with the following:
(a) The casing must be designed to withstand the superimposed loads.
(b) If there is a possibility of water entering the casing, the ends must be
sealed.
(c) If the ends of an unvented casing are sealed and the sealing is strong
enough to retain the maximum allowable operating pressure of the pipe,
the casing must be designed to hold this pressure at a stress level of not
more than 72 percent of SMYS.
(d) If vents are installed on a casing, the vents must be protected from the
weather to prevent water from entering the casing.
Charlie Chong/ Fion Zhang

Road & Highway Crossing
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Road & Highway Crossing - Open Ends
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Road & Highway Crossing - Open Ends
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Road & Highway Crossing - Open Ends
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Pipeline Casing for Crossing
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Pipeline Casing for Crossing
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Pipeline Casing for Crossing
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Pipeline Casing for Crossing- Vented and un-vented
Charlie Chong/ Fion Zhang
http://www.farwestcorrosion.com/casing-spacers-seals/casing-fill/suggested-pipeline-casing-standard/

§192.325 Underground clearance.
(a) Each transmission line must be installed with at least 12 inches (305
millimeters) of clearance from any other underground structure not
associated with the transmission line. If this clearance cannot be attained,
the transmission line must be protected from damage that might result
from the proximity of the other structure.
(b) Each main must be installed with enough clearance from any other
underground structure to allow proper maintenance and to protect against
damage that might result from proximity to other structures.
(c) In addition to meeting the requirements of paragraph (a) or (b) of this
section, each plastic transmission line or main must be installed with
sufficient clearance, or must be insulated, from any source of heat so as to
prevent the heat from impairing the serviceability of the pipe.
(d) Each pipe-type or bottle-type holder must be installed with a minimum
clearance from any other holder as prescribed in §192.175(b).
[35 FR 13257, Aug. 19, 1970, as amended by Amdt. 192-85, 63 FR 37503,
July 13, 1998]
Charlie Chong/ Fion Zhang

Discussion
Topic: What is this?
§192.325 (d) Each pipe-type or bottle-type holder must be installed with a
minimum clearance from any other holder as prescribed in §192.175(b).
• Pipe-type?
• Bottle-type holder?
Charlie Chong/ Fion Zhang

§192.327 Cover.
(a) Except as provided in paragraphs (c), (e), (f), and (g) of this section, each
buried transmission line must be installed with a minimum cover as follows:
Location
Inches (Millimeters)
Class 1 locations
Class 2, 3, and 4 locations
Drainage ditches of public roads and railroad crossings
Normal soil
30 (762)
36 (914)
36 (914)
Consolidated rock
18 (457)
24 (610)
24 (610)
(b) Except as provided in paragraphs (c) and (d) of this section, each buried
main must be installed with at least 24 inches (610 millimeters) of cover.
(c) Where an underground structure prevents the installation of a
transmission line or main with the minimum cover, the transmission line or
main may be installed with less cover if it is provided with additional
protection to withstand anticipated external loads.
Charlie Chong/ Fion Zhang

(d) A main may be installed with less than 24 inches (610 millimeters) of
cover if the law of the State or municipality:
(1) Establishes a minimum cover of less than 24 inches (610 millimeters);
(2) Requires that mains be installed in a common trench with other utility lines;
and
(3) Provides adequately for prevention of damage to the pipe by external
forces.
Charlie Chong/ Fion Zhang

Pipeline Covers
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Pipeline Covers
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Pipeline Covers- Trench Breaker
Charlie Chong/ Fion Zhang
http://huckbody.com/?page_id=1088

Pipeline Covers – Consolidated Rock
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Pipeline Covers – Consolidated Rock
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Pipeline Covers
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Pipeline Covers- Main
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(e) Except as provided in paragraph (c) of this section, all pipe installed in a
navigable river, stream, or harbor must be installed with a minimum cover
of 48 inches (1,219 millimeters) in soil or 24 inches (610 millimeters) in
consolidated rock between the top of the pipe and the underwater natural
bottom (as determined by recognized and generally accepted practices).
Keywords:
Navigable River Crossing Covers:
• Soil: 48 inches minimum
• Consolidated rock: 24 inches minimum
Charlie Chong/ Fion Zhang

Navigable River Crossing Covers
Charlie Chong/ Fion Zhang

Navigable River Crossing Covers
Charlie Chong/ Fion Zhang

Navigable River Crossing Covers
Charlie Chong/ Fion Zhang

Navigable River Crossing Covers
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River Crossing Covers- Non Navigable River
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River Crossing Covers- Non Navigable River
Charlie Chong/ Fion Zhang

(f) All pipe installed offshore, except in the Gulf of Mexico and its inlets, under
water not more than 200 feet (60 meters) deep, as measured from the
mean low tide, must be installed as follows:
(1) Except as provided in paragraph (c) of this section, pipe under water less
than 12 feet (3.66 meters) deep, must be installed with a minimum cover of
36 inches (914 millimeters) in soil or 18 inches (457 millimeters) in
consolidated rock between the top of the pipe and the natural bottom.
(2) Pipe under water at least 12 feet (3.66 meters) deep must be installed so
that the top of the pipe is below the natural bottom, unless the pipe is
supported by stanchions, held in place by anchors or heavy concrete
coating, or protected by an equivalent means.
Keywords: Offshore Pipeline Covers
Water depth < 12 feet: 36 inches minimum cover
Water depth ≥ 12 feet: top of the pipe below natural bottom
Charlie Chong/ Fion Zhang

(g) All pipelines installed under water in the Gulf of Mexico and its inlets, as
defined in §192.3, must be installed in accordance with §192.612(b)(3).
[35 FR 13257, Aug. 19, 1970, as amended by Amdt. 192-27, 41 FR 34606,
Aug. 16, 1976; Amdt. 192-78, 61 FR 28785, June 6, 1996; Amdt. 192-85, 63
FR 37503, July 13, 1998; Amdt. 192-98, 69 FR 48406, Aug. 10, 2004]
Charlie Chong/ Fion Zhang

Charlie Chong/ Fion Zhang
Gulf of Mexico

Offshore Pipeline Covers- Heaps or Buckling
Pipe under water at least 12 feet (3.66 meters) deep must be installed so that
the top of the pipe is below the natural bottom, unless the pipe is supported
by stanchions, held in place by anchors or heavy concrete coating, or
protected by an equivalent means.
Charlie Chong/ Fion Zhang

Offshore Pipeline Covers
Pipe under water at least 12 feet (3.66 meters) deep must be installed so that
the top of the pipe is below the natural bottom, unless the pipe is supported
by stanchions, held in place by anchors or heavy concrete coating, or
protected by an equivalent means.
Charlie Chong/ Fion Zhang

Offshore Pipeline Covers
Pipe under water at least 12 feet (3.66 meters) deep must be installed so that
the top of the pipe is below the natural bottom, unless the pipe is supported
by stanchions, held in place by anchors or heavy concrete coating, or
protected by an equivalent means.
Charlie Chong/ Fion Zhang

Offshore Pipeline Covers
Pipe under water at least 12 feet (3.66 meters) deep must be installed so that
the top of the pipe is below the natural bottom, unless the pipe is supported
by stanchions, held in place by anchors or heavy concrete coating, or
protected by an equivalent means.
Charlie Chong/ Fion Zhang

Offshore Pipeline Covers
Pipe under water at least 12 feet (3.66 meters) deep must be installed so that
the top of the pipe is below the natural bottom, unless the pipe is supported
by stanchions, held in place by anchors or heavy concrete coating, or
protected by an equivalent means.
Charlie Chong/ Fion Zhang

Offshore Pipeline Covers
Pipe under water at least 12 feet (3.66 meters) deep must be installed so that
the top of the pipe is below the natural bottom, unless the pipe is supported
by stanchions, held in place by anchors or heavy concrete coating, or
protected by an equivalent means.
Charlie Chong/ Fion Zhang

Offshore Pipeline Covers
Pipe under water at least 12 feet (3.66 meters) deep must be installed so that
the top of the pipe is below the natural bottom, unless the pipe is supported
by stanchions, held in place by anchors or heavy concrete coating, or
protected by an equivalent means.
Charlie Chong/ Fion Zhang
https://www.nord-stream.com/press-info/images/supervising-of-concrete-coating-processat-eupec-concrete-weight-coating-plant-in-mukran-germany-2779/?page=20

Offshore Pipeline Covers
Pipe under water at least 12 feet (3.66 meters) deep must be installed so that
the top of the pipe is below the natural bottom, unless the pipe is supported
by stanchions, held in place by anchors or heavy concrete coating, or
protected by an equivalent means.
Charlie Chong/ Fion Zhang

Offshore Pipeline Covers
Pipe under water at least 12 feet (3.66 meters) deep must be installed so that
the top of the pipe is below the natural bottom, unless the pipe is supported
by stanchions, held in place by anchors or heavy concrete coating, or
protected by an equivalent means.
Charlie Chong/ Fion Zhang
https://www.nord-stream.com/press-info/images/supervising-of-concrete-coating-processat-eupec-concrete-weight-coating-plant-in-mukran-germany-2779/?page=20

Offshore Pipeline Covers
Pipe under water at least 12 feet (3.66 meters) deep must be installed so that
the top of the pipe is below the natural bottom, unless the pipe is supported
by stanchions, held in place by anchors or heavy concrete coating, or
protected by an equivalent means.
Charlie Chong/ Fion Zhang
https://www.nord-stream.com/press-info/images/supervising-of-concrete-coating-processat-eupec-concrete-weight-coating-plant-in-mukran-germany-2779/?page=20

Offshore Pipeline Covers
Pipe under water at least 12 feet (3.66 meters) deep must be installed so that
the top of the pipe is below the natural bottom, unless the pipe is supported
by stanchions, held in place by anchors or heavy concrete coating, or
protected by an equivalent means.
Charlie Chong/ Fion Zhang

Offshore Lay Barge – Non self navigating
Charlie Chong/ Fion Zhang

Offshore Lay Barge with support vessels
Charlie Chong/ Fion Zhang

Offshore Lay Barge with support vessels
Charlie Chong/ Fion Zhang

Offshore Pipeline Barge
Charlie Chong/ Fion Zhang

Offshore Pipeline Barge
Charlie Chong/ Fion Zhang

Offshore Pipeline Barge
Charlie Chong/ Fion Zhang

Offshore Pipeline Barge
Charlie Chong/ Fion Zhang

Offshore Pipeline Barge
Charlie Chong/ Fion Zhang

Subsea Pipeline Trencher
Charlie Chong/ Fion Zhang
http://www.cnoocengineering.com/en/single_news_content.aspx?news_id=12343

Offshore Pipeline Trencher
Charlie Chong/ Fion Zhang

Offshore Pipeline Trencher
Charlie Chong/ Fion Zhang

Offshore Pipeline Trencher
Charlie Chong/ Fion Zhang

Offshore Pipeline Trencher
Charlie Chong/ Fion Zhang

Offshore Pipeline Mats
Charlie Chong/ Fion Zhang

Offshore Pipeline Mats
Charlie Chong/ Fion Zhang

Offshore Pipeline Mats
Charlie Chong/ Fion Zhang

§192.328 Additional construction requirements for steel pipe using
alternative maximum allowable operating pressure.
For a new or existing pipeline segment to be eligible for operation at the
alternative maximum allowable operating pressure calculated under
§192.620, a segment must meet the following additional construction
requirements. Records must be maintained, for the useful life of the pipeline,
demonstrating compliance with these requirements:
Charlie Chong/ Fion Zhang

To address this
construction issue:
(a) Quality assurance
The pipeline segment must meet this additional construction
requirement:
(1) The construction of the pipeline segment must be done under a
quality assurance plan addressing pipe inspection, hauling and
stringing, field bending, welding, non‐destructive examination of
girth welds, applying and testing field applied coating, lowering of
the pipeline into the ditch, padding and backfilling, and hydrostatic
testing.
(2) The quality assurance plan for applying and testing field applied
coating to girth welds must be:
(i) Equivalent to that required under §192.112(f)(3) for pipe; and
(ii) Performed by an individual with the knowledge, skills, and ability
to assure effective coating application.
(b) Girth welds
(1) All girth welds on a new pipeline segment must be nondestructively
examined in accordance with §192.243(b) and (c).
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(c) Depth of cover
(1) Notwithstanding any lesser depth of cover otherwise allowed in
§192.327, there must be at least 36 inches (914 millimeters) of cover
or equivalent means to protect the pipeline from outside force
damage.
(2) In areas where deep tilling or other activities could threaten
the pipeline, the top of the pipeline must be installed at least one
foot below the deepest expected penetration of the soil.
(d) Initial strength
testing
(1) The pipeline segment must not have experienced failures indicative
of systemic material defects during strength testing, including initial
hydrostatic testing. A root cause analysis, including metallurgical
examination of the failed pipe, must be performed for any failure
experienced to verify that it is not indicative of a systemic concern.
The results of this root cause analysis must be reported to each
PHMSA pipeline safety regional office where the pipe is in service at
least 60 days prior to operating at the alternative MAOP. An operator
must also notify a State pipeline safety authority when the pipeline is
located in a State where PHMSA has
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(e) Interference
currents
(1) For a new pipeline segment, the construction must address the
impacts of induced alternating current from parallel electric
transmission lines and other known sources of potential interference
with corrosion control.
[72 FR 62176, Oct. 17, 2008]
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Tilling Soil
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PHMSA- U.S. Department of Transportation (DOT)
Pipeline and Hazardous Materials
Safety Administration
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Tilling Soil
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Discussion
Topic: What is §192.620
Answer: Read http://www.gpo.gov/fdsys/pkg/CFR-2009-title49-vol3/pdf/CFR-
2009-title49-vol3-sec192-620.pdf
1. What is the alternative MAOP Rule?
The alternate MAOP Rule was promulgated ( 颁 布 ) by PHMSA to allow certain
gas transmission pipelines to operate at higher pressures and pipeline stress
levels than regulations previously allowed if certain conditions are met that
ensure an adequate margin of safety. By allowing pipelines to operate at
higher pressures and stress levels, greater efficiencies and gas product
throughput can be achieved (73 FR 62148). ………& more…
More on http://primis.phmsa.dot.gov/maop/faqs.htm
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Subpart J -
Test Requirements
§192.501 Scope.
This subpart prescribes minimum leak-test and strength-test requirements for
pipelines.
§192.503 General requirements.
(a) No person may operate a new segment of pipeline, or return to service a
segment of pipeline that has been relocated or replaced, until –
(1) It has been tested in accordance with this subpart and §192.619 to
substantiate the maximum allowable operating pressure; and
(2) Each potentially hazardous leak has been located and eliminated.
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(b) The test medium must be liquid, air, natural gas, or inert gas that is –
(1) Compatible with the material of which the pipeline is constructed;
(2) Relatively free of sedimentary materials; and
(3) Except for natural gas, nonflammable.
(c) Except as provided in §192.505(a), if air, natural gas, or inert gas is used
as the test medium, the following maximum hoop stress limitations apply:
Class location
Maximum hoop stress allowed as percentage of SMYS
Natural gas
Air or inert gas
1
2
3
4
80
30
30
30
80
75
50
40
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(d) Each joint used to tie in a test segment of pipeline is excepted from the
specific test requirements of this subpart, but each non-welded joint must be
leak tested at not less than its operating pressure.
[35 FR 13257, Aug. 19, 1970, as amended by Amdt. 192-58, 53 FR 1635, Jan.
21, 1988; Amdt. 192-60, 53 FR 36029, Sept. 16, 1988; Amdt. 192-60A, 54 FR
5485, Feb. 3, 1989]
Charlie Chong/ Fion Zhang

Discussion
Topic: The quoted Maximum hoop stress allowed as % of SMYS, is it meant
for testing?
Class location
Maximum hoop stress allowed as percentage of SMYS
1
2
Natural gas
80
30
Air or inert gas
80
75
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§ 192.5 Class locations.
(a) This section classifies pipeline locations for purposes of this part. The
following criteria apply to classifications under this section.
(1) A “class location unit” is an onshore area that extends 220 yards (200
meters) on either side of the centerline of any continuous 1- mile (1.6
kilometers) length of pipeline.
(2) Each separate dwelling unit in a multiple dwelling unit building is counted
as a separate building intended for human occupancy.
pipeline
220 yards
220 yards
1 mile/ 1.6 KM
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http://www.law.cornell.edu/cfr/text/49/192.5

(b) Except as provided in paragraph (c) of this section, pipeline locations are
classified as follows:
(1) A Class 1 location is:
(i) An offshore area; or
(ii) Any class location unit that has 10 or fewer buildings intended for human
occupancy.
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(2) A Class 2 location is any class location unit that has more than 10 but
fewer than 46 buildings intended for human occupancy.
(3) A Class 3 location is:
(i) Any class location unit that has 46 or more buildings intended for human
occupancy; or
(i) An area where the pipeline lies within 100 yards (91 meters) 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 20 or more persons on at least 5 days a week for 10 weeks in
any 12-month period. (The days and weeks need not be consecutive.)
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(4) A Class 4 location is any class location unit where buildings with four (4)
or more stories above ground are prevalent.
(c) The length of Class locations 2, 3, and 4 may be adjusted as follows:
(1) A Class 4 location ends 220 yards (200 meters) from the nearest building
with four or more stories above ground.
(2) When a cluster of buildings intended for human occupancy requires a
Class 2 or 3 location, the class location ends 220 yards (200 meters) from
the nearest building in the cluster.
[Amdt. 192-78, 61 FR 28783, June 6, 1996; 61 FR 35139, July 5, 1996, as
amended by Amdt. 192-85, 63 FR 37502, July 13, 1998]
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§192.505 Strength test requirements for steel pipeline to operate at a
hoop stress of 30 percent or more of SMYS.
(a) Except for service lines, each segment of a steel pipeline that is to operate
at a hoop stress of 30 percent or more of SMYS must be strength tested in
accordance with this section to substantiate the proposed maximum
allowable operating pressure.
In addition, in a Class 1 or Class 2 location, if there is a building intended for
human occupancy within 300 feet (91 meters) of a pipeline, a hydrostatic test
must be conducted to a test pressure of at least 125 percent of maximum
operating pressure on that segment of the pipeline within 300 feet (91 meters)
of such a building, but in no event may the test section be less than 600 feet
(183 meters) unless the length of the newly installed or relocated pipe is less
than 600 feet (183 meters).
However, if the buildings are evacuated while the hoop stress exceeds 50
percent of SMYS, air or inert gas may be used as the test medium.
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(b) In a Class 1 or Class 2 location, each compressor station regulator station,
and measuring station, must be tested to at least Class 3 location test
requirements.
(c) Except as provided in paragraph (e) of this section, the strength test must
be conducted by maintaining the pressure at or above the test pressure
for at least 8 hours.
(d) If a component other than pipe is the only item being replaced or added to
a pipeline, a strength test after installation is not required, if the
manufacturer of the component certifies that-
(1) The component was tested to at least the pressure required for the
pipeline to which it is being added;
(2) The component was manufactured under a quality control system that
ensures that each item manufactured is at least equal in strength to a
prototype and that the prototype was tested to at least the pressure
required for the pipeline to which it is being added; or
(3) The component carries a pressure rating established through applicable
ASME/ANSI, MSS specifications, or by unit strength calculations as
described in §192.143.
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(e) For fabricated units and short sections of pipe, for which a post installation
test is impractical, a preinstallation strength test must be conducted by
maintaining the pressure at or above the test pressure for at least 4 hours.
[35 FR 13257, Aug. 19, 1970, as amended by Amdt. 192-85, 63 FR 37504,
July 13, 1998; Amdt. 192-94, 69 FR 32895, June 14, 2004; Amdt. 195-94, 69
FR 54592, Sept. 9, 2004]
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Keywords: Testing pressure & Medium
• Operating condition: 30% of SMYS;
• Area Class: 1 or 2;
• Occupancy criteria: a building within 300 feet within pipe center line;
• Testing requirements: Hydrostatic testing at 125% of MOP.
• Exclusion: However, if the buildings are evacuated while the hoop stress
exceeds 50 percent of SMYS, air or inert gas may be used as the test
medium.
Question: Area Class 2 & 4 what are the testing requirements?
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Keywords: Test Duration at rated pressure
Operating condition: 30% of SMYS;
• the strength test must be conducted by maintaining the pressure at or
above the test pressure for at least 8 hours.
• For fabricated units and short sections of pipe, for which a post installation
test is impractical, a pre-installation strength test must be conducted by
maintaining the pressure at or above the test pressure for at least 4 hours.
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§192.505 However, if the buildings are evacuated while the hoop stress
exceeds 50 percent of SMYS, air or inert gas may be used as the test
medium.
Charlie Chong/ Fion Zhang
http://portolaplanet.com/2012/06/pge-pipeline-testing-keeps-the-portola-safe/

§192.507 Test requirements for pipelines to operate at a hoop stress
less than 30 percent of SMYS and at or above 100 p.s.i. (689 kPa) gage.
Except for service lines and plastic pipelines, each segment of a pipeline that
is to be operated at a hoop stress less than 30 percent of SMYS and at or
above 100 p.s.i. (689 kPa) gage must be tested in accordance with the
following:
(a) The pipeline operator must use a test procedure that will ensure discovery
of all potentially hazardous leaks in the segment being tested.
(b) If, during the test, the segment is to be stressed to 20 percent or more of
SMYS and natural gas, inert gas, or air is the test medium -
(1) A leak test must be made at a pressure between 100 p.s.i. (689 kPa) gage
and the pressure required to produce a hoop stress of 20 percent of SMYS;
or
(2) The line must be walked to check for leaks while the hoop stress is held at
approximately 20 percent of SMYS.
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(c) The pressure must be maintained at or above the test pressure for at
least 1 hour.
[35 FR 13257, Aug. 19, 1970, as amended by Amdt. 192-58, 53 FR 1635, Jan.
21, 1988; Amdt. 192-85, 63 FR 37504, July 13, 1998]
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§192.509 Test requirements for pipelines to operate below 100 p.s.i.
(689 kPa) gage. Except for service lines and plastic pipelines, each
segment of a pipeline that is to be operated below 100 p.s.i. (689 kPa)
gage must be leak tested in accordance with the following:
(a) The test procedure used must ensure discovery of all potentially
hazardous leaks in the segment being tested.
(b) Each main that is to be operated at less than 1 p.s.i. (6.9 kPa) gage must
be tested to at least 10 p.s.i. (69 kPa) gage and each main to be operated
at or above 1 p.s.i. (6.9 kPa) gage must be tested to at least 90 p.s.i. (621
kPa) gage.
[35 FR 13257, Aug. 19, 1970, as amended by Amdt. 192-58, 53 FR 1635, Jan.
21, 1988; Amdt. 192-85, 63 FR 37504, July 13, 1998]
Charlie Chong/ Fion Zhang

§192.511 Test requirements for service lines.
(a) Each segment of a service line (other than plastic) must be leak tested in
accordance with this section before being placed in service. If feasible, the
service line connection to the main must be included in the test; if not
feasible, it must be given a leakage test at the operating pressure when
placed in service.
(b) Each segment of a service line (other than plastic) intended to be operated
at a pressure of at least 1 p.s.i. (6.9 kPa) gage but not more than 40 p.s.i.
(276 kPa) gage must be given a leak test at a pressure of not less than 50
p.s.i. (345 kPa) gage.
(c) Each segment of a service line (other than plastic) intended to be operated
at pressures of more than 40 p.s.i. (276 kPa) gage must be tested to at
least 90 p.s.i. (621 kPa) gage, except that each segment of a steel service
line stressed to 20 percent or more of SMYS must be tested in accordance
with §192.507 of this subpart.
[35 FR 13257, Aug. 19, 1970, as amended by Amdt. 192-74, 61 FR 18517,
Apr. 26, 1996; Amdt. 192-85, 63 FR 37504, July 13, 1998]
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§192.513 Test requirements for plastic pipelines.
(a) Each segment of a plastic pipeline must be tested in accordance with this
section.
(b) The test procedure must insure discovery of all potentially hazardous leaks
in the segment being tested.
(c) The test pressure must be at least 150 percent of the maximum operating
pressure or 50 p.s.i. (345 kPa) gage, whichever is greater. However, the
maximum test pressure may not be more than three times the pressure
determined under §192.121, at a temperature not less than the pipe
temperature during the test.
(d) During the test, the temperature of thermoplastic material may not be more
than 100 °F (38 °C), or the temperature at which the material's long-term
hydrostatic strength has been determined under the listed specification,
whichever is greater.
[35 FR 13257, Aug. 19, 1970, as amended by Amdt. 192-77, 61 FR 27793,
June 3, 1996; 61 FR 45905, Aug. 30, 1996; Amdt. 192-85, 63 FR 37504, July
13, 1998]
Charlie Chong/ Fion Zhang

§192.515 Environmental protection and safety requirements.
(a) In conducting tests under this subpart, each operator shall insure that
every reasonable precaution is taken to protect its employees and the
general public during the testing. Whenever the hoop stress of the
segment of the pipeline being tested will exceed 50 percent of SMYS, the
operator shall take all practicable steps to keep persons not working on
the testing operation outside of the testing area until the pressure is
reduced to or below the proposed maximum allowable operating pressure.
(b) The operator shall insure that the test medium is disposed of in a manner
that will minimize damage to the environment.
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§192.517 Records.
(a) Each operator shall make, and retain for the useful life of the pipeline, a
record of each test performed under §§192.505 and 192.507. The record
must contain at least the following information:
(1) The operator's name, the name of the operator's employee responsible for
making the test, and the name of any test company used.
(2) Test medium used.
(3) Test pressure.
(4) Test duration.
(5) Pressure recording charts, or other record of pressure readings.
(6) Elevation variations, whenever significant for the particular test.
(7) Leaks and failures noted and their disposition.
(b) Each operator must maintain a record of each test required by
§§192.509, 192.511, and 192.513 for at least 5 years.
[35 FR 13257, Aug. 19, 1970, as amended by Amdt. 192-93, 68 FR 53901,
Sept. 15, 2003]
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Pipeline Testing
Charlie Chong/ Fion Zhang

Pipeline Testing
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http://joyce-road.blogspot.com/2012/05/pipeline-construction_19.html

Pipeline Testing
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Subpart N –
Qualification of Pipeline Personnel
SOURCE: Amdt. 192-86, 64 FR 46865, Aug. 27, 1999, unless otherwise
noted.
§192.801 Scope.
(a) This subpart prescribes the minimum requirements for operator
qualification of individuals performing covered tasks on a pipeline
facility.
(a) For the purpose of this subpart, a covered task is an activity, identified by
the operator, that:
(1) Is performed on a pipeline facility;
(2) Is an operations or maintenance task;
(3) Is performed as a requirement of this part; and
(4) Affects the operation or integrity of the pipeline.
Charlie Chong/ Fion Zhang

Subpart N –
Qualification of Pipeline Personnel
SOURCE: Amdt. 192-86, 64 FR 46865, Aug. 27, 1999, unless otherwise
noted.
§192.801 Scope.
(a) This subpart prescribes the minimum requirements for operator
qualification of individuals performing covered tasks on a pipeline facility.
(b) For the purpose of this subpart, a covered task is an activity, identified by
the operator, that:
(1) Is performed on a pipeline facility;
(2) Is an operations or maintenance task;
(3) Is performed as a requirement of this part; and
(4) Affects the operation or integrity of the pipeline.
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§192.803 Definitions.
Abnormal operating condition means a condition identified by the operator
that may indicate a malfunction of a component or deviation from normal
operations that may:
(a) Indicate a condition exceeding design limits; or
(b) Result in a hazard(s) to persons, property, or the environment.
Evaluation means a process, established and documented by the operator,
to determine an individual's ability to perform a covered task by any of the
following:
(a) Written examination;
(b) Oral examination;
(c) Work performance history review;
(d) Observation during:
(1) Performance on the job,
(2) On the job training, or
(3) Simulations;
(e) Other forms of assessment.
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Qualified means that an individual has been evaluated and can:
(a) Perform assigned covered tasks; and
(b) Recognize and react to abnormal operating conditions.
[Amdt. 192-86, 64 FR 46865, Aug. 27, 1999, as amended by Amdt. 192-90,
66 FR 43523, Aug. 20, 2001]
Keywords:
(a) Perform assigned covered tasks; and
(b) Recognize and react to abnormal operating conditions.
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Keywords:
Qualified means that an individual has been evaluated and can:
(a) Perform assigned covered tasks; and
(b) Recognize and react to abnormal operating conditions.
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On the Job Training
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§192.805 Qualification program.
Each operator shall have and follow a written qualification program. The
program shall include provisions to:
(a) Identify covered tasks;
(b) Ensure through evaluation that individuals performing covered tasks are
qualified;
(c) Allow individuals that are not qualified pursuant ( 按 照 ) to this subpart to
perform a covered task if directed and observed by an individual that is
qualified;
(d) Evaluate an individual if the operator has reason to believe that the
individual's performance of a covered task contributed to an incident as
defined in Part 191;
(e) Evaluate an individual if the operator has reason to believe that the
individual is no longer qualified to perform a covered task;
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(f) Communicate changes that affect covered tasks to individuals performing
those covered tasks;
(g) Identify those covered tasks and the intervals at which evaluation of the
individual's qualifications is needed;
(h) After December 16, 2004, provide training, as appropriate, to ensure that
individuals performing covered tasks have the necessary knowledge and
skills to perform the tasks in a manner that ensures the safe operation of
pipeline facilities; and
(i) After December 16, 2004, notify the Administrator or a state agency
participating under 49 U.S.C. Chapter 601 if the operator significantly
modifies the program after the Administrator or state agency has verified
that it complies with this section.
[Amdt. 192-86, 64 FR 46865, Aug. 27, 1999, as amended by Amdt. 192-100,
70 FR 10335, Mar. 3, 2005]
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Keywords:
Provisions on evaluations of:
Qualified personnel
No longer qualified.
Training provision after December 16, 2004
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§192.807 Recordkeeping.
Each operator shall maintain records that demonstrate compliance with this
subpart.
(a) Qualification records shall include:
(1) Identification of qualified individual(s);
(2) Identification of the covered tasks the individual is qualified to perform;
(3) Date(s) of current qualification; and
(4) Qualification method(s).
(b) Records supporting an individual's current qualification shall be
maintained while the individual is performing the covered task. Records of
prior qualification and records of individuals no longer performing covered
tasks shall be retained for a period of five years.
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§192.809 General.
(a) Operators must have a written qualification program by April 27, 2001. The
program must be available for review by the Administrator or by a state
agency participating under 49 U.S.C. Chapter 601 if the program is under
the authority of that state agency.
(b) Operators must complete the qualification of individuals performing
covered tasks by October 28, 2002.
(c) Work performance history review may be used as a sole evaluation
method for individuals who were performing a covered task prior to
October 26, 1999.
(d) After October 28, 2002, work performance history may not be used as a
sole evaluation method.
(e) After December 16, 2004, observation of on-the-job performance may not
be used as the sole method of evaluation.
[Amdt. 192-86, 64 FR 46865, Aug. 27, 1999, as amended by Amdt. 192-90,
66 FR 43524, Aug. 20, 2001; Amdt. 192-100, 70 FR 10335, Mar. 3, 2005]
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Keywords:
• Work performance history review
• Observation of on-the-job performance
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49 CFR-192 Numbers to be remembered
Some numbers to
be remember – at
least knowing
where to find them.
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49CFR §192.309 (b) Repair of steel pipe.
(2) A dent that affects the longitudinal weld or a circumferential weld.
(3) In pipe to be operated at a pressure that produces a hoop stress of 40
percent or more of SMYS, a dent that has a depth of:
(i) More than ¼ inch (6.4 millimeters) in pipe 12 ¾ inches (324 millimeters) or
less in outer diameter; or
(ii) More than 2 percent of the nominal pipe diameter in pipe over 12 ¾
inches (324 millimeters) in outer diameter.
For the purpose of this section a “dent” is a depression that produces a gross
disturbance in the curvature of the pipe wall without reducing the pipe-wall
thickness. The depth of a dent is measured as the gap between the lowest
point of the dent and a prolongation of the original contour of the pipe.
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§192.319 Installation of pipe in a ditch.
When installed in a ditch, each transmission line that is to be operated at a
pressure producing a hoop stress of 20 percent or more of SMYS must be
installed so that the pipe fits the ditch so as to minimize stresses and protect
the pipe coating from damage.
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§192.325 Underground clearance.
Each transmission line must be installed with at least 12 inches (305
millimeters) of clearance from any other underground structure not
associated with the transmission line. If this clearance cannot be attained,
the transmission line must be protected from damage that might result
from the proximity of the other structure.
Charlie Chong/ Fion Zhang

Charlie Chong/ Fion Zhang