--`,,```,,,,````-`-`,,`,,`,`,,`---2 Normative ReferencesAPI Standard 1104, Welding of Pipelines and Related Facilities AISC M016 1, Manual of Steel Construction ASME B31.4 2, Pipeline Tr
Applications
This practice is designed for onshore steel pipelines and emphasizes that relocating in-service pipelines can be a safe and cost-effective solution The guidelines provided are relevant for any lowering or movement of existing pipelines, whether to make way for new roads, railroads, foreign utilities, ditches, or creeks, or to address any situation where relocating the pipeline is the preferred option.
Exceptions
The recommendations outlined in this document are not applicable to pipelines that were relocated before the effective date of this practice Additionally, they do not pertain to movements caused by mining activities or natural subsidence Furthermore, the movement of pipelines with attached appurtenances falls outside the scope of this recommended practice.
The methods, criteria, values, and recommendations outlined in this document do not take into account certain types of pipelines, specifically: a) offshore pipelines; b) pipelines that include valves, flanges, fittings, concrete coatings, or other attached appurtenances in the section designated for movement; and c) pipelines connected by oxyacetylene welds, mechanical joints, or girth welds of known poor quality, unless these welds are reinforced with full encirclement sleeves or other acceptable methods.
Safety Considerations
This document emphasizes safety recommendations relevant to typical conditions in the pipeline industry It does not address requirements for abnormal situations or provide specific engineering and construction details It is crucial that all movements of in-service pipelines adhere to the applicable safety standards.
Conventions
This document defines each equation term in Annex A, located below the first equation that utilizes it It is important to note that negative stress values represent compressive stress, while positive values indicate tensile stress.
API Standard 1104, Welding of Pipelines and Related Facilities
AISC M016 1 , Manual of Steel Construction
ASME B31.4 2 , Pipeline Transportation Systems for Liquid Hydrocarbons and Other Liquids
ASME B31.8, Gas Transmission & Distribution Piping Systems
OSHA 29 3 , Code of Federal Regulations Part 1926—Construction Industry Regulations
DOT 49 4 , Code of Federal Regulations Part 192—Transportation of Natural and Other Gas by Pipeline: Minimum
DOT 49, Code of Federal Regulations Part 195—Transportation of Hazardous Liquids by Pipeline
Longitudinal stress in the pipe before its movement, excluding residual stress in girth welds and in bends.
Design method that calculates bending stress in the pipe using elastic structural design methods.
Pipeline containing a hazardous fluid and is operating at normal flow conditions.
The controlled displacement of a pipeline segment without cutting the pipeline.
Minimum longitudinal distance required to move a portion of a pipeline a certain distance without exceeding its longitudinal stress limits.
A permanent inelastic deflection of a pipe.
Condition of a pipeline with neither longitudinal stress nor compressive longitudinal stress.
Longitudinal stress in a portion of a pipeline during or after its movement.
1 American Institute of Steel Construction, One East Wacker Drive, Suite 700, Chicago, Illinois 60601, www.aisc.org.
2 ASME International, 3 Park Avenue, New York, New York 10016, www.asme.org.
3 Occupational Safety & Health Administration, 200 Constitution Avenue, NW, Washington, D.C 20210, www.osha.gov.
4 U.S Department of Transportation, 1200 New Jersey Avenue, S.E., Washington, D.C 20590, www.dot.gov.
Design Considerations
This section outlines design techniques for calculating the longitudinal stress in a pipeline, taking into account factors such as pressure, temperature, bending, elongation, and initial conditions relevant to specific pipeline movement operations Additionally, it addresses mechanical influences and different types of loadings.
The total longitudinal stress in the pipe can be estimated with the following equation:
S L is the total longitudinal stress in the pipe, in psi;
S E is the existing longitudinal stress in the pipe, in psi;
S B is the longitudinal stress in the pipe due to bending caused by the movement operation, in psi;
S S is the longitudinal stress in the pipe due to its elongation caused by the movement operation, in psi.
4.1.3 Longitudinal Tensile Stress Due to Internal Pressure
The longitudinal tensile stress in the pipe due to internal pressure may be estimated with the following equation:
S P is the longitudinal tensile stress in the pipe due to internal pressure, in psi;
P is the maximum internal operating pressure of the pipe, in psi;
D is the outside diameter of the pipe, in inches; à is Poisson’s Ratio for steel, 0.3; t is the nominal wall thickness of the pipe, in inches.
4.1.4 Longitudinal Tensile Stress Due to Temperature Change
The longitudinal tensile stress in the pipe due to a change in its temperature may be estimated with the following equation:
S r is the longitudinal tensile stress in the pipe due to a change in its temperature, in psi;
E is the modulus of elasticity of steel 29 × 10 6 psi; α is the linear coefficient of thermal expansion of steel, 6.5 × 10 –6 in per in per °F;
T 1 is the temperature of the pipe at the time of the installation, in °F;
T 2 is the operating temperature of the pipe at the time of the movement, in °F.
If the pipe’s temperature at installation time is not known, it should be reasonably estimated.
4.1.5 Longitudinal Flexural Stress Due to Existing Elastic Curvature
When a pipeline is installed to adapt to a specific trench profile, it will undergo flexural stress that correlates with its curvature In unstable hilly areas or soils prone to frost heave or liquefaction, the pipeline may face unpredictable and varying stress levels This stress, denoted as \( S_C \), can fluctuate between near-yield-strength in tension and near-buckling in compression, necessitating careful consideration before any movement operations.
The longitudinal stress in a pipeline typically ranges from –10,000 psi to +20,000 psi In flat or gently rolling terrain, where soils are stable and not affected by frost heave or liquefaction, the pipeline primarily experiences longitudinal tensile stress due to internal pressure and temperature, along with flexural stress when it is elastically curved.
The existing longitudinal stress in the pipe may be estimated with the following equation:
S C is the longitudinal stress in the pipe due to existing elastic curvature, in psi.
4.1.7 Longitudinal Stress Due to Bending
The longitudinal stress in the pipe due to bending may be estimated with the following equation:
(5) where ω T is the net uniformly distributed load required to achieve the desired mid-span vertical deflection of the pipe
(Δ) [not the full weight of the pipe and fluid (see Annex B)], in lb/in.;
L I is the minimum trench length required to reach the mid-span vertical deflection of the pipe (Δ), in inches;
S is the elastic section modulus of the pipe, in in 3
4.1.8 Longitudinal Stress Due to Elongation
The longitudinal stress in the pipe due to elongation caused by the movement operation may be estimated with the following equation:
(6) where Δ is the mid-span deflection of the pipe, in ft;
L is the minimum trench length required to reach the mid-span deflection of the pipe (Δ), in ft.
The effects of this stress may be offset by an elastic compressive stress existing in the pipeline prior to the moving because of slack.
When designing pipeline movement operations, it is essential to account for dynamic effects caused by impacts, vibrations, earthquakes, and subsidence, which are beyond the pipeline operator's control Additionally, dynamic loads resulting from reconditioning, rehabilitation, and other temporary loads under the operator's control must also be factored into the design process.
The effects of previous movements should be considered in the design of movement operations.
Design Criteria
This subsection defines methodology and outlines criteria and minimum values that may be used in the design of pipeline-movement operations.
A total longitudinal stress limit must be set for movement operations, defined by the specified minimum yield strength of the line pipe (SMYS) adjusted by a design factor (FD) determined by the pipeline operator This design factor considers the pipeline's condition, operating history, and relevant codes and regulations, with a significant influence from the condition of the girth welds.
The longitudinal stress available for bending may be estimated with the following equation:
S A is the longitudinal stress available for bending, in psi;
SMYS is the specified minimum yield strength of the pipe, in psi.
To determine the minimum trench length necessary for achieving a specific mid-span deflection of a pipe while adhering to the longitudinal stress limit, one can utilize an equation derived from elastic free deflection theory This theory models the pipe as a single-span beam, fixed at both ends, subjected to a uniformly distributed load.
To minimize induced bending stress concentrations in the moved portion of the pipeline, a carefully designed profile is essential (refer to Figure 2) To achieve an acceptable longitudinal stress distribution resulting from bending, the deflection at any point along the trench profile can be calculated using a specific equation.
The vertical deflection of the pipe at a distance \( x \) is represented by \( \Delta x \), measured in feet Here, \( x \) indicates the distance along the trench from the initial point of the pipe deflection, also measured in feet.
Figure 1—Application of the Minimum Trench Length ( L )
Figure 2—Preferred Trench Profile of the General Lowering
L /2 Pipeline lowered to pass a short obstruction
L /2 Required transition length at each end of an extended obstruction
Support Spacing
Based on a four-span, uniformly loaded beam, the maximum free span between supports can be determined with the following equation:
L S is the maximum free span between pipe supports, in ft; d is the inside diameter of the pipe, in inches.
A Sample Problem and Its Solution
This article provides a detailed, step-by-step solution for calculating the minimum trench length necessary to achieve the desired pipe deflection, establish the preferred trench profile, and determine the maximum free span between supports.
The pipeline has a size of 12.75 inches in outer diameter and a wall thickness of 0.250 inches, resulting in a diameter of 12.75 inches, a thickness of 0.250 inches, and an inner diameter of 12.25 inches Constructed from API 5L Grade X42 material, the specified minimum yield strength (SMYS) is 42,000 psi The design aims for a vertical deflection of 5 feet, with a maximum operating pressure of 1000 psi The installation temperature of the pipe is set at 100°F, while the operating temperature is 30°F The pipeline is designed under favorable conditions and has a positive operating history, indicating a reliable design factor.
Step 1: With Equation (2), determine the longitudinal stress in the pipe due to internal pressure.
Step 2: With Equation (3), determine the longitudinal stress in the pipe due to temperature.
Step 3: With Equation (4), determine the existing longitudinal stress in the pipe, assuming that the longitudinal stress due to existing elastic curvature is equal to zero.
Step 4: With Equation (8), determine the minimum trench length required to reach the desired vertical deflection of the pipe and remain within the longitudinal stress limits.
The minimum trench length required to achieve the desired vertical deflection of 5 ft and remain within the longitudinal stress limits is 510 ft.
Step 5: With Equation (9), determine the preferred trench profile.
Table 1 presents the calculated vertical deflection for the preferred trench profile at 25 ft intervals, while Figure 3 depicts both the minimum trench length and the preferred trench profile.
Figure 3—Preferred Trench Profile of a Sample Lowering
Step 6: With Equations (6), (7), and (10), determine the maximum allowable support spacing.
Table 1—Some Vertical Deflections (Δ x ) in the Preferred Trench Profile of a Sample Movement
NOTE The deflection Δ x is measured in ft The first part of station x is measured in hundreds of ft, and the second part is measured in ft.
Conclusion: The minimum trench length required to achieve the desired 5-ft vertical deflection of the pipe is 510 ft The pipeline must be supported every 51.3 ft.
General
A pipeline-moving project consists of three essential steps: first, project planning; second, executing the physical tasks of ditching, moving, backfilling, and cleanup; and finally, completing documentation to fulfill the requirements of pipeline operators and regulatory bodies.
Each of the consideration discussed in this section should be taken into account in at least one of these steps.
Safety Precautions
Caution—For safety, the cautions and recommendations described in 5.2.2 through 5.2.7 should be considered and followed.
Prior to the pipe movement, the internal operating pressure of the pipeline should be reduced in accordance with the pipeline operators’ procedures and applicable regulations.
Prior to planning and excavation, the location of the pipeline, including its depth, should be determined.
Before starting any planning and excavation, it is crucial to identify potential underground facilities and their locations The construction site should be inspected for utility markers and signs of underground installations Accessing state or local “One Call” systems is recommended, and if not available, direct communication with the operators of these facilities is necessary for proper location and marking It is important to document all contacts made during this process.
Reviewing pipe mill test reports and welding inspection records is essential Additionally, visual and nondestructive inspections of girth welds should be conducted once the pipeline is exposed and before any movement occurs.
Attachments like fittings and valves can influence pipeline movement, and their impact must be taken into account However, the movement of pipelines with these appurtenances is not covered in this recommended practice (refer to section 1.2).
Excavation presents some unique safety considerations It should be performed in accordance with the pipeline operators’ procedures and applicable safety regulations Refer to OSHA trenching and excavation regulations.
Terrain
Terrain significantly impacts pipeline movement by determining the ground profile where the pipeline is situated It influences the length of the trench needed for pipeline installation, affecting the overall efficiency of the project.
In flat or gently rolling landscapes, pipelines are typically installed by adapting them to the terrain's contours This approach requires careful movement to reduce any extra stress on the pipeline.
In flat or gently rolling terrain, it is important to excavate a longer trench than what the trench length equation suggests to minimize additional stress and ensure the safe movement of the pipeline.
In mountainous or hilly areas, pipelines often feature permanent overbends or sag bends, which must be included in the physical profile of the relocated pipeline It is essential to conduct movement operations carefully to maintain the integrity of these bends.
When navigating challenging terrains like mountains and hills, it is crucial to approach movement operations as unique situations These scenarios often necessitate thorough engineering analysis and the implementation of specialized construction techniques to ensure safety.
Soil
The soil type may determine the cross-sectional shape of the excavation and how the pipeline will be handled over the ditch.
Other Considerations
All pipeline movement projects must be approached with caution to prevent additional stress on the pipe When a pipeline is under tension with minimal slack, the weight of the pipe, the fluid it carries, and seasonal temperature fluctuations can exacerbate stress levels Special attention is required for older pipelines, as their connections may be mechanically compromised.
For pipelines of known low toughness, additional consideration should be given before pipeline movement operations.
Trenching Requirements
The pipeline excavation should be performed so as to reduce the chances of damage to the pipeline coating system
If necessary, the ditch should be padded before moving the pipeline The bottom of the completed trench should conform to the design profile for the moved pipeline.
Supports
Changes in longitudinal stress within a pipeline can lead to unintended movement, often caused by factors such as residual stress or temperature fluctuations To mitigate this movement, it is essential to ensure that the pipeline is adequately supported and laterally restrained.
Support or lift points for pipelines must be positioned away from girth welds to prevent structural damage Proper spacing of these points is essential to maintain stress levels within acceptable limits.
The soil bearing capacities for equipment and temporary supports should be considered.
Figures 4 through 7 illustrate some pipeline-supporting methods
Figure 4—Pig Pen Method of Pipeline Support
Figure 5—Air Bag Method of Pipeline Support
Figure 6—Earth Pillar Method of Pipeline Support
Figures 8 to 10 demonstrate various methods for pipeline movement It is crucial to manage the differential heights of adjacent supports during the operation to ensure that the elastic curvature of the pipeline does not surpass the anticipated final elastic curvature resulting from the movement.
Figure 7—Sling Method of Pipeline Support
Figure 8—Pipeline-movement Method Using Two Side Booms
Figure 9—Pipeline-movement Method Using One Side Boom and One Backhoe
Figure 10—Pipeline-movement Method in Which Pipe is Slide into Ditch
Spoil from side of ditch
General
Prior to the execution of the pipeline movement, the exposed portion of the pipeline should be given a thorough overall visual inspection A record should then be made of the inspection.
Girth Welds
Girth welds identified by 5.2.5 as requiring visual inspection should be visually inspected.
Caution—Pipe movement cannot be controlled once started.
NOTE Successive steps may be required.
Inspection for External Corrosion
Inspect the pipeline for signs of external corrosion, and ensure that any corroded sections are addressed following the pipeline operators' procedures and relevant regulations.
Inspection for Mechanical Damage
The pipeline should be inspected for mechanical damage Imperfections and defects should be handled in accordance with the pipeline operators’ procedures and applicable regulations.
External Coating
The coating should be inspected both before and after a movement.
Holidays in the coating must be repaired with a compatible system, while any loose or disbonded coating should be removed and replaced following the pipeline operators' procedures and relevant regulations.
General
Caution—Backfilling and restoration should be performed as described in 7.2 and 7.3 so as not to damage the pipe or its coating.
Backfilling
When backfilling, it is essential to use rock shields or adequate padding to protect the pipeline The backfill adjacent to the pipeline must be free of rocks and hard objects to minimize stress Ensuring the pipe is flat on the trench bottom and well-padded with sand or quality fill dirt can further reduce stress Additionally, it is crucial to keep the ditch clear of trash, and in high-traffic areas like streets, driveways, and parking lots, extra compaction may be necessary.
Surface Restoration
Once backfilling is finished, it is essential to restore the right-of-way contours to their original grade The backfill material should be shaped to create a crown over the excavation to accommodate soil settling Additionally, proper water diversions must be implemented to prevent any washout of the excavation site.
General
Proper documentation and records of each pipeline movement project must be established and preserved to ensure that any future operations at the movement site consider the adjustments made It is essential to retain movement records for the entire lifespan of the pipeline.
Alignment Sheets
Line-moving projects must be promptly recorded on alignment sheets At the very least, the posting reference should clearly indicate the location of the design details and the "as-built" information.
Files
When documenting the relocation of a pipeline, it is essential to include key information such as the reason for the move, the condition of both the pipe and its coating, and the pipeline designation and location Additionally, any relevant design calculations, the “as-built” plan and profile record, and the dates of the work performed should be recorded Observations of the pipe's behavior during movement, the pressure experienced during the process, and the name of the on-site representative are also crucial Finally, it is important to note the locations of adjacent structures and boundaries, along with a record of postings to alignment sheets.
The linear coefficient of thermal expansion for steel is \(6.5 \times 10^{-6}\) inches per inch per °F The mid-span vertical deflection of the pipe is denoted as \(\Delta\), while \(\Delta x\) represents the vertical deflection at a specific distance \(x\) Additionally, the inside diameter of the pipe is referred to as \(d\).
D outside diameter of the pipe in.
E modulus of elasticity of steel 29 × 10 6 psi
L minimum trench length required to reach the mid-span vertical deflection of the pipe (Δ) ft
L I minimum trench length required to reach the mid-span vertical deflection of the pipe (Δ) in.
L S maximum free span between pipe supports ft μ Poisson’s Ratio for steel 0.3
P maximum internal operating pressure of the pipe psi
S elastic section modulus of the pipe in 3
S A longitudinal stress available for bending psi
S B longitudinal stress in the pipe due to bending caused by the lowering operation psi
S C longitudinal stress in the pipe due to existing elastic curvature psi
S E existing longitudinal stress in the pipe psi
S L total longitudinal stress in the pipe psi
SMYS specified minimum yield strength of the pipe psi
S P longitudinal tensile stress in the pipe due to internal pressure psi
S S longitudinal stress in the pipe due to its elongation caused by the moving operation psi
S r longitudinal tensile stress in the pipe due to a change in its temperature psi t nominal wall thickness of the pipe in.
T 1 temperature of the pipe at the time of the installation °F
The operating temperature of the pipe during movement is denoted as T2 in °F The desired mid-span vertical deflection of the pipe, represented as ωT (Δ), is measured in lb/in and does not account for the full weight of the pipe and fluid (refer to Annex B) Additionally, the distance along the trench from the starting point of the pipe is indicated as x, measured in feet.
Derivation of the Equation for Longitudinal Stress Due to Bending and of the Equation for Trench Length
Equations (8) and (5) are derived from the AISC beam diagram 15, which pertains to a single-span, fixed-end, uniformly loaded beam The desired pipe deflection (\$Δ I\$) is equated to the mid-span deflection of a fixed-end beam to calculate the net load (\$ω T\$) necessary for achieving this deflection Subsequently, the length (\$L I\$) of the beam is determined, where the bending stress (\$S B\$) resulting from the desired deflection matches the available bending stress (\$S A\$).
NOTE All AISC dimensions are in inches.
Setting the desired deflection (Δ l ) of the pipe equal to the maximum deflection of a fixed-end beam where
I is moment of inertia, in in 4 Rearranging to solve for ω T
The maximum moment in a fixed-end beam occurs at the ends as follows: where
M is the maximum moment in a fixed-end beam, in in.-lb.
The bending stress in the beam (pipe) at its outer surface is where
C is the distance from neutral axis to outside surface of beam, in inches.
Therefore, as expressed in Equation (5), the equation for longitudinal stress in the pipe due to bending.
Setting S B equal to S A and substituting for S S
For a hollow circular pipe (see AISC M016)
Converting to ft, the units used for L in this document
Derivation of Trench Profile Equation
Equation (9) represents the deflection of the pipe at any point along the trench profile, derived from AISC beam diagram 15 (refer to AISC M016) This equation assumes the beam is fixed at both ends, with uniformly distributed loads and consistent units of measure.
(C.1) Setting the desired deflection of the pipe (Δ) equal to the maximum (mid-span) deflection of a fixed-end beam
Substitution of the right-hand side of the above equation for ω T in Equation (C.1) and simplification of the resulting equation show that
Derivation of Equation for Longitudinal Stress Due to Elongation
Equation (6) estimates the longitudinal stress in the pipe caused by elongation, highlighting that for any specified horizontal distance, the arc length of a circular curve exceeds the length of the corresponding horizontal line segment, as illustrated in Figure D.1.
For any one of the four circular-curve segments of the moved pipe (see Figure D.2), the elongation (δ) is the difference in length due to stretching.
(D.1) where δ is the difference in length of the pipe segment due to stretching caused by movement;
A is the arc length of a circular curve representing the pipe segment in its final position, after movement; l is the original length of the pipe segment, before movement.
The strain (ε) on the pipe due to its elongation is the difference in length divided by the original length.
(D.2) where ε is the strain on the pipe due to its elongation.
Figure D.1—Arc Length ( A ) of a Circular Curve δ= A l– l
Trigonometry indicates that for angles in radians where
R is the radius of curvature; θ is the arc angle, in radians.
Since for small angles therefore
Figure D.2—The Four Circular-curve Segments in the Preferred Trench Profile of the General Movement
By substituting the right-hand side of the second line of Equation (D.3) for δ in Equation (D.2), and reducing Rθ to l as per the previous equation, we can simplify the resulting equation to reveal the final results.
Since there are four circular-curve segments in each lowering (see Figure D.2)
Rewriting the above equation for ε in terms of Δ and L
(D.11) therefore, the stress in the pipe due to its elongation is
Derivation of Equation for Maximum Free Span Between Pipe Supports
Equation (10) defines the maximum free span between pipe supports, based on the AISC beam diagram 39 (refer to AISC M016), which pertains to a continuous beam featuring four equal spans under load.
NOTE All dimensions are in inches. where is the maximum free span between pipe supports, in inches;
M MAX is the maximum moment, in in.-lb;
W is the full weight of water-filled pipe, in lb/in.
Since where ρ steel is the density of steel, 0.283 lb/in 3 ; ρ water is the density of water, 0.0361 lb/in 3 ;
A pipe is the cross-sectional area of steel pipe, in in 2 ;
A water is the cross-sectional area of water in filled pipe, in in 2
Converting to ft, the units used for L S in this RP
Equation No Description, in Units
[1] total longitudinal stress in the pipe, in psi
[2] longitudinal tensile stress in the pipe due to internal pressure, in psi
[3] longitudinal tensile stress in the pipe due to a change in its temperature, in psi
[4] existing longitudinal stress in the pipe, in psi
[5] longitudinal stress in pipe due to bending caused by the movement operation, in psi
[6] longitudinal stress in pipe due to elongation caused by the movement operation, in psi
[7] longitudinal stress available for bending, in psi
[8] minimum trench length required to reach the mid-span vertical deflection of the pipe (Δ), in ft
[9] vertical deflection of the pipe at distance x, in ft
[10] maximum free span between pipe supports, in ft
S C = longitudinal stress in the pipe — longitudinal stress in the pipe due to existing elastic curvature, in psi due to existing curvature
[1] Cardinal, J.W and P.A Cox, “Guidelines Studied for Lowering Pipe in Service,” Oil & Gas Journal, November
[2] Cromwell, M.D., “How to Lower an Existing Pipe Line That Is Still In Service,” Pipe Line Industry, July 1986, pp 47 – 49.
The report titled "Guidelines for Lowering Pipelines While in Service," authored by Kiefner et al., was published on February 25, 1985, and is a collaborative effort between the American Society of Mechanical Engineers, the U.S Department of Transportation, and Battelle Columbus Laboratories This document, available through the National Technical Information Service in Springfield, Virginia, provides essential guidelines for safely lowering pipelines during operation.
[4] Kiefner, J.F and T.A Wall, “Joint Research Project Develops Guidelines for Lowering In-Service Pipelines,”
Pipeline & Gas Journal, November 1985, pp 45 – 47; February 1986, pp 34 – 35; and March 1986, pp 30, 33 – 34,
[5] Rosenfeld, M.J., Pipeline In-Service Relocation Engineering Manual, December 31, 1994, AGA Catalog no L51717.
[6] Summers, P.B and D.J Nyman, Pipeline Stress Analysis for Lowering Operations, 1985 Pressure Vessels and Piping Conference and Exhibition, New Orleans, Louisiana, June 23 – 27, 1985.
[7] Summers, P.B and D.J Nyman, Pipesag—A Microcomputer Program to Assess the Effects of Large Ground-
Deformations on Buried Pipelines, 1985 Pressure Vessels and Piping Conference and Exhibition, New Orleans,
[8] Tennille, R.N., “Minimizing Stresses: A Goal in Lowering In-Service Lines,” Pipeline Digest, May 1987, pp 9 – 10.
`,,```,,,,````-`-`,,`,,`,`,,` - of In-service Pipelines, 3 rd Edition, July 2008
This errata corrects editorial errors in the 3rd Edition of API RP 1117
The change listed below was issued with Errata 1 (December 2008)
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