POF_specs_200Specifications and requirements for intelligent pig inspection of pipelines
PM9 - Difficult to Pig Pipelines
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Transcript of PM9 - Difficult to Pig Pipelines
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David WintManager, Global Services Development
TDW Services, [email protected]
Difficult to Pig Pipelines
May 18, 2011
Appalachian Underground Corrosion Short Course
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Regulations
• In 1994 §192.150 / §195.120 regulations were passed that required each new transmission line and each replacement of line pipe, valve, fitting, or other line component in a transmission line must be designed and constructed to accommodate the passage of instrumented internal inspection devices.
• Design & Construction Standards to reduce internal corrosion on Gas Transmission Pipelines –Final Rule May 23, 2007– New and replaced gas transmission pipelines must be
configured to reduce the risk that liquids will collect in the line
– Have effective liquid removal features
– Allow use of corrosion monitoring devices in locations with significant potential for internal corrosion
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What is Pigging ?
A widely utilized process which is the act ofpropelling a properly sized spherical orcylindrical device through the interior of apipeline by manipulating the pressure & flowof the existing media, or by artificiallyintroduced media or by mechanically pullingthe device through the pipeline for thespecific purpose of cleaning, inspecting ordistributing inhibitor throughout the pipeline.
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Why Pig a Pipeline
During the 1940s pipelines in the United Stateswere mainly pigged to remove paraffin to increaseefficiency in crude oil pipelines in order tomaximize flow conditions for the war effort. Thepigging equipment utilized at that time was limitedto a few applications while being very crude innature. In today's world, pipelines are pigged for avariety of reasons and the pigging equipment usedis designed by engineers to perform particularfunctions.
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Piggability
• Physical Characteristics (Pipeline Design)
• Line Pipe Grade
• Type of Welds
• Length
• Fittings
• Internal Diameter
• Elevation Profile
• Tees
• Bends
• Valves
• Spans
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Piggability
Line Pipe Grade
Class Location Definition§192.5
The class location unit is an onshore area that extends 220 yards on either side of the centerline of any continuous1-mile length of pipeline.
The class location is determined by the buildings in the class location unit. For the purposes of this section, each separate dwelling unit in a multiple dwelling building is counted as a separate building intended for human occupancy.
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A Class 1 = 10 or less buildings intended for human occupancy or an offshore area.
A Class 2 = Greater that 10 but less than 46 buildings intended for human occupancy.
A Class 3 = 46 or more buildings intended for human occupancy; or
Piggability
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Class 3 - where the pipeline lies within 100 yards of either a building or a small, well-defined Outside Area
– Playground– Recreation Area– Outdoor Theater
Occupied by 20 or more persons on at least 5 days a week for 10 weeks in any 12-month period
Piggability
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Class 4 - where buildings with four or
more stories aboveground are
prevalent.
Piggability
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§192.105 - Design of Steel Pipe
P = Design Pressure
S = Yield Strength
D = Outside Diameter
t = Wall Thickness
F = Design factor - §192.111
E = Longitudinal joint factor - §192.113
T = Temperature de-rating factor - §192.115
P = (2St/D)(F)(E)(T)
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P=2St (F)
D
Class location Design factor (F)
1 .72
2 .60
3 .50
4 .40
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Type of Welds (Connections)
• Acetylene welding was first used around 1911 to join pipe segments together (girth welding) and just prior to 1920, arc welding was introduced.
• Chills Rings are sometimes called backup rings or spacers. These rings are machined pieces of metal that conform to the dimensions of the joint design used. Bell-to-bell joints that were welded together with the use of a chill ring.
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Type of Welds (Connections)Chill Rings
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Type of Welds (Connections)Dresser Coupling
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Types of Welds (Connection)Dresser Coupling Pumpkin Repair Sleeve
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Types of Welds (Connection)Zap-Lok Connections
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PiggabilityLength
The distance between two pig traps is a variable and must be determined for each specific pipeline.
Some considerations:– Wear on the Pigs
– Pipeline Product
The following pipeline lengths are not uncommon;–Natural Gas pipelines 50-100 miles between traps
–Refined Products Pipelines 100-150 miles between traps
–Crude Oil Pipelines 150-200 miles between traps
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PiggabilityDual Diameter Pipelines
Pipelines that have been designed toaccept input along their length may needto increase in diameter as the through-put increases. Instead of having trapsinstalled at each change in pipe sizereducers are used. Concentric reducersshould be used for changes in diameterwithin a pipeline so that the center line ofthe pig can remain on the same plane asit makes the transition from one size toanother.
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PiggabilityDual Diameter Pipelines
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Piggability
Reducers – Typical Applications
Concentric - used in line Eccentric - used in Traps
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PiggabilityLinings
Pipelines are lined to help protect theinside of the pipe from the effects of theproduct and to create less flowresistance. Natural gas pipelines areusually internally coated with an epoxyfusion bonded coating applied undercontrolled conditions at the factory or aspecial field site. Wire brush pigs shouldnot be used on pipelines that have beeninternally coated. A combination ofUrethane blades,discs and cups shouldbe used for maintenance pigging.
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Piggability
Examples of common Factory Bends w/ 5D, 3D and 1.5D Radius
Miter Bends are veryuncommon in the gasindustry and are locatedas a result of In LineInspection
Greater than 5D FactoryBends and/or FieldBends can be producedw/ a little advancedplanning
Bends
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PiggabilityBends
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PiggabilityBends
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PiggabilityMiter Bends
Miter bends are made by cutting the end of the pipe at an angle to achieve a change in direction of the pipe. In general miter bends should be avoided if you intend to pig the pipeline. If for some reason there is a miter bend in the line you should contact your pig supplier and give them the dimensions of the miter bend so they can determine if your pig will pass through the miter bend.
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PiggabilityDiameter and Wall Thickness
One of the largest cost of a pipeline is the costof the pipe. In the process of the designengineering phase the through-put is used todetermine the pipe diameter and the pipe wallthickness.
The wall thickness may vary due to externalconditions such as High Consequence Area’s,Road Crossings, Railroad Crossings, etc.
As long as the wall thickness is such that theinside pipe diameter is within the tolerancesallowed by the pig manufacturer the varyingwall thickness should not be a problem.
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Piggability
Tees with outlets greater than 50% of themain diameter should be barred to reducethe risk of sticking pigs. This is especially truein laterals with high flow conditions
Tees
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PiggabilityOff-Takes
Unbarred Tees
Forged tees are usually used for installing offtakes (outlets) in a pipeline during construction.Most conventional pigs will safely transverse teeswith outlets up to 60% of the nominal line size.However it is good practice to install guide bars inall outlets above 50%.
Off takes should not be installed adjacent to oneanother. At least three diameters of straight pipeshould be installed between any two fittings.
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Piggability
Pigs can typically beconfigured to accommodateback to back laterals bylengthening the pig to avoidmodification of the laterals
A perfect condition
for a “stalled pig”
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PiggabilityBarred Tees
Any off take that is more than 50% of thepipeline size should have bars installed toassist the pig past the opening without anydamage.
The bars should be installed parallel to the axisof the pipe and spaced from about 2” apart forsmall off takes to about 4” apart for larger sizes.
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PiggabilityLaterals/Tees
Generic Suggestions for Barred Tees:
► 4” to 8” laterals – 1 single bar centered in tapped hole.
► 4” thru 10” Laterals w/ bars ¼” thick
► 10” and larger laterals – 2 bars equally separated in tapped hole.
► 12” and larger laterals bars ½” thick
Minimum Requirements
Conservative Specifications
► 4” thru 10” - ¼ ” bars w/ 2” spacing
► 12” and larger – ½” bars w/ 2” spacing
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PiggabilityValves
Valves are the biggest single cause ofpigging problems. Full bore valves are moreor less essential. If gate valves must be used,they should be the through conduit type sothat no voids, seat rings or other features arepresent which might affect the smoothpassage of a pig. The inlet and outlet boresmust also be concentric.
If wedge gate or parallel slide valves areinstalled, it is important to know thedimensions of the gap between the seat ringsto be able to select the proper pig for the line.
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PiggabilitySeat Ring Spacing
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Piggability
Valves
Valves can be a significant source of aggravationrelative to Stuck Pigs. Appropriately designedvalves should be considered when making pipingsystems piggable. Full bore or Pipeline ID isrecommended.
Solid Ball Hollow Ball Thru-port Gate Wedge Gate Tapered Plug
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PiggabilityCheck Valves
By the nature of their design, check valves require
an area in the valve body that is larger that the pipe
inside diameter. This requires the cups and/or discs
on the pig to be spaced far enough apart to span
the oversized area in the valve body. In addition the
pig must provide the force required to open the
check valve fully for it to pass through.
Spheres are not suitable for pigging lines with check
valves. The sphere will drop into the oversize body
and bypass. You must use the bump and run
method if you are going to pig with spheres.
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PiggabilityCheck Valves
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PiggabilityCheck Valves
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PiggabilityElevation
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PiggabilityElevation
Pipe
Receiver
a
c
b
Depth of Cover (DOC)
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PiggabilitySpans
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Piggability Spans
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Piggability Non-Engineered Spans
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Piggability Drips
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Piggability Drips
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PiggabilityOther
Intrusive Repairs – Pipeline Carrot
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Piggability Other
Siphons
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PiggabilityOther
Coupon Holders
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Piggability Operations
A common approach is to pressurize the whole pipeline and run the pig by venting at the downstream end, maintaining a certain minimum pressure in front of the pig to act as a buffer.In reality, a specific minimum pressure cannot be stated as both the diameter and condition of the pipeline must be considered. The suppliers will always discuss this aspect during the planning stage for each instrument pig survey.
Pressure
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Piggability Operations
Typical Differential Pressure (DP) Required to Drive a pig:
DP (bars) = K (type of pig)
Nominal Diameter (inches)
K (Types of Pigs)
• Sphere and Foam Pig = 1
• 2 Cup Pig = 4
• 4 Cup Pig = 7
• Disc Pig = 9
• Cup Brush Pig = 12
• Disc Brush Pig = 15
• UT ILI Tool = 19
• MFL ILI Tool = 24
Pressure
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Piggability Operations
Typical Differential Pressure (DP) Required to Drive a pig:
DP (bars) = K (type of pig)
Nominal Diameter (inches)
Example: 10-inch Disc Brush Pig (K factor = 15)
DP (bars) = 15
10-inch
1.5 bars x 14.5 psi = 21.75 DP (psi)
Pressure
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PiggabilityOperations
Flow Rate
Most cleaning, batching and swabbing applications are run on-stream and will have to be carried out at the velocity of the product stream.
Pigs are most effective if run at a near constant speed. When the flow rate is low the pig may run in a series of start and stop motions, and it will not be very effective under these conditions.
Pigs will not be effective if run at too high a velocity. This is seldom a problem with on-stream pigging as the flow rates are usually quite moderate. However, during construction, flow rates cannot always be controlled and it is then difficult to achieve maximum effectiveness.
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Piggability Operations
Flow Rate
The following are considered to be typical speeds for utility pigging and are given as reference only.
Application Speed (Mph)New Construction 1 - 5On-Stream Gas 2 – 8On-Stream Liquids 1 – 8ILI Tools 2 – 7
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Piggability Operations
Flow Rate
Gas velocity (Mph) is calculated with the following formula:
(31210) (mmcfd)(psi)(d2)
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Piggability Operations
Flow Rate
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PiggabilityOperations
Temperature
Most pigs use polyurethane seals and the allowable temperature range for this material is generally between 32° F. and 180° F. (0° and 82° C.) Since most pipelines operate at ambient temperatures within this range, this does not normally create any problems for utility pigs.
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Piggability Operations
Contaminants
Bacteria
Sulfate Reducing Bacteria (SRB) - SRB’s use the sulfate ion in water as a food source. Through their metabolic process, the sulfate is converted to H2S.
Acid Producing Bacteria (APB) - APB’s produce carboxylic acids and/or CO2 as a by-product of their metabolic process
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Piggability Operations
Contaminants
SolidsIron Sulfide (pyrophoric material will ignite spontaneously in air)Iron CarbonateIron Oxide
OtherPCBs (acute poisoning – source is typically from compressors)NORMS (Natural Occurring Radioactive Materials) – source is radium-226 and radium-228 are the decay products of uranium and thorium that are present in subsurface formations.
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Piggability
Launcher Receiver Design
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PiggabilityPurpose of Launcher & Receivers
The primary purpose of a Pig
Launcher and Receiver is to
Launch and/or Receive a pipeline
pig into a pipeline system without
interruption of the flow.
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PiggabilityLauncher & Receivers
Utility Pigs
The “rule of thumb” for the length of the launcher barrel is 1.5 times the length of the longest pig to be used.
It is often the case that the pigs have not been selected at the time the traps are designed so an alternative “rule of thumb” for the length of the barrel, assuming single module pigs will be used, is 2.5D.
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PiggabilityLauncher & ReceiversIn-Line Inspection Tools
Many In-Line Inspection, or “ILI” tools, are typically constructed of several modules joined together. When these and similar “extra-long” ILI tools are to be used, the launcher barrel should be at least 1D longer than the overall length of the longest pig. Except for the length, all other dimensions will be the same as for utility pigs.
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PiggabilityLauncher & Receivers
Spheres
Spheres have a single line of seal and therefore must be treated differently than pigs that will have at least two and often four or more seals per pig. Since spheres are the same dimension in all directions, they are not self-guiding and will try to follow the flow within the pipeline even through smaller pipe sizes
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Launcher Nomenclature
Line Size Flange Kicker
VentPressure Gauge
Closure
Drain
BarrelReducerLine Size Pipe
A pig launcher includes an oversized pipe section, reducer,
various sized nozzles, line size pipe section and a quick
opening closure.
12” X 16”-600# Receiver
PIG-SIG®
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Launcher: Rule-of-Thumb Nozzle Sizing
Eccentric Reducer
Barrel SizeLess Than 12” -One Size Larger12” & Larger - Two Sizes Larger
Vent SizeUp to 22” = 1” NPT24” & Larger = 2” NPT
Gauge SizeAll Sizes = 1/2” NPT
Drain Line Size2” - 4” = 1 1/2”6” - 18” = 2”20” & Larger = 4”
One PigLength
Closure
Kicker Line1/3 PipelineDiameter
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Typical Launcher Schematic
VentValve Mainline
Trap Valve PIG-SIG®
MainlineBypassValve
Drain
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Receiver Nomenclature
Line Size Flange By-Pass
VentPressure Gauge
Closure
Drain
BarrelReducerLine Size Pipe
A receiver is similar to a launcher, but is configured to remove the pipeline pig from the system.
12” X 16”-600# Receiver
PIG-SIG®
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Receiver: Rule-of-Thumb Nozzle
Sizing
By-Pass Line1/3 Pipeline Size
Vent SizeUp to 22” = 1” NPT24” & Larger = 2” NPT
Gauge SizeAll Sizes = 1/2” NPT
Drain Line Size2” - 4” = 1 1/2”6” - 18” = 2”20” & Larger = 4”
Two Pig Lengths orOne Corrosion Tool Length
One PigLength
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Closures
Closures are used for scraper
traps, filters, strainers,
scrubbers, blow-downs, meter
provers, storage tanks, terminal
manifolds, test chambers and
other types of vessels and
piping.
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Launcher & Receiver Types Pigging Systems
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Launcher & Receiver Types: Automated Sphere Launching Systems
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Launcher & Receiver Types: Vertical Automated Systems
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Launcher & Receiver Types: Sloped Automated System
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Launcher & Receiver Types: Automated Batch System
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Launcher & Receiver Types: Temporary Launcher & Receivers
Temporary launchers are sometimes
used for the following purposes:• Clean Short Pipeline Segments such as HCAs
• Perform Hydrostatic Pressure Tests
• Decommissioning of Pipeline from Service
• Economic Purposes – Rent instead of Purchase
• Specialty Pigging Operations such as Blow Through
Cleaning and Inspection
• Proving Pigging Operations
• New Construction Cleaning & Inspections
• Off-line Pigging Operations
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Launcher & Receiver Types: Specialty Pigging - Tethering
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Pig Receiving
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Pigging during Construction
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Effective results of using cleaning fluids and brush pigs with RealSeal Cups.
Operational PiggingBlack Powder
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Line Cleanliness is Critical
MFL Tools are the best & most expensive cleaning pigsavailable. Sensor “Lift Off” will reduce the intensity ofthe magnetic signal and will affect data quality.
You don’t want MFL Tools to be a Cleaning Pig!
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Magnetic Cleaning Pig for Ferrous Materials
Debris such as welding rods, bolts, tools, etc., is verydifficult to remove with conventional pigs as the pigstypically push these objects for some distance and thenride over them.
The removal of this type of debris is a must beforeattempting to run Corrosion Inspection Pigs.
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Technology Timeline
1964
1966
1969
1978
1997
+
2000
?
First commercial
MFL pig --
inspected bottom
portion of
pipeline
First full-
circumference
MFL pig
Kaliper
Geometry Tool
First high-
resolution MFL
First reduced-
port pigs
High resolution
geometry tools
??
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Integrity Regulations (U.S.)
Where we are today
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High Consequence Areas (HCAs)
• Highly Populated Areas
• Other Populated Areas
• Areas unusually sensitive to
environmental damage
• Commercially navigable waterways
• Drinking water
Hazardous Liquids Pipelines
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High Consequence Areas
OPA
DW
NW
HPA
ESA
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HCA Repairs by Type
Repairs on HCA-
affecting Segments
over and above
those required by
the Liquid IM Rule
and all Repairs
outside of CA-
affecting Segments,
71%
Immediate
Repairs, 6%
60-Day
Repairs, 4%
180-Day
Repairs, 19%
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The Department of Transportation/Office of Pipeline Safety (DOT/OPS) issued an amendment to 192 Subpart O titled Pipeline Safety: Pipeline Integrity Management in High Consequence Areas (Gas Transmission Pipelines) effective January 14, 2004.
The Rule specifies regulations for assessing, evaluating, repairing and validating through comprehensive analysis the integrity of gas transmission pipelines that, in the event of a leak or failure, could affect:
(i) a Class 3 location
(ii) a Class 4 location
(iii) any area outside of a Class 3 or Class 4 location where the potential impact radius (PIR) is greater than 660 feet, and the area within a potential impact circle contains 20 or more buildings for human occupancy
(iv) the area within a potential impact circle containing an identified site (collectively called High Consequence Areas or HCA’s).
Natural Gas Pipelines
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High Consequence Area
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HCA Repair Conditions
Immediate
Metal Loss > 80%
Metal Loss predicted burst pressure
< MOP
Dent top of pipe with metal loss, crack
stress riser
Dent top of pipe > 6%
Anomaly that analyst believes to
warrant immediate repair
60 Days
Dent top of pipe > 3% (or > 0.25” if
pipe diameter < 12”)
Dent bottom of pipe with metal loss,
crack, stress riser
180 Days
Dent > 2% that affects pipe curvature at
girth or seam weld
Dent top of pipe > 2% (or > 0.25” if
pipe diameter < 12”)
Dent bottom of pipe > 6%
Metal loss calculated MAOP < MOP
Metal loss area of general corrosion
> 50%
Metal loss > 50% affecting girth weld
or at pipeline crossing
Crack
Corrosion along seam weld
Gouge > 12.5%
Immediate
Metal Loss > 80%
Metal Loss predicted burst pressure
≤ 1.1 x MOP
Dent with metal loss, crack stress
riser
Anomaly that analyst believes to
warrant immediate repair
1 Year
Dent (smooth) top of pipe > 6% (or
> 0.50” if pipe diameter < 12”)
Dent > 2% (or > 0.50” if pipe
diameter < 12”) that affects pipe
curvature at girth or seam weld
Monitored
Conditions
Dent bottom of pipe > 6% (or
> 0.50” if pipe diameter < 12”)
Dent top of pipe > 6% (or > 0.50” if
pipe diameter < 12”) and
engineering analysis of the dent
demonstrate critical strain levels are
not exceeded
Dent > 2% (or > 0.25” if pipe
diameter < 12”) that affects pipe
curvature at girth or seam weld and
engineering analysis of the dent
demonstrate critical strain levels are
not exceeded
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Summary
Many pipelines can be made piggable with readily available components
System information is critical when making a line to become piggable.
Don’t assume anything about the pipeline’s construction specifications or operational history.