Abdul Majid Hwidi-PND/34
01/11/2021
PIPELINE DESIGN REPORT
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TABLE OF CONTENTS
1.0
1.1
1.2
1.3
1.4
1.5
2.0
2.1
2.2
2.3
2.4
2.5
3.0
3.1
3.2
4.0
4.1
4.2
4.3
4.4
GENERAL ....................................................................................................................................................3
INTRODUCTION ........................................................................................................................................... 3
BACKGROUND ............................................................................................................................................ 3
CONTRACT OBJECTIVE ........................................................................................................................... 3
DOCUMENT OBJECTIVE .............................................................................................................................. 4
ABBREVIATIONS ......................................................................................................................................... 5
REFERENCE DOCUMENTS AND STANDARDS .......................................................................................5
ORDER OF PRECEDENCE ............................................................................................................................ 5
QP CORPORATE STANDARDS AND REGULATIONS ........................................................................................ 6
SHELL DEP’S ............................................................................................................................................ 6
PROJECT REFERENCE DOCUMENTS ............................................................................................................ 6
INTERNATIONAL CODES AND STANDARDS .................................................................................................... 6
CLASS LOCATION IDENTIFICATION (B31.8) ...........................................................................................7
GENERAL................................................................................................................................................... 7
DESIGN FACTORS SELECTED ...................................................................................................................... 8
DESIGN CALCULATIONS...........................................................................................................................9
GENERAL................................................................................................................................................... 9
DESIGN DATA 1.......................................................................................................................................... 9
DESIGN DATA 2........................................................................................................................................ 10
PIPELINE WALL THICKNESS CALCULATION AS PER ASME B31.4................................................................. 10
4.4.1
4.4.2
4.5
4.6
4.7
4.8
Material Yield Strength ................................................................................................................................. 10
Pipeline Wall Thickness Check .................................................................................................................... 11
MINIMUM BEND WALL THICKNESS CHECK AS PER PD 8010 - PART 1 ......................................................... 11
SUMMARY OF WALL THICKNESS SELECTION AS PER ASME B31.4 ............................................................. 12
PIPE WALL THICKNESS STRESS CHECK AS PER ASME B31.4.................................................................... 12
PIPELINE WALL THICKNESS CALCULATION AS PER ASME B31.8................................................................. 14
4.8.1
4.8.2
4.9
4.10
4.11
4.12
Material Yield Strength ................................................................................................................................. 14
Pipe Wall Thickness Check.......................................................................................................................... 14
MINIMUM BEND WALL THICKNESS CHECK AS PER PD 8010 - PART 1 .........................................................
SUMMARY OF WALL THICKNESS SELECTION AS PER ASME B31.8 .........................................................
PIPE WALL THICKNESS STRESS CHECK AS PER ASME B31.8................................................................
ROAD CROSSING THICKNESS CALCULATION: API RP 1102....................................................................
4.12.1
4.12.2
4.12.3
15
15
16
18
Design Basis ................................................................................................................................................ 18
Type of Crossings According to API RP 1102 .............................................................................................. 18
Summary of Results ..................................................................................................................................... 19
5.0 ATTACHMENTS........................................................................................................................................ 21
5.1
ATTACHMENT 1: RESULTS FOR WALL THICKNESS / THINNING CALCULATIONS AS PER ASME B31.4............. 22
5.2
ATTACHMENT 2: PIPE WALL THICKNESS STRESS CHECK AS PER ASME B31.4........................................... 23
5.3
ATTACHMENT 3: RESULTS FOR WALL THICKNESS / THINNING CALCULATIONS AS PER ASME B31.8............. 24
5.4
ATTACHMENT 4: PIPE WALL THICKNESS STRESS CHECK AS PER ASME B31.8........................................... 25
5.5
ATTACHMENT 5: API RP 1102 CALCULATION ............................................................................................ 26
PIPELINE DESIGN REPORT
1.0
GENERAL
1.1
Introduction
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Qatar Petroleum has awarded the contract GC191008B0 EPIC for Route Survey, Design,
Construction, Installation & Hook-Up of Well Flowlines in Dukhan Fields (2019-2022) to Black
Cat Engineering & Construction W.L.L (BCEC), who has in turn subcontracted the detailed
engineering services for the project to Black Cat Consulting and Engineering Services W.L.L.
(BCCES).
1.2
Background
Dukhan is an ageing oil field which is constantly being upgraded with field development plans to
sustain oil and gas production. As part of this activity, field development plans are developed to
drill new wells and implement various modifications in the Dukhan field surface processing
facilities to integrate new wells drilled to sustain production in Dukhan. It is also necessary to
workover on existing wells and bring back to operation which involves dismantling and reinstatement of surface facilities and also some modification to workover wells as per filed
development plan.
QP intends to drill new Oil producers, PWI injectors, Khuff Gas producers, ADGCR gas
producers / injectors, UER source wells, UER recirculation wells, produced water/UER dump
wells and Uwainat producers for the forthcoming years (2019 to 2022) in Dukhan field and hook
up the new wells with the existing facilities. In addition, existing wells workover are also planned
to sustain the well production and to ensure integrity of existing wells.
During the above period, QP business plan envisages drilling of about one hundred and fifty
(150) new wells to meet the objective of producing crude oil and gas from Dukhan field. QP is
also planning to workover about Three Hundred and Fifty Five (355) wells at Dukhan based on
QP’s Well Integrity Department recommendations to improve well integrity or for installation of
gas lift mandrels.
Further QP has divided the requirements into two parts: -
1.3
1.
PART A (South area, and Work over Wells)
2.
PART B (North Area, RG, and Khuff)
CONTRACT Objective
The objective of this CONTRACT is to implement Part B, which is to hook up new wells to
the nearest manifolds and production stations to meet production targets. Wells which are
involved in this Contract include the following well types: -

Crude oil producers, (with Gas lift flow lines)

PWI injectors,

UER source water wells,

UER recirculation wells,

Khuff gas producers,

Khuff gas producers/injectors,

Arab D producers, and

Arab D injectors.
The scope also includes Decommissioning and demolition works for existing flowlines of various
sizes and provision of new tie-ins for hook up of future Arab D and Uwainat Gas Cap Wells flow
lines.
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1.4
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Document Objective
This calculation report presents the Mechanical Calculations (i.e. wall thickness, road crossings,
and preliminary stress) for the flowlines associated with this project.
The purposes of this calculation report are to:
1.
2.
Confirm that the selected wall thicknesses are suitable for road crossings in accordance
with API RP 1102;
Confirm that the selected wall thicknesses for line pipe and mother pipe are passing the
stress calculations in accordance with ASME B31.4, ASME B31.8 and PD 8010 Part 1 and
present the minimum bending radius;
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1.5
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Abbreviations
Abbreviations
Descriptions
API
ASME
American Petroleum Institute
American Society of Mechanical Engineers
ASTM
American Society for Testing and Materials
DF
FEED
Design Factor
Front-End Engineering Design
HAZ
ISO
Heat Affected Zone
International Standards Organization
MSS
MOP
Manufacturers Standardization Society
Maximum Operating Pressure
NDT
Non-Destructive Testing
NACE
NGL
National Association for Corrosion Engineers
Natural Gas Liquid
OD
SMLS
Outside Diameter
Carbon Steel Seamless line pipes
SMYS
PWI
Specified Minimum Yield Stress
Produced Water Injection
SW
Source Well
RW
GL
Recycle Well
Gas Lift
KGP
KGI
Khuff Gas Production
Khuff Gas Injection
RGP
RGI
Recycled Gas Production
Recycled Gas Injection
2.0
REFERENCE DOCUMENTS AND STANDARDS
2.1
Order of Precedence
Should any conflicts arise, the following ranking of precedence shall apply in descending order:
1.
Qatar Statutory Regulations
2.
QP Corporate Regulations
3.
QP Corporate Philosophies
4.
QP Corporate Standards
5.
QP Amendments to Shell DEP’s
6.
CONTRACT specific Amendments to Shell DEP’s
7.
Shell DEP’s version 42
8.
CONTRACT/Project specific Specifications
9.
QP Engineering Standards and Specifications
10. QP recognized International, Regional, National, Industry Codes of Practices and
Standards
CONTRACTOR / VENDOR / SUPPLIER shall notify QP for any conflict and shall seek “approval
for proceeding” in writing.
PIPELINE DESIGN REPORT
2.2
2.3
2.4
2.5
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QP Corporate Standards and Regulations
Document Reference
Title
QP-SPC-L-018
Specification for Onshore Pipeline Construction
QP-STD-A-001
QP Accepted International, National and Industry Codes and
Standards
QP-STD-L-017
QP Standard for Onshore Pipeline Transmission and Distribution
Systems for Gas and Liquid Hydrocarbons
Shell DEP’s
Document Reference
Title
DEP 31.40.20.37
Line Pipe for Critical Service (Amendments/Supplements To ISO
3183:2012 And API Spec 5L 45th Edition)
DEP 31.40.00.10
Pipeline Engineering (Amendments/Supplements to ISO 13623)
Project Reference Documents
Document Reference
Title
4148-DGTYP-0-29-0001
Design Basis Memorandum
4148-DGTYP-7-14-0001
Specification of Line Pipe
4148-DGTYP-7-13-0001
Datasheet for line pipe
International Codes and Standards
Document Reference
Title
API 5L
Specification for Line Pipe
ASME B 31.4
Pipeline Transportation Systems for Liquids and Slurries
ASME B31.8
Gas Transmission and Distribution Piping System.
PD 8010 Part 1
Code of Practice for Pipelines – Part 1 – Steel Pipelines on Land
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3.0
CLASS LOCATION IDENTIFICATION (B31.8)
3.1
General
Pipeline classification has been described in section 840.2.1 and 840.2.2 of ASME B31.8, the
following is defined: -
The pipeline route has been studied and verified along entire route. It is observed that location
Class 1 is applicable to the pipeline.
As per B31.8, selection of minimum design Factor of 0.72 is applicable as a Division 2.
Therefore, the complete pipelines have been designated as Class 1, Division 2.
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Design Factors Selected
Below are the applicable design factors for Class 1, division 2, and the relevant items are marked
in Blue font, as extracted from ASME B31.8 table 841.1.6-2.
Ser.
no.
Narrative as per ASME B31.8
Table 841.1.6-2
1
Pipeline, mains and service lines
2
Crossing of roads, railroads without
casing
2a
Private roads
2b
Unimproved public roads
2c
Roads, highways, or public streets
with hard surface and railroads
3
Notes
1
Div-2
(Note-4)
Applicable to Project
0.72
Applies to pipeline route across
entire length, and Culverted
crossings.
0.72
Not applicable to this project
0.6
Applies to Track crossings with
concrete slab protections
0.6
Trenchless crossings (HDD or
Micro tunneling)
Crossing of roads, railroads with
casing
3a
Private roads
0.72
Not applicable to this project
3b
Unimproved public roads
0.72
Not applicable to this project
3c
Roads, highways, or public streets
with hard surface and railroads
0.72
Not applicable to this project
4
Parallel encroachment of pipelines
and mains on roads and railroads
2
4a
Private roads
0.72
Not applicable to this project
4b
Unimproved public roads
0.72
Not applicable to this project
4c
Roads, highways, or public streets
with hard surface and railroads
0.6
Not applicable to this project
5
Fabricated assemblies
0.6
Not applicable to this project
6
Pipelines on bridges
0.6
Not applicable to this project
7
Pressure / flow control and metering
facilities
0.6
Applicable to inside Stations Plot
boundaries (Wellheads and
Manifolds)
8
Compressor station piping
0.5
Not applicable to this project
9
Liquid separators constructed of pipe
and fitting without internal welding
0.4
Not applicable to this project
10
Near concentration of people in
location classes 1 and 2
3
0.5
Not applicable to this project
Notes:
1.
2.
3.
4.
Micro-tunneling / HDD as required.
Parallel encroachments are defined as those sections of a pipeline running parallel to an existing
road or railway at a distance less than 50m.
Concentration of people as defined in ASME B31.8 article 840.3(b).
Design Factor selected for this project pipeline design.
PIPELINE DESIGN REPORT
4.0
DESIGN CALCULATIONS
4.1
General
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The following calculations have been performed to ensure the pipeline integrity: -
4.2
1.
Wall thickness calculations for internal pressure as per B31.4.
2.
Minimum Bend Wall Thickness Check as per PD 8010 - Part 1 for ASNE B31.4.
3.
Pipe Wall Thickness Stress Check as per ASME B31.4
4.
Wall thickness calculations for internal pressure as per B31.8.
5.
Minimum Bend Wall Thickness Check as per PD 8010 - Part 1 for ASNE B31.8.
6.
Pipe Wall Thickness Stress Check as per ASME B31.8.
7.
Wall thickness verification for road Crossing (API RP 1102).
Design Data 1
Pipeline Design Data
Service
Sour Crude, Lift Gas, Water (Saline), Sour Water, Sour Gas
Locations
Stations - Wellheads and Manifolds
Installation
Generally Above Ground, with Buried Track Crossing.
Pipelines outside diameter
DN 8’’
DN 6’’
DN 4’’
DN 3’’
219.08mm
168.28mm
114.3mm
88.9mm
API 5L Grade X52 PSL2 (Note-1)
Pipeline Material
API 5L Grade X60, PSL2 (Note-1)
API 5L Grade X65, PSL2 (Note-1)
SMYS for API 5L Gr.X60
60,000 psi = 415 MPa (Refer to API 5L Table 7) for ASME B31.4
SMYS for API 5L Gr.X52
52,000 psi = 359 MPa (Refer to ASME B31.8 Table D-1)
SMYS for API 5L Gr.X60
60,000 psi = 414 MPa (Refer to ASME B31.8 Table D-1)
SMYS for API 5L Gr.X65
65,000 psi = 448 MPa (Refer to ASME B31.8 Table D-1)
Pipe Types
Seamless
Weld Joint Factor, E
1.00 (ASME B31.4 Table 403.2.1-1, for SMLS)
Temperature Derating Factor, T
1.00 (refer to ASME B31.8 Table 841.1.8-1)
Longitudinal Joint Factor, E
1.00 (refer to ASME B31.8 Table 841.1.7-1 for SMLS)
Design Pressure / Design Code
Refer Section 4.3
Maximum Design Temperature
Refer Section 4.3
Minimum Design Temperature
Refer Section 4.3
Temperature at time of installation
21 °C
Corrosion Allowance (C)
Refer Section 4.3
Location Class
Class 1, Division 2 (As per ASME B31.8)
Material Conformance
NACE MR0175/ISO 15156/QP-STD-R-001 Rv3/ DEP 31.40.20.37
Design Factors
Off Plot Area
0.72
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Pipeline Design Data
Off plot Crossings
0.6
On plot area Stations
0.6
Other
Line is Piggable?
No
Diameter to Wall Thickness Ratio
< 96
Note:
1.
4.3
Under this project, line pipe Material Grade for Seamless has already been selected by QP in contract
document API 5L Gr.X52, X60 and X65 (Refer FEED Line Pipe Data Sheet 4021-DGEN-7-13-0001001 Rv2).
Design Data 2
Corrosion
Allowance
(mm)
Max.
Design
Temp.
Deg.C
Minim.
Design
Temp.
Deg.C
Design
Pressure
(barg)
3
84
0
110.3
API 5L X65
3
84
0
142.58
ASME B31.4
API 5L X60
3
84
0
139.62
8
ASME B31.4
API 5L X60
3
84
0
43.4
UER Recycle well flowline
8
ASME B31.4
API 5L X60
3
84
0
16.9
6
Khuff Production flowline
6
ASME B31.8
API 5L X65
3
150
-10
359
7
Khuff injection flowline
6
ASME B31.8
API 5L X65
3
84
-10
368.6
8
RG production flowline
8
ASME B31.8
API 5L X52
3
84
-10
179.3
9
RG injection flowline
6
ASME B31.8
API 5L X60
3
84
-10
240
SL
No.
Well Type
Size
(Inch)
Design
Code
1
Oil Flow line
6
ASME B31.4
2
Gas lift flowline
3
ASME B31.8
3
PWI flowline
4
4
UER Source well flowline
5
Material
API 5L X60
4.4
Pipeline wall Thickness Calculation as per ASME B31.4
4.4.1
Material Yield Strength
The material yield strengths as listed in API 5L, Table table-7 and Weld Joint Factor listed in
ASME B31.4 table 403.2.1-1 are used in the calculations.
PIPELINE DESIGN REPORT
4.4.2
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Pipeline Wall Thickness Check
The wall thickness for pressure containment only has been calculated based upon the following
formula given in ASME B 31.4 – clause 403.2.1:
Minimum required pipe wall thickness shall be calculated by including corrosion allowance:
tmin = t + C
Where C = Corrosion allowance specified.
For mechanical handling consideration and to limit damage to line pipe during construction, the
nominal pipe wall thickness shall not be less than 4.8 mm and the diameter to wall thickness
(Do/t) ratio shall not exceed 96.
4.5
Minimum Bend Wall Thickness Check as per PD 8010 - Part 1
Minimum bend wall thickness is calculated as per PD 8010 – Part 1 taking into consideration
that mechanical properties, after bending, fulfil requirements as per API 5L X60. The cold field
bends shall be made in accordance with QP Specification QP-SPC-L-018. The minimum radius
of curvature shall be 40D, where D is the outside diameter of the pipe. Where there is a
requirement for a tighter bend radius, factory manufactured induction bends shall be used. These
hot induction bends will have a minimum bend radius of 5 times for oil flow line and 20 times for
source / recycle wells the nominal diameter, unless otherwise specified.
The wall thickness of finished bends, considering wall thinning at the outer radius, shall be not
less than required design thickness, calculated as given in below table. An indication of wall
thinning as a percentage may be given by the following empirical formula:
Wall thinning =
50
n
+1
Please note the following.
1. Oil flow line.
n
- The inner bend radius divided by pipe diameter. = (5D – 0.5D)/D = 4.5
(Hence 50 / (4.5+1) = 9.09%, predicted thinning).
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However, 10% wall thinning has been considered (conservatively) to allow for manufacturing
tolerances from hot induction bends suppliers.
2. PWI flow line, Source Well flow line and Recycle Well flow line
n
- The inner bend radius divided by pipe diameter. = (20D – 0.5D)/D = 19.5
(Hence 50 / (19.5+1) = 2.44%, predicted thinning).
However, 3% wall thinning has been considered (conservatively) to allow for manufacturing
tolerances from hot induction bends suppliers.
4.6
Summary of Wall Thickness Selection as per ASME B31.4
Calc. Thickness tcal
(DF=0.72)
Minimum Thickness
tmin req. (tcal+CA)
(DF=0.72)
Calc. Thickness tcal
(DF=0.6)
Minimum Thickness
tmin req. (tcal+CA)
(DF=0.6)
Mother pipes for
Bends Thickness
Selected (tsel2)
Tsel2
After Thining
OD/tsel1
(<96)
tsel1 > tmin
(mm)
(mm)
(mm)
(mm)
(mm)
(mm)
Check
Check
Check
6
168.28
3.10
6.10
3.72
6.72
7.11
7.50
6.75
OK
OK
OK
PWI
4
114.30
2.67
5.67
3.20
6.20
7.14
7.14
6.93
OK
OK
OK
SW
8
219.08
1.59
4.59
1.91
4.91
5.56
5.56
5.39
OK
OK
OK
8
219.08
0.62
3.62
0.74
3.74
4.80
5.40
5.24
OK
OK
OK
OIL
tsel2 > tmin
PIPE OD
(mm)
Straight Pipe
Thickness Selected
(tsel1)
PIPE SIZE
(mm)
WELL TYPE
(in)
RW
For the detail calculations refer Attachment 1. The summary of wall thickness calculation and
results as follows.
Notes: 1.
Proposed pipelines wall thickness as shown above table are adequate for straight pipe and mother
pipe for hot induction bends.
2.
The straight pipe thicknesses are same as per FEED. Mother pipe thickness is selected as per detailed
design calculation which is not as per FEED as following;
3.
4.7
a)
Mother pipe thickness for 6’’ oil flow line = 7.50mm.
a)
Mother pipe thickness for 8’’ Recycle Well Flow line = 5.4mm.
From above calculation all thicknesses are in accordance with the thickness selection during FEED
as per Document 4021-DGEN-7-13-0001 Rev.2 except which is mentioned above point 2.
Pipe Wall Thickness Stress Check as per ASME B31.4
The stress check also done for the selected wall thickness as per ASME B31.4 section 402 and
found that all the stresses are within the allowable limits refer Attachment-2. The summary of
results is listed below:
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1. Oil Flow line
Stress
Unit
Max
Allowable
Calculated
Value
Ratio of calculated
to allowable
Check
Hoop (SH)
Mpa
249.00
225.22
90.45%
OK
Thermal Expansion (SE)
Worst Case Scenario
Mpa
359.67
-173.38
48.21%
OK
Longitudinal (SL)
Worst Case Scenario
Mpa
332.00
-173.7
52.32%
OK
OVERALL STRESS CHECK OF WALL THICKNESS
ACCEPTED
2. PWI flowline
Stress
Unit
Max
Allowable
Calculated
Value
Ratio of calculated
to allowable
Check
Hoop (SH)
Mpa
298.80
192.74
64.50%
OK
Thermal Expansion (SE)
Worst Case Scenario
Mpa
359.67
-149.63
41.60%
OK
Longitudinal (SL)
Worst Case Scenario
Mpa
332.00
-147.70
44.49%
OK
OVERALL STRESS CHECK OF WALL THICKNESS
ACCEPTED
3. UER Source well flowline
Stress
Unit
Max
Allowable
Calculated
Value
Ratio of calculated
to allowable
Check
Hoop (SH)
Mpa
249.00
185.72
74.59%
OK
Thermal Expansion (SE)
Worst Case Scenario
Mpa
359.67
-149.63
41.60%
OK
Longitudinal (SL)
Worst Case Scenario
Mpa
332.00
-172.70
52.01%
OK
OVERALL STRESS CHECK OF WALL THICKNESS
ACCEPTED
4. UER Recycle well flowline
Stress
Unit
Max
Allowable
Calculated
Value
Ratio of calculated
to allowable
Check
Hoop (SH)
Mpa
249.00
104.01
41.77%
OK
Thermal Expansion (SE)
Worst Case Scenario
Mpa
359.67
-149.63
41.60%
OK
Longitudinal (SL)
Worst Case Scenario
Mpa
332.00
-197.2
59.04%
OK
OVERALL STRESS CHECK OF WALL THICKNESS
ACCEPTED
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4.8
Pipeline wall Thickness Calculation as per ASME B31.8
4.8.1
Material Yield Strength
The material yield strengths as listed in ASME B 31.8, Table D-1 are used in the calculations.
4.8.2
Pipe Wall Thickness Check
The wall thickness for pressure containment only has been calculated based upon the following
formula given in ASME B 31.8 – Section 841.1.1.
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Minimum required pipe wall thickness shall be calculated by including corrosion allowance:
tmin = t + C
Where C = Corrosion allowance specified.
For mechanical handling consideration and to limit damage to line pipe during construction, the
nominal pipe wall thickness shall not be less than 4.8 mm and the diameter to wall thickness
(Do/t) ratio shall not exceed 96.
4.9
Minimum Bend Wall Thickness Check as per PD 8010 - Part 1
Minimum bend wall thickness shall be calculated as per PD 8010–Part 1 taking into
consideration that mechanical properties, after bending, fulfil requirements as per API 5L X52.
The hot induction bends will have a minimum bend radius of 5 times the nominal diameter,
unless otherwise specified.
The wall thickness of finished bends, taking into account wall thinning at the outer radius, shall
be not less than required design thickness (tmin). An indication of wall thinning as a percentage
may be given by the following empirical formula:
50
Wall thinning =
n
+1
Where,
n
- The inner bend radius divided by pipe diameter. = (5D – 0.5D)/D = 4.5
(Hence 50 / (4.5+1) = 9.09%, predicted thinning).
However, 10% wall thinning has been considered (conservatively) to allow for manufacturing
tolerances from hot induction bends suppliers.
Summary of Wall Thickness Selection as per ASME B31.8
Calc. Thickness tcal
(DF=0.72)
Minimum Thickness
tmin req. (tcal+CA)
(DF=0.72)
Calc. Thickness tcal
(DF=0.6)
Minimum Thickness
tmin req. (tcal+CA)
(DF=0.6)
Mother pipes for
Bends Thickness
Selected (tsel2)
Tsel2
After Thining
OD/tsel1
(<96)
tsel1 > tmin
(mm)
(mm)
(mm)
(mm)
(mm)
(mm)
Check
Check
Check
3
88.90
1.96
4.96
2.36
5.36
5.49
6.20
5.58
OK
OK
OK
KGP
6
168.28
9.36
12.36
11.23
14.23
14.27
15.90
14.31
OK
OK
OK
6
168.28
9.61
12.61
11.53
14.53
14.27/
16.50
16.50
14.85
OK
OK
OK
8
219.08
7.61
10.61
9.13
12.13
12.70
13.50
12.15
OK
OK
OK
GL
tsel2 > tmin
PIPE OD
(mm)
Straight Pipe
Thickness Selected
(tsel1)
PIPE SIZE
(mm)
WELL TYPE
(in)
KGI
For the detail calculations refer Attachment 3. The summary of wall thickness calculation and
results as follows.
RGP
4.10
11.13
10.97/
12.70
12.70
OK
OK
OK
tsel2 > tmin
8.13
tsel1 > tmin
Minimum Thickness
tmin req. (tcal+CA)
(DF=0.6)
9.78
OD/tsel1
(<96)
Calc. Thickness tcal
(DF=0.6)
6.78
Tsel2
After Thining
Minimum Thickness
tmin req. (tcal+CA)
(DF=0.72)
168.28
Mother pipes for
Bends Thickness
Selected (tsel2)
Calc. Thickness tcal
(DF=0.72)
6
Straight Pipe
Thickness Selected
(tsel1)
PIPE OD
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12/10/2021
16 of 26
PIPE SIZE
Rev.:
Date:
Page
WELL TYPE
4148-DGTYP-7-17-0001
RGI
PIPELINE DESIGN REPORT
Doc No.
Notes: -
1.
Proposed pipelines wall thickness as shown above table are adequate for straight pipe and
mother pipe for hot induction bends.
2.
The straight pipe thickness is same inline FEED except Khuff Gas Injection flow line and
Arab-D Gas Injection flow line for design factor 0.6 which is shown below. Mother pipe
thickness is selected as per detailed design calculation which is not as per FEED as
following;
a) Mother pipe thickness for 3’’ Gas lift flow line = 6.20mm.
b) Mother pipe thickness for 6’’ Khuff Gas Production flow line = 15.90mm.
c) Line pipe (DF=0.6) and Mother pipe thickness for 6’’ Khuff Gas Injection flow line =
16.50mm.
d) Mother pipe thickness for 8’’ Arab-D Gas Production flow line = 13.5mm.
e) Line pipe (DF=0.6) and Mother pipe thickness for 6’’ Arab-D Gas Injection flow line =
12.7mm.
3.
4.11
From above calculation all thicknesses are in accordance with the thickness selection during
FEED as per Document 4021-DGEN-7-13-0001 Rev.2 except which is mentioned above
point 2.
Pipe Wall Thickness Stress Check as per ASME B31.8
The stress check also done for the selected wall thickness as per ASME B31.8 and found that
all the stresses are within the allowable limits refer Attachment-4. The summary of results are
listed below:
1. Gas lift flowline
Stress
Unit
Max
Allowable
Calculated
Value
Ratio of calculated
to allowable
Check
Hoop (SH)
Mpa
270.00
254.53
94.27%
OK
Thermal Expansion (SE)
Worst Case Scenario
Mpa
103.88
45.21
43.52%
OK
Longitudinal (SL)
Worst Case Scenario
Mpa
337.50
31.2
9.23%
OK
OVERALL STRESS CHECK OF WALL THICKNESS
ACCEPTED
2. Khuff Production flowline
Stress
Unit
Max
Allowable
Calculated
Value
Ratio of
calculated to
allowable
Check
Hoop (SH)
Mpa
270.00
268.06
99.28%
OK
PIPELINE DESIGN REPORT
Doc No.
4148-DGTYP-7-17-0001
Rev.:
Date:
Page
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17 of 26
Thermal Expansion (SE)
Worst Case Scenario
Mpa
96.59
70.04
72.51%
OK
Longitudinal (SL)
Worst Case Scenario
Mpa
337.50
10.4
3.08%
OK
OVERALL STRESS CHECK OF WALL THICKNESS
ACCEPTED
3. Khuff injection flowline (DF=0.72)
Stress
Unit
Max
Allowable
Calculated
Value
Ratio of
calculated to
allowable
Check
Hoop (SH)
Mpa
324.00
277.22
84.95%
OK
Thermal Expansion (SE)
Worst Case Scenario
Mpa
103.88
74.84
72.05%
OK
Longitudinal (SL)
Worst Case Scenario
Mpa
337.50
7.7
2.29%
OK
OVERALL STRESS CHECK OF WALL THICKNESS
ACCEPTED
4. Khuff injection flowline (DF=0.6)
Stress
Unit
Max
Allowable
Calculated
Value
Ratio of
calculated to
allowable
Check
Hoop (SH)
Mpa
270.00
229.76
85.10%
OK
Thermal Expansion (SE)
Worst Case Scenario
Mpa
103.88
70.04
67.42%
OK
Longitudinal (SL)
Worst Case Scenario
Mpa
337.50
-1.1
0.33%
OK
OVERALL STRESS CHECK OF WALL THICKNESS
ACCEPTED
5. RG production flowline
Stress
Unit
Max
Allowable
Calculated
Value
Ratio of
calculated to
allowable
Check
Hoop (SH)
Mpa
216.00
202.50
93.75%
OK
Thermal Expansion (SE)
Worst Case Scenario
Mpa
109.50
73.46
67.09%
OK
Longitudinal (SL)
Worst Case Scenario
Mpa
270.00
-12.7
4.71%
OK
OVERALL STRESS CHECK OF WALL THICKNESS
ACCEPTED
6. RG injection flowline (DF=0.72)
Stress
Unit
Max
Allowable
Calculated
Value
Ratio of
calculated to
allowable
Check
Hoop (SH)
Mpa
298.80
253.40
84.81%
OK
Thermal Expansion (SE)
Worst Case Scenario
Mpa
117.76
72.80
62.82%
OK
Longitudinal (SL)
Worst Case Scenario
Mpa
311.25
3.2
1.04%
OK
OVERALL STRESS CHECK OF WALL THICKNESS
ACCEPTED
PIPELINE DESIGN REPORT
Doc No.
4148-DGTYP-7-17-0001
Rev.:
Date:
Page
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18 of 26
7. RG injection flowline (DF=0.6)
Stress
Unit
Max
Allowable
Calculated
Value
Ratio of
calculated to
allowable
Check
Hoop (SH)
Mpa
249.00
208.21
83.62%
OK
Thermal Expansion (SE)
Worst Case Scenario
Mpa
117.76
67.88
57.65%
OK
Longitudinal (SL)
Worst Case Scenario
Mpa
311.25
-5.4
1.74%
OK
OVERALL STRESS CHECK OF WALL THICKNESS
4.12
ACCEPTED
Road Crossing Thickness Calculation: API RP 1102
In order to design the pipelines appropriately, all the pipeline crossing shall be qualified / checked
in accordance with API RP 1102 in order to ensure that the pipelines thickness is adequate for
underground buried road and track crossings.
4.12.1 Design Basis
1.
Traffic load shall be established and stress calculations to be performed for road crossings,
to ensure against failure and stresses to be within permissible limits. The calculations shall
not take the concrete protection slab into consideration.
2.
Design Pressure shall be used in the calculation.
3.
Cover depth considered is (1000mm (min Soil cover) Plus 200mm for road subbase) i.e.
total 1200mm. (This is also consistent with QP typical details for track crossings for normal
area).
4.
The effective stresses of the pipelines (Seff) have been checked against Design factor of
0.9, as this factor is defined in ASME B31.8 Para. 833.9 (b) as follows:
quote “The maximum allowable sum of circumferential stress due to internal pressure and
circumferential through-wall bending stress caused by surface vehicle loads or other local
loads is 0.9ST, where S is the specified minimum yield strength, psi, per Para. 841.1.1(a),
and T is the temperature derating factor per 841.1.8 unquote.
The effective stresses of the pipelines (Seff) have been checked against Design factor of 0.9,
as this factor is defined in ASME B31.4 Table 403.3.1-1.
Therefore, the checking formula for maximum allowable effective stresses will be as follows:
Seff < 0.9xSMYS
4.12.2 Type of Crossings According to API RP 1102
Two types of crossings are envisaged, which are as follows:
1.
Culvert Road Crossings
2.
Track Crossings
4.12.2.1 Culvert Road Crossing
There is no contact between the road and underground pipeline in culvert type road crossing.
Hence wall thickness check as per API 1102 is not applicable.
4.12.2.2 Track Crossing
At Track crossings underground Pipeline is buried in trench, below the track with concrete
protection slabs.
PIPELINE DESIGN REPORT
Doc No.
4148-DGTYP-7-17-0001
Rev.:
Date:
Page
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19 of 26
In order to check the adequacy of the selected wall thickness, calculations in accordance with
API RP 1102 have been carried out for “Uncased crossing”. The calculations are enclosed in
Attachment-5.
The results show that the combined stress in the pipelines due to the additional loading remains
within the allowable Material Yield strength.
Although the calculations show that a concrete slab is not necessary, a reinforced concrete slab
protection shall be installed for road crossings as per the Contract requirement.
4.12.3 Summary of Results
As per the calculation results, the pipelines thickness used for road crossings area are
acceptable since it is passing API RP 1102 calculations. For the detail calculations refer
Attachment 5.
The summary of calculation results as follows;
1. Gas lift flowline
Calculated
Allowable
Stress (PSI)
Stress (PSI)
Factor of
safety (FOS)
1.Barlow Stress Check
32,751
36,000
1.1
2.Principal Stresses (Seff)
26,137
54,000
2.1
3.Girt Weld Fatigue Check
2,221
7,200
3.2
4.Longitudinal Weld Fatigue Check
2,976
13,800
4.6
Calculated
Allowable
Stress (PSI)
Stress (PSI)
Factor of
safety (FOS)
Summary
2. Gas lift flowline
Summary
1.Barlow Stress Check
36,916
36,000
1.1
2.Principal Stresses (Seff)
27,313
58,500
2.1
3.Girt Weld Fatigue Check
2,754
7,200
2.6
4.Longitudinal Weld Fatigue Check
2,638
13,800
5.2
Calculated
Allowable
Stress (PSI)
Stress (PSI)
Factor of
safety (FOS)
1.Barlow Stress Check
27,954
36,000
1.3
2.Principal Stresses (Seff)
22,739
54,000
2.4
3.Girt Weld Fatigue Check
2,104
7,200
3.4
4.Longitudinal Weld Fatigue Check
1,988
13,800
6.9
Calculated
Allowable
Stress (PSI)
Stress (PSI)
Factor of
safety (FOS)
26,934
36,000
1.3
3. PWI flowline
Summary
4. UER Source well flowline
Summary
1.Barlow Stress Check
2.Principal Stresses (Seff)
24,823
54,000
2.2
3.Girt Weld Fatigue Check
2,092
7,200
3.4
4.Longitudinal Weld Fatigue Check
3,118
13,800
4.4
5. UER Recycle well flowline
PIPELINE DESIGN REPORT
Doc No.
4148-DGTYP-7-17-0001
Rev.:
Date:
Page
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20 of 26
Calculated
Allowable
Stress (PSI)
Stress (PSI)
Factor of
safety (FOS)
1.Barlow Stress Check
14,917
36,000
2.4
2.Principal Stresses (Seff)
19,765
54,000
2.7
3.Girt Weld Fatigue Check
1,981
7,200
3.6
4.Longitudinal Weld Fatigue Check
2,653
13,800
5.2
Calculated
Allowable
Stress (PSI)
Stress (PSI)
Factor of
safety (FOS)
1.Barlow Stress Check
38,874
36,000
1.0
2.Principal Stresses (Seff)
27,287
58,000
2.1
3.Girt Weld Fatigue Check
1,182
7,200
6.1
4.Longitudinal Weld Fatigue Check
674
13,800
20.5
Calculated
Allowable
Stress (PSI)
Stress (PSI)
Factor of
safety (FOS)
Summary
6. Khuff Production flowline
Summary
7. Khuff injection flowline
Summary
1.Barlow Stress Check
33,320
36,000
1.2
2.Principal Stresses (Seff)
24,170
58,000
2.4
3.Girt Weld Fatigue Check
1,137
7,200
6.3
4.Longitudinal Weld Fatigue Check
463
13,800
29.8
Calculated
Allowable
Stress (PSI)
Stress (PSI)
Factor of
safety (FOS)
1.Barlow Stress Check
29,367
31,200
1.1
2.Principal Stresses (Seff)
23,467
46,800
2.0
3.Girt Weld Fatigue Check
1,137
7,200
5.4
4.Longitudinal Weld Fatigue Check
1,434
13,800
9.6
Calculated
Allowable
Stress (PSI)
Stress (PSI)
Factor of
safety (FOS)
30,194
36,000
1.2
8. RG production flowline
Summary
9. RG injection flowline
Summary
1.Barlow Stress Check
2.Principal Stresses (Seff)
23,265
54,000
2.3
3.Girt Weld Fatigue Check
1,270
7,200
5.7
4.Longitudinal Weld Fatigue Check
943
13,800
14.6
PIPELINE DESIGN REPORT
5.0
ATTACHMENTS
Doc No.
4148-DGTYP-7-17-0001
Rev.:
Date:
Page
C
12/10/2021
21 of 26
PIPELINE DESIGN REPORT
5.1
Doc No.
4148-DGTYP-7-17-0001
Rev.:
Date:
Page
C
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22 of 26
Attachment 1: Results for Wall Thickness / Thinning Calculations as per ASME B31.4
CONTRACT NO: 4121 / GC191008B0
PROJECT TITLE:
Design Code
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION &
HOOK-UP OF WELL FLOWLINES IN DUKHAN FIELDS (2019-2022)
ASME B31.4
LOCATION: DUKHAN FIELDS
6'' Oil Flow line
Item
Symbol
Line Pipe Material
Equation / Remarks
Units
API 5L
Calc1
Calc2
(Oil Flow Line)
(Oil Flow Line)
X60
X60
Design Pressure
P
barg
110.00
110.00
Design Temperature
T
ºC
84
84
inch
6
6
mm
168.3
168.3
Pipeline Nominal Bore
Pipeline Outside Diameter
D
Longitudinal Weld Joint Factor
E
1
1
Design Factor
F
0.72
0.60
Specified Min. Yield Strength
SMYS
X60 Materials
MPa
415
415
Allowable Stress
S
F x E x SMYS
MPa
298.80
249.00
Corrosion Allowance,
c
mm
3
3
Pressure Thickness
t
P*D/20S
mm
3.10
3.72
t+c
mm
6.10
6.72
mm
7.11
7.11
tmin
Minimum Required Thickness
Pipe Thickness Selected
ts
Outside Dia. to Wall Thk. Ration
-
OD/tsel1 (<96)
OK
OK
Check point
-
ts >= tmin
OK
OK
Pipeline Inside Diameter
d
D - 2 * ts
mm
154
154
Pipe Volume Per Linear mtr
A
(D^2 - d^2) *
m3/m
0.0036
0.0036
Carbon Steel Density
ρ
kg/m3
7850
7850
Kg/m
W
28.260
28.260
Line Pipe Weight
Doc. No.: 4148-DGTYP-7-17-0001
π/4
Attachment-1
CONTRACT NO: 4121 / GC191008B0
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-
PROJECT TITLE:
UP OF WELL FLOWLINES IN DUKHAN FIELDS (2019-2022) - PART B
Design Code
ASME B31.4
LOCATION: DUKHAN FIELDS
4'' PWI flowline
Item
Symbol
Line Size
D
Pipe Bend Radius
R0
Pipe Bending Inner Radius
R
R0 - 0.5
Pipe Thinning Ratio
n
R/D
Estimated Thining%
%thin
50 / (n+1)
Used Thining%
%thin_Used
Design Factor
F
Minimum Required Thickness
tmin
Pipe Thickness Selected
ts
Post Bending Wall Thickness,
Tp
ts * (1 - %thin_Used)
Check point
-
ts >= tmin?
Doc. No.: 4148-DGTYP-7-17-0001
Equation / Remarks
Hot Induction Bend
Field (Cold) Bend
Hot Induction Bend
Field (Cold) Bend
(PWI Flowline)
(PWI Flowline)
(PWI Flowline)
(PWI Flowline)
4
4
4
4
20D
40D
20D
40D
19.5D
39.5D
19.5D
39.5D
19.5
39.5
19.5
39.5
2.44%
1.23%
2.44%
1.23%
3%
2%
2%
3%
0.72
0.72
0.60
0.60
mm
5.67
5.67
6.20
6.20
mm
7.14
7.14
7.14
7.14
mm
6.93
7.00
7.00
6.93
OK
OK
OK
OK
Units
Inch
%
Attachment-1
CONTRACT NO: 4121 / GC191008B0
PROJECT TITLE:
Design Code
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION &
HOOK-UP OF WELL FLOWLINES IN DUKHAN FIELDS (2019-2022)
ASME B31.4
LOCATION: DUKHAN FIELDS
4'' PWI flowline
Item
Symbol
Line Pipe Material
Equation / Remarks
Units
API 5L
Calc1
Calc2
(PWI Flowline)
(PWI Flowline)
X60
X60
Design Pressure
P
barg
139.62
139.62
Design Temperature
T
ºC
84
84
inch
4
4
mm
114.3
114.3
Pipeline Nominal Bore
Pipeline Outside Diameter
D
Longitudinal Weld Joint Factor
E
1
1
Design Factor
F
0.72
0.60
Specified Min. Yield Strength
SMYS
X60 Materials
MPa
415
415
Allowable Stress
S
F x E x SMYS
MPa
298.80
249.00
Corrosion Allowance,
c
mm
3
3
Pressure Thickness
t
P*D/20S
mm
2.67
3.20
t+c
mm
5.67
6.20
mm
7.14
7.14
tmin
Minimum Required Thickness
Pipe Thickness Selected
ts
Outside Dia. to Wall Thk. Ration
-
OD/tsel1 (<96)
OK
OK
Check point
-
ts >= tmin
OK
OK
Pipeline Inside Diameter
d
D - 2 * ts
mm
100
100
Pipe Volume Per Linear mtr
A
(D^2 - d^2) *
m3/m
0.0024
0.0024
Carbon Steel Density
ρ
kg/m3
7850
7850
Kg/m
W
18.869
18.869
Line Pipe Weight
Doc. No.: 4148-DGTYP-7-17-0001
π/4
Attachment-1
CONTRACT NO: 4121 / GC191008B0
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP
PROJECT TITLE:
OF WELL FLOWLINES IN DUKHAN FIELDS (2019-2022) - PART B
Design Code
ASME B31.4
LOCATION: DUKHAN FIELDS
8'' UER Source well flowline
Item
Symbol
Equation / Remarks
Line Size
D
Pipe Bend Radius
R0
Pipe Bending Inner Radius
R
R0 - 0.5
Pipe Thinning Ratio
n
R/D
Estimated Thining%
%thin
50 / (n+1)
Used Thining%
%thin_Used
Design Factor
F
Minimum Required Thickness
tmin
Pipe Thickness Selected
ts
Post Bending Wall Thickness,
Tp
ts * (1 - %thin_Used)
Check point
-
ts >= tmin?
Doc. No.: 4148-DGTYP-7-17-0001
Units
Inch
Hot Induction Bend
Field (Cold) Bend
Hot Induction Bend
(UER Source Well
(UER Source Well
(UER Source Well
Flowline)
Flowline)
Flowline)
8
8
8
8
20D
40D
20D
40D
19.5D
39.5D
19.5D
39.5D
Field (Cold) Bend
(UER Source Well Flowline)
19.5
39.5
19.5
39.5
2.44%
1.23%
2.44%
1.23%
3%
2%
3%
2%
0.72
0.72
0.60
0.60
mm
4.59
4.59
4.91
4.91
mm
5.56
5.56
5.56
5.56
mm
5.39
5.45
5.39
5.45
OK
OK
OK
OK
%
Attachment-1
CONTRACT NO: 4121 / GC191008B0
PROJECT TITLE:
Design Code
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION &
HOOK-UP OF WELL FLOWLINES IN DUKHAN FIELDS (2019-2022)
ASME B31.4
LOCATION: DUKHAN FIELDS
8'' UER Source well flowline
Item
Symbol
Line Pipe Material
Equation / Remarks
Units
API 5L
Calc1
Calc2
(UER Source Well
(UER Source Well
Flowline)
Flowline)
X60
X60
Design Pressure
P
barg
43.40
43.40
Design Temperature
T
ºC
84
84
inch
8
8
mm
219.1
219.1
Pipeline Nominal Bore
Pipeline Outside Diameter
D
Longitudinal Weld Joint Factor
E
1
1
Design Factor
F
0.72
0.60
Specified Min. Yield Strength
SMYS
X60 Materials
MPa
415
415
Allowable Stress
S
F x E x SMYS
MPa
298.80
249.00
Corrosion Allowance,
c
mm
3
3
Pressure Thickness
t
P*D/20S
mm
1.59
1.91
t+c
mm
4.59
4.91
mm
5.56
5.56
Minimum Required Thickness
tmin
Pipe Thickness Selected
ts
Outside Dia. to Wall Thk. Ration
-
OD/tsel1 (<96)
OK
OK
Check point
-
ts >= tmin
OK
OK
Pipeline Inside Diameter
d
D - 2 * ts
mm
208
208
Pipe Volume Per Linear mtr
A
(D^2 - d^2) *
m3/m
0.0037
0.0037
Carbon Steel Density
ρ
kg/m3
7850
7850
Kg/m
W
29.280
29.280
Line Pipe Weight
Doc. No.: 4148-DGTYP-7-17-0001
π/4
Attachment-1
CONTRACT NO: 4121 / GC191008B0
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP
PROJECT TITLE:
OF WELL FLOWLINES IN DUKHAN FIELDS (2019-2022) - PART B
Design Code
ASME B31.4
LOCATION: DUKHAN FIELDS
8'' UER Recycle well flowline
Item
Symbol
Equation / Remarks
Line Size
D
Pipe Bend Radius
R0
Pipe Bending Inner Radius
R
R0 - 0.5
Pipe Thinning Ratio
n
R/D
Estimated Thining%
%thin
50 / (n+1)
Used Thining%
%thin_Used
Design Factor
F
Minimum Required Thickness
tmin
Pipe Thickness Selected
ts
Post Bending Wall Thickness,
Tp
ts * (1 - %thin_Used)
Check point
-
ts >= tmin?
Doc. No.: 4148-DGTYP-7-17-0001
Units
Inch
Hot Induction Bend
Field (Cold) Bend
Hot Induction Bend
(UER Recycle Well
(UER Recycle Well
(UER Recycle Well
Flowline)
Flowline)
Flowline)
8
8
8
8
20D
40D
20D
40D
19.5D
39.5D
19.5D
39.5D
Field (Cold) Bend
(UER Recycle Well Flowline)
19.5
39.5
19.5
39.5
2.44%
1.23%
2.44%
1.23%
3%
2%
3%
2%
0.72
0.72
0.60
0.60
mm
3.62
3.62
3.74
3.74
mm
5.40
5.40
5.40
5.40
mm
5.24
5.29
5.24
5.29
OK
OK
OK
OK
%
Attachment-1
CONTRACT NO: 4121 / GC191008B0
PROJECT TITLE:
Design Code
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION &
HOOK-UP OF WELL FLOWLINES IN DUKHAN FIELDS (2019-2022)
ASME B31.4
LOCATION: DUKHAN FIELDS
8'' UER Recycle well flowline
Calc1
Item
Symbol
Line Pipe Material
Equation / Remarks
Units
API 5L
Calc2
(UER Recycle Well (UER Recycle Well
Flowline)
Flowline)
X60
X60
Design Pressure
P
barg
16.90
16.90
Design Temperature
T
ºC
84
84
inch
8
8
mm
219.1
219.1
Pipeline Nominal Bore
Pipeline Outside Diameter
D
Longitudinal Weld Joint Factor
E
1
1
Design Factor
F
0.72
0.60
Specified Min. Yield Strength
SMYS
X60 Materials
MPa
415
415
Allowable Stress
S
F x E x SMYS
MPa
298.80
249.00
Corrosion Allowance,
c
mm
3
3
Pressure Thickness
t
P*D/20S
mm
0.62
0.74
t+c
mm
3.62
3.74
mm
4.80
4.80
Minimum Required Thickness
tmin
Pipe Thickness Selected
ts
Outside Dia. to Wall Thk. Ration
-
OD/tsel1 (<96)
OK
OK
Check point
-
ts >= tmin
OK
OK
Pipeline Inside Diameter
d
D - 2 * ts
mm
210
210
Pipe Volume Per Linear mtr
A
(D^2 - d^2) *
m3/m
0.0032
0.0032
Carbon Steel Density
ρ
kg/m3
7850
7850
Kg/m
W
25.368
25.368
Line Pipe Weight
Doc. No.: 4148-DGTYP-7-17-0001
π/4
Attachment-1
PIPELINE DESIGN REPORT
5.2
Doc No.
4148-DGTYP-7-17-0001
Rev.:
Date:
Page
C
12/10/2021
23 of 26
Attachment 2: Pipe Wall Thickness Stress Check as per ASME B31.4
Attachment - Wall Thickness Calculation - Stress Check
WALL THICKNESS CALCULATION SHEET- STRESS CHECK AS PER ASME B31.4
PROJECT:
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN DUKHAN FIELDS (2019-2022) - PART B
LOCATION: DUKHAN, QATAR
SYSTEM DESCRIPTION: OIL FLOWLINE / DF = 0.6
PIPE WALL THICKNESS CALCULATION TO ASME B31.4 (UNRESTRAINED)
1.0 INTRODUCTION
1.1 Description
This Excel sheet completes the wall thickness calculation for pipeline system in line with the design requirements outlined within the ASME B31.4. The sheet determines the required wall thickness for
pressure containment and stress requirements.
1.2 Codes
(1) ASME B31.4
(2) API 5L
(3) ASME B36.10
1.3 Assumptions
(1) This Excel sheet is currently set up for CARBON STEEL only.
(2) This Calculation is applicable for Above Ground, unrestrained pipelines only.
(3) Design temperature -29ºC<T<120ºC
(4) Compressive stress is a negative value
2.0 DESIGN DATA SUMMARY
2.1 Pipeline Data
Product / Liquid Type
Oil Flowline
Selected Pipe Material
API 5L
X60
Grade
Specified Minimum Yield Strength
SMYS =
415.00
MPa
Ref. API 5L Table-7
Modulus of Elasticity of steel
Es =
203000
MPa
Ref. (3) Table C-1 (SI)
Poisson's ratio
v=
Weld Joint Factor
E=
1
Coefficient of Thermal Expansion
α=
0.0000117
0.30
Note (1)
Ref. (1) Para 402.2.3
Ref. (1) Table 403.2.1-1
◦
mm/mm. C
Ref. (1) Para 402.2.1 (Valid up to 120ºC)
2.2 Input Data
Nominal Pipe Size
NPS =
Pipe Outside Diameter
D=
168.30
6
mm
Internal Design gage Pressure
Pi =
110
barg
From Process Data
Maximum Operating Temperature
T2,MAX =
84
ºC
From Process Data
Ref. (1) Para. 402.5.1
Minimum Operating Temperature
T2,MIN =
0
ºC
From Process Data
Ref. (1) Para. 402.5.1
Installation Temperature
T1 =
21
ºC
From Process Data
Design Factor
F=
0.6
Corrosion Allowance
Ca =
Water Density
ρwater
External Force Axial Component (if any)
Fx =
3
=
1000
0
in
mm
3
kg/m
N
Fatigue factor
f=
2⁄3Sy at the lower of the installed or minimum operating temperature
Scold
276.67
MPa
2⁄3Sy at the higher of the installed or maximum operating temperature
Shot
276.67
MPa
4148-DGTYP-7-17-0001
1
Rev.C
Note (2)
Attachment - Wall Thickness Calculation - Stress Check
3.0 EQUATIONS
Equation
Unit
Eq. No.
[Mpa]
(1)
Notes
3.1 Stresss
3.1.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL = F.E.SY
Max Allowable Expansion Stress
SE,ALL = f[1.25(Scold+Shot)-SL]
[Mpa]
(2)
Ref. (1) Para 403.3.2
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL = 80%.SY
[Mpa]
(3)
Ref. (1) Table 403.3.1-1
Hoop Stress
SH = Pi.D / 20.tmin
[Mpa]
(6)
Longitudinal Stress due to Internal Pressure
SL,P =
[Mpa]
(7)
Thermal Expansion Stress: Case 1
ST1=
Es.α.(ΔTCase1)
[Mpa]
(8)
Thermal Expansion Stress: Case 2
ST2=
Es.α.(ΔTCase2)
[Mpa]
(9)
Longitudinal Stress due to Axial Loading
Sx = Fx / A
[Mpa]
(10)
Bending Stress (Tension)
SBT = iM / Z
[Mpa]
(11)
Bending Stress (Compression)
SBC= -iM / Z
[Mpa]
(12)
Longitudinal Stress (Sustained Loads): Case 1
SL1=ST1 + SL,P + SBT + Sx
[Mpa]
(13)
Ref. (1) Para 402.6.2
Longitudinal Stress (Sustained Loads): Case 2
SL2=ST1 + SL,P + SBC + Sx
[Mpa]
(14)
Ref. (1) Para 402.6.2
Longitudinal Stress (Sustained Loads): Case 3
SL3=ST2 + SL,P + SBT + Sx
[Mpa]
(15)
Ref. (1) Para 402.6.2
Longitudinal Stress (Sustained Loads): Case 4
SL4=ST2 + SL,P + SBC + Sx
[Mpa]
(16)
Ref. (1) Para 402.6.2
Ref. (1) Table 403.3.1-1
3.1.2 Stresses
ν.SH
3.1.3 Ratios
Ratio to SMYS
SMYS % = SH / SY
[%]
(20)
Ratio of calculated to Allowable (Hoop)
%H = SH / SH,ALL
[%]
(21)
Ratio of calculated to Allowable (Longitudinal)
%L = SL / SL,ALL
[%]
(22)
3.2 Wall Thickness
Calculated wall thickness
t =Pi.D / 20.SH,ALL
[mm]
(25)
Ref. (1) Para 403.2.1
Calculated wall thickness with corrosion allowance
tn = t + Ca
[mm]
(26)
Ref. (1) Para 403.2.1
Selected wall thickness
ts > tn
[mm]
(27)
Ref. (2) Table 1
Minimum wall thickness
tmin = ts - Ca
[mm]
(28)
Din = D-2tmin
[mm]
(29)
3.3 Pipeline Properties
Internal Diameter of the Pipe
Pipe moment of Inertia
I=
4
π (D
-
Pipe section modulus
Z=2*I/D
Pipe Metal Cross Section Area
A=
2
π (D
4
Din )
/64
2
- Din ) / 4
4
[m ]
(30)
3
[cm ]
(31)
[mm ]
2
(32)
3.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1= T1 - T2,MAX
[ºC]
(33)
Ref (1) Para 402.6.1
Temperature Difference: Case 2
ΔTCase2= T1 - T2,MIN
[ºC]
(34)
Ref (1) Para 402.6.1
[N.m]
(35)
[-]
(43)
3.5 Bending Moment
Bending Moment
M=Es.I/R
3.7 Stress Intensification Factor
Stress Intensification Factor
4148-DGTYP-7-17-0001
i=1
Rev.C
Note (4)
Attachment - Wall Thickness Calculation - Stress Check
4.0 CALCULATIONS
4.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL =
249.00
MPa
[Eq. (1)]
Max Allowable Expansion Stress
SE,ALL =
359.67
MPa
[Eq. (2)]
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL =
332.00
MPa
[Eq. (3)]
4.2 Wall Thickness
Calculated wall thickness
t=
3.72
mm
[Eq. (25)]
Calculated wall thickness with corrosion allowance
tn =
6.72
mm
[Eq. (26)]
Selected wall thickness
ts =
7.11
mm
[Eq. (27)]
Minimum wall thickness
tmin =
4.11
mm
[Eq. (28)]
Check Acceptability:
If tn<ts, selected wall thickness is accepted
Accepted
Ref. (1) Para 403.2.1
4.2.1 D/t ratio for constructability and handing evaluation
D / ts =
23.67
Note (5)
4.3 Pipeline Properties
Internal Diameter
Din =
Pipe moment of Inertia
I=
0.000007
Pipe section modulus
Z=
84.95
cm
Pipe Metal Cross Section Area
A=
2120.01
mm
[Eq. (32)]
160.08
mm
[Eq. (29)]
4
[Eq. (30)]
m
3
[Eq. (31)]
2
4.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1=
-63
ºC
[Eq. (33)]
Temperature Difference: Case 2
ΔTCase2=
21
ºC
[Eq. (34)]
5.77E+03
N.m
[Eq. (35)]
4.5 Bending Moment
Bending Moment
M=
4.6 Pipeline Stresses
4.6.1 Hoop Stress
Hoop Stress
SH =
225.22
MPa
Ratio to SMYS
SMYS %=
54.27%
%
[Eq. (20)]
Ratio of calculated to Allowable (Hoop)
%H =
90.45%
%
[Eq. (21)]
If SH<SH,ALL, selected wall thickness is acceptable
Check Acceptability:
[Eq. (6)]
Accepted
Ref. (1) Table 403.3.1-1
4.6.2 Longitudinal Stress
Thermal Expansion Stress: Case 1
ST1=
-149.63
MPa
[Eq. (8)]
Thermal Expansion Stress: Case 2
ST2=
49.88
MPa
[Eq. (9)]
Check Acceptability:
If (ST1, ST2)<SE,ALL, selected wall thickness is acceptable
Accepted
Ref. (1) Table 403.3.1-1
Longitudinal Stress due to Internal Pressure
SL,P =
67.57
MPa
[Eq. (7)]
Bending Stress (Tension)
SBT =
67.88
MPa
[Eq. (11)]
Bending Stress (Compression)
SBC=
-67.88
MPa
[Eq. (12)]
Longitudinal Stress due to Axial Loading
Sx=
0.00
Mpa
[Eq. (10)]
Longitudinal Stress (Sustained Loads): Case 1
SL1=
-14.2
Mpa
[Eq. (13)]
Ratio of calculated to Allowable (Longitudinal)
%L1 =
4.27%
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 2
SL2=
-149.9
Mpa
[Eq. (14)]
Ratio of calculated to Allowable (Longitudinal)
%L2 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 3
SL3=
Mpa
[Eq. (15)]
Ratio of calculated to Allowable (Longitudinal)
%L3 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 4
SL4=
Mpa
[Eq. (16)]
Ratio of calculated to Allowable (Longitudinal)
%L4 =
%
[Eq. (22)]
(1) Four cases of evaluation
45.16%
185.3
55.82%
49.6
14.93%
Check Acceptability:
If all ǀSLǀ<SL,ALL, selected wall thickness is acceptable
4148-DGTYP-7-17-0001
Rev.C
Accepted
Ref. (1) Table 403.3.1-1
Attachment - Wall Thickness Calculation - Stress Check
5.0 RESULTS SUMMARY
5.1 Results
5.1.1 Wall Thickness
Calculated Wall Thickness
Selected Wall Thickness
D to t Ratio
t=
3.72
mm
ts =
7.11
mm
D/t=
23.67
5.1.2 Calculated Stress Values
Max
Ratio of calculated to
Stress
Unit
Hoop (SH)
Mpa
249.00
225.22
90.45%
OK
Mpa
359.67
-149.63
41.60%
OK
Mpa
332.00
-149.9
45.16%
OK
Allowable
Calculated Value
allowable
Check
Thermal Expansion
(SE)
Worst Case Scenario
Longitudinal (SL)
Worst Case Scenario
OVERALL CHECK OF WALL THICKNESS
5.2 Notes
(1) For SI units, the calculated value shall be rounded to the nearest 5 MPa.
(2) Not Applicable for A/G Pipeline
(3) Applied for sustained loads
(4) Stress intensification factor equals 1 for straight pipe (See Ref. (1) Paragraph 402.6.2)
(5) Minimum wall thickness of pipe shall not be less than 4.8mm
4148-DGTYP-7-17-0001
Rev.C
ACCEPTED
Attachment - Wall Thickness Calculation - Stress Check
WALL THICKNESS CALCULATION SHEET- STRESS CHECK AS PER ASME B31.4
PROJECT:
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN DUKHAN FIELDS (2019-2022) - PART B
LOCATION: DUKHAN, QATAR
SYSTEM DESCRIPTION: PRODUCED WATER INJECTION FLOWLINE / DF = 0.6
PIPE WALL THICKNESS CALCULATION TO ASME B31.4 (UNRESTRAINED)
1.0 INTRODUCTION
1.1 Description
This Excel sheet completes the wall thickness calculation for pipeline system in line with the design requirements outlined within the
ASME B31.4. The sheet determines the required wall thickness for pressure containment and stress requirements.
1.2 Codes
(1) ASME B31.4
(2) API 5L
(3) ASME B36.10
1.3 Assumptions
(1) This Excel sheet is currently set up for CARBON STEEL only.
(2) This Calculation is applicable for Above Ground, unrestrained pipelines only.
(3) Design temperature -29ºC<T<120ºC
(4) Compressive stress is a negative value
2.0 DESIGN DATA SUMMARY
2.1 Pipeline Data
Product / Liquid Type
Produced Water Injection Flowline
Selected Pipe Material
API 5L
X60
Grade
Specified Minimum Yield Strength
SMYS =
415.00
MPa
Ref. API 5L Table-7
Modulus of Elasticity of steel
Es =
203000
MPa
Ref. (3) Table C-1 (SI)
Poisson's ratio
v=
Weld Joint Factor
E=
1
Coefficient of Thermal Expansion
α=
0.0000117
0.30
Note (1)
Ref. (1) Para 402.2.3
Ref. (1) Table 403.2.1-1
◦
mm/mm. C
Ref. (1) Para 402.2.1 (Valid up to 120ºC)
2.2 Input Data
Nominal Pipe Size
NPS =
Pipe Outside Diameter
D=
114.30
4
mm
Internal Design gage Pressure
Pi =
139.62
barg
From Process Data
Maximum Operating Temperature
T2,MAX =
84
ºC
From Process Data
Ref. (1) Para. 402.5.1
Minimum Operating Temperature
T2,MIN =
0
ºC
From Process Data
Ref. (1) Para. 402.5.1
Installation Temperature
T1 =
21
ºC
From Process Data
Design Factor
F=
0.72
Corrosion Allowance
Ca =
Water Density
ρwater
External Force Axial Component (if any)
Fx =
3
=
1000
0
in
mm
3
kg/m
N
Fatigue factor
f=
2⁄3Sy at the lower of the installed or minimum operating temperature
Scold
276.67
MPa
2⁄3Sy at the higher of the installed or maximum operating temperature
Shot
276.67
MPa
4148-DGTYP-7-17-0001
1
Rev.C
Note (2)
Attachment - Wall Thickness Calculation - Stress Check
3.0 EQUATIONS
Equation
Unit
Eq. No.
[Mpa]
(1)
Notes
3.1 Stresss
3.1.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL = F.E.SY
Max Allowable Expansion Stress
SE,ALL = f[1.25(Scold+Shot)-SL]
[Mpa]
(2)
Ref. (1) Para 403.3.2
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL = 80%.SY
[Mpa]
(3)
Ref. (1) Table 403.3.1-1
Hoop Stress
SH = Pi.D / 20.tmin
[Mpa]
(6)
Longitudinal Stress due to Internal Pressure
SL,P =
[Mpa]
(7)
Thermal Expansion Stress: Case 1
ST1=
Es.α.(ΔTCase1)
[Mpa]
(8)
Thermal Expansion Stress: Case 2
ST2=
Es.α.(ΔTCase2)
[Mpa]
(9)
Longitudinal Stress due to Axial Loading
Sx = Fx / A
[Mpa]
(10)
Bending Stress (Tension)
SBT = iM / Z
[Mpa]
(11)
Bending Stress (Compression)
SBC= -iM / Z
[Mpa]
(12)
Longitudinal Stress (Sustained Loads): Case 1
SL1=ST1 + SL,P + SBT + Sx
[Mpa]
(13)
Ref. (1) Para 402.6.2
Longitudinal Stress (Sustained Loads): Case 2
SL2=ST1 + SL,P + SBC + Sx
[Mpa]
(14)
Ref. (1) Para 402.6.2
Longitudinal Stress (Sustained Loads): Case 3
SL3=ST2 + SL,P + SBT + Sx
[Mpa]
(15)
Ref. (1) Para 402.6.2
Longitudinal Stress (Sustained Loads): Case 4
SL4=ST2 + SL,P + SBC + Sx
[Mpa]
(16)
Ref. (1) Para 402.6.2
Ref. (1) Table 403.3.1-1
3.1.2 Stresses
ν.SH
3.1.3 Ratios
Ratio to SMYS
SMYS % = SH / SY
[%]
(20)
Ratio of calculated to Allowable (Hoop)
%H = SH / SH,ALL
[%]
(21)
Ratio of calculated to Allowable (Longitudinal)
%L = SL / SL,ALL
[%]
(22)
3.2 Wall Thickness
Calculated wall thickness
t =Pi.D / 20.SH,ALL
[mm]
(25)
Ref. (1) Para 403.2.1
Calculated wall thickness with corrosion allowance
tn = t + Ca
[mm]
(26)
Ref. (1) Para 403.2.1
Selected wall thickness
ts > tn
[mm]
(27)
Ref. (2) Table 1
Minimum wall thickness
tmin = ts - Ca
[mm]
(28)
Din = D-2tmin
[mm]
(29)
3.3 Pipeline Properties
Internal Diameter of the Pipe
Pipe moment of Inertia
I=
4
π (D
-
Pipe section modulus
Z=2*I/D
Pipe Metal Cross Section Area
A=
2
π (D
4
Din )
/64
2
- Din ) / 4
4
[m ]
(30)
3
[cm ]
(31)
[mm ]
2
(32)
3.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1= T1 - T2,MAX
[ºC]
(33)
Ref (1) Para 402.6.1
Temperature Difference: Case 2
ΔTCase2= T1 - T2,MIN
[ºC]
(34)
Ref (1) Para 402.6.1
[N.m]
(35)
[-]
(43)
3.5 Bending Moment
Bending Moment
M=Es.I/R
3.7 Stress Intensification Factor
Stress Intensification Factor
4148-DGTYP-7-17-0001
i=1
Rev.C
Note (4)
Attachment - Wall Thickness Calculation - Stress Check
4.0 CALCULATIONS
4.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL =
298.80
MPa
[Eq. (1)]
Max Allowable Expansion Stress
SE,ALL =
359.67
MPa
[Eq. (2)]
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL =
332.00
MPa
[Eq. (3)]
4.2 Wall Thickness
Calculated wall thickness
t=
2.67
mm
[Eq. (25)]
Calculated wall thickness with corrosion allowance
tn =
5.67
mm
[Eq. (26)]
Selected wall thickness
ts =
7.14
mm
[Eq. (27)]
Minimum wall thickness
tmin =
4.14
mm
[Eq. (28)]
Check Acceptability:
If tn<ts, selected wall thickness is accepted
Accepted
Ref. (1) Para 403.2.1
4.2.1 D/t ratio for constructability and handing evaluation
D / ts =
16.01
Note (5)
4.3 Pipeline Properties
Internal Diameter
Din =
Pipe moment of Inertia
I=
0.000002
Pipe section modulus
Z=
38.08
cm
Pipe Metal Cross Section Area
A=
1432.76
mm
[Eq. (32)]
106.02
mm
[Eq. (29)]
4
[Eq. (30)]
m
3
[Eq. (31)]
2
4.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1=
-63
ºC
[Eq. (33)]
Temperature Difference: Case 2
ΔTCase2=
21
ºC
[Eq. (34)]
2.13E+03
N.m
[Eq. (35)]
4.5 Bending Moment
Bending Moment
M=
4.6 Pipeline Stresses
4.6.1 Hoop Stress
Hoop Stress
SH =
192.74
MPa
Ratio to SMYS
SMYS %=
46.44%
%
[Eq. (20)]
Ratio of calculated to Allowable (Hoop)
%H =
64.50%
%
[Eq. (21)]
If SH<SH,ALL, selected wall thickness is acceptable
Check Acceptability:
[Eq. (6)]
Accepted
Ref. (1) Table 403.3.1-1
4.6.2 Longitudinal Stress
Thermal Expansion Stress: Case 1
ST1=
-149.63
MPa
[Eq. (8)]
Thermal Expansion Stress: Case 2
ST2=
49.88
MPa
[Eq. (9)]
Check Acceptability:
If (ST1, ST2)<SE,ALL, selected wall thickness is acceptable
Accepted
Ref. (1) Table 403.3.1-1
Longitudinal Stress due to Internal Pressure
SL,P =
57.82
MPa
[Eq. (7)]
Bending Stress (Tension)
SBT =
55.91
MPa
[Eq. (11)]
Bending Stress (Compression)
SBC=
-55.91
MPa
[Eq. (12)]
Longitudinal Stress due to Axial Loading
Sx=
0.00
Mpa
[Eq. (10)]
Longitudinal Stress (Sustained Loads): Case 1
SL1=
-35.9
Mpa
[Eq. (13)]
Ratio of calculated to Allowable (Longitudinal)
%L1 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 2
SL2=
Mpa
[Eq. (14)]
Ratio of calculated to Allowable (Longitudinal)
%L2 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 3
SL3=
Mpa
[Eq. (15)]
Ratio of calculated to Allowable (Longitudinal)
%L3 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 4
SL4=
Mpa
[Eq. (16)]
Ratio of calculated to Allowable (Longitudinal)
%L4 =
%
[Eq. (22)]
(1) Four cases of evaluation
10.81%
-147.7
44.49%
163.6
49.28%
51.8
15.60%
Check Acceptability:
If all ǀSLǀ<SL,ALL, selected wall thickness is acceptable
4148-DGTYP-7-17-0001
Rev.C
Accepted
Ref. (1) Table 403.3.1-1
Attachment - Wall Thickness Calculation - Stress Check
5.0 RESULTS SUMMARY
5.1 Results
5.1.1 Wall Thickness
Calculated Wall Thickness
Selected Wall Thickness
D to t Ratio
t=
2.67
mm
ts =
7.14
mm
D/t=
16.01
5.1.2 Calculated Stress Values
Max
Ratio of calculated to
Stress
Unit
Hoop (SH)
Mpa
298.80
192.74
64.50%
OK
Mpa
359.67
-149.63
41.60%
OK
Mpa
332.00
-147.7
44.49%
OK
Allowable
Calculated Value
allowable
Check
Thermal Expansion
(SE)
Worst Case Scenario
Longitudinal (SL)
Worst Case Scenario
OVERALL CHECK OF WALL THICKNESS
5.2 Notes
(1) For SI units, the calculated value shall be rounded to the nearest 5 MPa.
(2) Not Applicable for A/G Pipeline
(3) Applied for sustained loads
(4) Stress intensification factor equals 1 for straight pipe (See Ref. (1) Paragraph 402.6.2)
(5) Minimum wall thickness of pipe shall not be less than 4.8mm
4148-DGTYP-7-17-0001
Rev.C
ACCEPTED
Attachment - Wall Thickness Calculation - Stress Check
WALL THICKNESS CALCULATION SHEET- STRESS CHECK AS PER ASME B31.4
PROJECT:
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN DUKHAN FIELDS (2019-2022) - PART B
LOCATION: DUKHAN, QATAR
SYSTEM DESCRIPTION: SOURCE WELL FLOWLINE / DF = 0.6
PIPE WALL THICKNESS CALCULATION TO ASME B31.4 (UNRESTRAINED)
1.0 INTRODUCTION
1.1 Description
This Excel sheet completes the wall thickness calculation for pipeline system in line with the design requirements outlined within the ASME B31.4. The sheet determines the required wall thickness for
pressure containment and stress requirements.
1.2 Codes
(1) ASME B31.4
(2) API 5L
(3) ASME B36.10
1.3 Assumptions
(1) This Excel sheet is currently set up for CARBON STEEL only.
(2) This Calculation is applicable for Above Ground, unrestrained pipelines only.
(3) Design temperature -29ºC<T<120ºC
(4) Compressive stress is a negative value
2.0 DESIGN DATA SUMMARY
2.1 Pipeline Data
Product / Liquid Type
Source Well Flowline
Selected Pipe Material
API 5L
X60
Grade
Specified Minimum Yield Strength
SMYS =
415.00
MPa
Ref. API 5L Table-7
Modulus of Elasticity of steel
Es =
203000
MPa
Ref. (3) Table C-1 (SI)
Poisson's ratio
v=
Weld Joint Factor
E=
1
Coefficient of Thermal Expansion
α=
0.0000117
0.30
Note (1)
Ref. (1) Para 402.2.3
Ref. (1) Table 403.2.1-1
◦
mm/mm. C
Ref. (1) Para 402.2.1 (Valid up to 120ºC)
2.2 Input Data
Nominal Pipe Size
NPS =
Pipe Outside Diameter
D=
219.10
8
mm
Internal Design gage Pressure
Pi =
43.4
barg
From Process Data
Maximum Operating Temperature
T2,MAX =
84
ºC
From Process Data
Ref. (1) Para. 402.5.1
Minimum Operating Temperature
T2,MIN =
0
ºC
From Process Data
Ref. (1) Para. 402.5.1
Installation Temperature
T1 =
21
ºC
From Process Data
Design Factor
F=
0.6
Corrosion Allowance
Ca =
Water Density
ρwater
External Force Axial Component (if any)
Fx =
3
=
1000
0
in
mm
3
kg/m
N
Fatigue factor
f=
2⁄3Sy at the lower of the installed or minimum operating temperature
Scold
276.67
MPa
2⁄3Sy at the higher of the installed or maximum operating temperature
Shot
276.67
MPa
4148-DGTYP-7-17-0001
1
Rev.C
Note (2)
Attachment - Wall Thickness Calculation - Stress Check
3.0 EQUATIONS
Equation
Unit
Eq. No.
[Mpa]
(1)
Notes
3.1 Stresss
3.1.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL = F.E.SY
Max Allowable Expansion Stress
SE,ALL = f[1.25(Scold+Shot)-SL]
[Mpa]
(2)
Ref. (1) Para 403.3.2
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL = 80%.SY
[Mpa]
(3)
Ref. (1) Table 403.3.1-1
Hoop Stress
SH = Pi.D / 20.tmin
[Mpa]
(6)
Longitudinal Stress due to Internal Pressure
SL,P =
[Mpa]
(7)
Thermal Expansion Stress: Case 1
ST1=
Es.α.(ΔTCase1)
[Mpa]
(8)
Thermal Expansion Stress: Case 2
ST2=
Es.α.(ΔTCase2)
[Mpa]
(9)
Longitudinal Stress due to Axial Loading
Sx = Fx / A
[Mpa]
(10)
Bending Stress (Tension)
SBT = iM / Z
[Mpa]
(11)
Bending Stress (Compression)
SBC= -iM / Z
[Mpa]
(12)
Longitudinal Stress (Sustained Loads): Case 1
SL1=ST1 + SL,P + SBT + Sx
[Mpa]
(13)
Ref. (1) Para 402.6.2
Longitudinal Stress (Sustained Loads): Case 2
SL2=ST1 + SL,P + SBC + Sx
[Mpa]
(14)
Ref. (1) Para 402.6.2
Longitudinal Stress (Sustained Loads): Case 3
SL3=ST2 + SL,P + SBT + Sx
[Mpa]
(15)
Ref. (1) Para 402.6.2
Longitudinal Stress (Sustained Loads): Case 4
SL4=ST2 + SL,P + SBC + Sx
[Mpa]
(16)
Ref. (1) Para 402.6.2
Ref. (1) Table 403.3.1-1
3.1.2 Stresses
ν.SH
3.1.3 Ratios
Ratio to SMYS
SMYS % = SH / SY
[%]
(20)
Ratio of calculated to Allowable (Hoop)
%H = SH / SH,ALL
[%]
(21)
Ratio of calculated to Allowable (Longitudinal)
%L = SL / SL,ALL
[%]
(22)
3.2 Wall Thickness
Calculated wall thickness
t =Pi.D / 20.SH,ALL
[mm]
(25)
Ref. (1) Para 403.2.1
Calculated wall thickness with corrosion allowance
tn = t + Ca
[mm]
(26)
Ref. (1) Para 403.2.1
Selected wall thickness
ts > tn
[mm]
(27)
Ref. (2) Table 1
Minimum wall thickness
tmin = ts - Ca
[mm]
(28)
Din = D-2tmin
[mm]
(29)
3.3 Pipeline Properties
Internal Diameter of the Pipe
Pipe moment of Inertia
I=
4
π (D
-
Pipe section modulus
Z=2*I/D
Pipe Metal Cross Section Area
A=
2
π (D
4
Din )
/64
2
- Din ) / 4
4
[m ]
(30)
3
[cm ]
(31)
[mm ]
2
(32)
3.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1= T1 - T2,MAX
[ºC]
(33)
Ref (1) Para 402.6.1
Temperature Difference: Case 2
ΔTCase2= T1 - T2,MIN
[ºC]
(34)
Ref (1) Para 402.6.1
[N.m]
(35)
[-]
(43)
3.5 Bending Moment
Bending Moment
M=Es.I/R
3.7 Stress Intensification Factor
Stress Intensification Factor
4148-DGTYP-7-17-0001
i=1
Rev.C
Note (4)
Attachment - Wall Thickness Calculation - Stress Check
4.0 CALCULATIONS
4.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL =
249.00
MPa
[Eq. (1)]
Max Allowable Expansion Stress
SE,ALL =
359.67
MPa
[Eq. (2)]
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL =
332.00
MPa
[Eq. (3)]
4.2 Wall Thickness
Calculated wall thickness
t=
1.91
mm
[Eq. (25)]
Calculated wall thickness with corrosion allowance
tn =
4.91
mm
[Eq. (26)]
Selected wall thickness
ts =
5.56
mm
[Eq. (27)]
Minimum wall thickness
tmin =
2.56
mm
[Eq. (28)]
Check Acceptability:
If tn<ts, selected wall thickness is accepted
Accepted
Ref. (1) Para 403.2.1
4.2.1 D/t ratio for constructability and handing evaluation
D / ts =
39.41
Note (5)
4.3 Pipeline Properties
Internal Diameter
Din =
Pipe moment of Inertia
I=
0.000010
Pipe section modulus
Z=
93.19
cm
Pipe Metal Cross Section Area
A=
1741.52
mm
[Eq. (32)]
213.98
mm
[Eq. (29)]
4
[Eq. (30)]
m
3
[Eq. (31)]
2
4.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1=
-63
ºC
[Eq. (33)]
Temperature Difference: Case 2
ΔTCase2=
21
ºC
[Eq. (34)]
7.34E+03
N.m
[Eq. (35)]
4.5 Bending Moment
Bending Moment
M=
4.6 Pipeline Stresses
4.6.1 Hoop Stress
Hoop Stress
SH =
185.72
MPa
Ratio to SMYS
SMYS %=
44.75%
%
[Eq. (20)]
Ratio of calculated to Allowable (Hoop)
%H =
74.59%
%
[Eq. (21)]
If SH<SH,ALL, selected wall thickness is acceptable
Check Acceptability:
[Eq. (6)]
Accepted
Ref. (1) Table 403.3.1-1
4.6.2 Longitudinal Stress
Thermal Expansion Stress: Case 1
ST1=
-149.63
MPa
[Eq. (8)]
Thermal Expansion Stress: Case 2
ST2=
49.88
MPa
[Eq. (9)]
Check Acceptability:
If (ST1, ST2)<SE,ALL, selected wall thickness is acceptable
Accepted
Ref. (1) Table 403.3.1-1
Longitudinal Stress due to Internal Pressure
SL,P =
55.72
MPa
[Eq. (7)]
Bending Stress (Tension)
SBT =
78.77
MPa
[Eq. (11)]
Bending Stress (Compression)
SBC=
-78.77
MPa
[Eq. (12)]
Longitudinal Stress due to Axial Loading
Sx=
0.00
Mpa
[Eq. (10)]
Longitudinal Stress (Sustained Loads): Case 1
SL1=
-15.1
Mpa
[Eq. (13)]
Ratio of calculated to Allowable (Longitudinal)
%L1 =
4.56%
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 2
SL2=
-172.7
Mpa
[Eq. (14)]
Ratio of calculated to Allowable (Longitudinal)
%L2 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 3
SL3=
Mpa
[Eq. (15)]
Ratio of calculated to Allowable (Longitudinal)
%L3 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 4
SL4=
Mpa
[Eq. (16)]
Ratio of calculated to Allowable (Longitudinal)
%L4 =
%
[Eq. (22)]
(1) Four cases of evaluation
52.01%
184.4
55.53%
26.8
8.08%
Check Acceptability:
If all ǀSLǀ<SL,ALL, selected wall thickness is acceptable
4148-DGTYP-7-17-0001
Rev.C
Accepted
Ref. (1) Table 403.3.1-1
Attachment - Wall Thickness Calculation - Stress Check
5.0 RESULTS SUMMARY
5.1 Results
5.1.1 Wall Thickness
Calculated Wall Thickness
Selected Wall Thickness
D to t Ratio
t=
1.91
mm
ts =
5.56
mm
D/t=
39.41
5.1.2 Calculated Stress Values
Max
Ratio of calculated to
Stress
Unit
Hoop (SH)
Mpa
249.00
185.72
74.59%
OK
Mpa
359.67
-149.63
41.60%
OK
Mpa
332.00
-172.7
52.01%
OK
Allowable
Calculated Value
allowable
Check
Thermal Expansion
(SE)
Worst Case Scenario
Longitudinal (SL)
Worst Case Scenario
OVERALL CHECK OF WALL THICKNESS
5.2 Notes
(1) For SI units, the calculated value shall be rounded to the nearest 5 MPa.
(2) Not Applicable for A/G Pipeline
(3) Applied for sustained loads
(4) Stress intensification factor equals 1 for straight pipe (See Ref. (1) Paragraph 402.6.2)
(5) Minimum wall thickness of pipe shall not be less than 4.8mm
4148-DGTYP-7-17-0001
Rev.C
ACCEPTED
Attachment - Wall Thickness Calculation - Stress Check
WALL THICKNESS CALCULATION SHEET- STRESS CHECK AS PER ASME B31.4
PROJECT:
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN DUKHAN FIELDS (2019-2022) - PART B
LOCATION: DUKHAN, QATAR
SYSTEM DESCRIPTION: RECYCLE WELL FLOWLINE / DF = 0.6
PIPE WALL THICKNESS CALCULATION TO ASME B31.4 (UNRESTRAINED)
1.0 INTRODUCTION
1.1 Description
This Excel sheet completes the wall thickness calculation for pipeline system in line with the design requirements outlined within the ASME B31.4. The sheet determines the required wall thickness for
pressure containment and stress requirements.
1.2 Codes
(1) ASME B31.4
(2) API 5L
(3) ASME B36.10
1.3 Assumptions
(1) This Excel sheet is currently set up for CARBON STEEL only.
(2) This Calculation is applicable for Above Ground, unrestrained pipelines only.
(3) Design temperature -29ºC<T<120ºC
(4) Compressive stress is a negative value
2.0 DESIGN DATA SUMMARY
2.1 Pipeline Data
Product / Liquid Type
Recycle Well Flowline
Selected Pipe Material
API 5L
X60
Grade
Specified Minimum Yield Strength
SMYS =
415.00
MPa
Ref. API 5L Table-7
Modulus of Elasticity of steel
Es =
203000
MPa
Ref. (3) Table C-1 (SI)
Poisson's ratio
v=
Weld Joint Factor
E=
1
Coefficient of Thermal Expansion
α=
0.0000117
0.30
Note (1)
Ref. (1) Para 402.2.3
Ref. (1) Table 403.2.1-1
◦
mm/mm. C
Ref. (1) Para 402.2.1 (Valid up to 120ºC)
2.2 Input Data
Nominal Pipe Size
NPS =
Pipe Outside Diameter
D=
219.10
8
mm
Internal Design gage Pressure
Pi =
16.9
barg
From Process Data
Maximum Operating Temperature
T2,MAX =
84
ºC
From Process Data
Ref. (1) Para. 402.5.1
Minimum Operating Temperature
T2,MIN =
0
ºC
From Process Data
Ref. (1) Para. 402.5.1
Installation Temperature
T1 =
21
ºC
From Process Data
Design Factor
F=
0.6
Corrosion Allowance
Ca =
Water Density
ρwater
External Force Axial Component (if any)
Fx =
3
=
1000
0
in
mm
3
kg/m
N
Fatigue factor
f=
2⁄3Sy at the lower of the installed or minimum operating temperature
Scold
276.67
MPa
2⁄3Sy at the higher of the installed or maximum operating temperature
Shot
276.67
MPa
4148-DGTYP-7-17-0001
1
Rev.C
Note (2)
Attachment - Wall Thickness Calculation - Stress Check
3.0 EQUATIONS
Equation
Unit
Eq. No.
[Mpa]
(1)
Notes
3.1 Stresss
3.1.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL = F.E.SY
Max Allowable Expansion Stress
SE,ALL = f[1.25(Scold+Shot)-SL]
[Mpa]
(2)
Ref. (1) Para 403.3.2
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL = 80%.SY
[Mpa]
(3)
Ref. (1) Table 403.3.1-1
Hoop Stress
SH = Pi.D / 20.tmin
[Mpa]
(6)
Longitudinal Stress due to Internal Pressure
SL,P =
[Mpa]
(7)
Thermal Expansion Stress: Case 1
ST1=
Es.α.(ΔTCase1)
[Mpa]
(8)
Thermal Expansion Stress: Case 2
ST2=
Es.α.(ΔTCase2)
[Mpa]
(9)
Longitudinal Stress due to Axial Loading
Sx = Fx / A
[Mpa]
(10)
Bending Stress (Tension)
SBT = iM / Z
[Mpa]
(11)
Bending Stress (Compression)
SBC= -iM / Z
[Mpa]
(12)
Longitudinal Stress (Sustained Loads): Case 1
SL1=ST1 + SL,P + SBT + Sx
[Mpa]
(13)
Ref. (1) Para 402.6.2
Longitudinal Stress (Sustained Loads): Case 2
SL2=ST1 + SL,P + SBC + Sx
[Mpa]
(14)
Ref. (1) Para 402.6.2
Longitudinal Stress (Sustained Loads): Case 3
SL3=ST2 + SL,P + SBT + Sx
[Mpa]
(15)
Ref. (1) Para 402.6.2
Longitudinal Stress (Sustained Loads): Case 4
SL4=ST2 + SL,P + SBC + Sx
[Mpa]
(16)
Ref. (1) Para 402.6.2
Ref. (1) Table 403.3.1-1
3.1.2 Stresses
ν.SH
3.1.3 Ratios
Ratio to SMYS
SMYS % = SH / SY
[%]
(20)
Ratio of calculated to Allowable (Hoop)
%H = SH / SH,ALL
[%]
(21)
Ratio of calculated to Allowable (Longitudinal)
%L = SL / SL,ALL
[%]
(22)
3.2 Wall Thickness
Calculated wall thickness
t =Pi.D / 20.SH,ALL
[mm]
(25)
Ref. (1) Para 403.2.1
Calculated wall thickness with corrosion allowance
tn = t + Ca
[mm]
(26)
Ref. (1) Para 403.2.1
Selected wall thickness
ts > tn
[mm]
(27)
Ref. (2) Table 1
Minimum wall thickness
tmin = ts - Ca
[mm]
(28)
Din = D-2tmin
[mm]
(29)
3.3 Pipeline Properties
Internal Diameter of the Pipe
Pipe moment of Inertia
I=
4
π (D
-
Pipe section modulus
Z=2*I/D
Pipe Metal Cross Section Area
A=
2
π (D
4
Din )
/64
2
- Din ) / 4
4
[m ]
(30)
3
[cm ]
(31)
[mm ]
2
(32)
3.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1= T1 - T2,MAX
[ºC]
(33)
Ref (1) Para 402.6.1
Temperature Difference: Case 2
ΔTCase2= T1 - T2,MIN
[ºC]
(34)
Ref (1) Para 402.6.1
[N.m]
(35)
[-]
(43)
3.5 Bending Moment
Bending Moment
M=Es.I/R
3.7 Stress Intensification Factor
Stress Intensification Factor
4148-DGTYP-7-17-0001
i=1
Rev.C
Note (4)
Attachment - Wall Thickness Calculation - Stress Check
4.0 CALCULATIONS
4.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL =
249.00
MPa
[Eq. (1)]
Max Allowable Expansion Stress
SE,ALL =
359.67
MPa
[Eq. (2)]
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL =
332.00
MPa
[Eq. (3)]
4.2 Wall Thickness
Calculated wall thickness
t=
0.74
mm
[Eq. (25)]
Calculated wall thickness with corrosion allowance
tn =
3.74
mm
[Eq. (26)]
Selected wall thickness
ts =
4.78
mm
[Eq. (27)]
Minimum wall thickness
tmin =
1.78
mm
[Eq. (28)]
Check Acceptability:
If tn<ts, selected wall thickness is accepted
Accepted
Ref. (1) Para 403.2.1
4.2.1 D/t ratio for constructability and handing evaluation
D / ts =
45.84
Note (5)
4.3 Pipeline Properties
Internal Diameter
Din =
Pipe moment of Inertia
I=
0.000007
Pipe section modulus
Z=
65.49
cm
Pipe Metal Cross Section Area
A=
1215.26
mm
[Eq. (32)]
215.54
mm
[Eq. (29)]
4
[Eq. (30)]
m
3
[Eq. (31)]
2
4.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1=
-63
ºC
[Eq. (33)]
Temperature Difference: Case 2
ΔTCase2=
21
ºC
[Eq. (34)]
5.16E+03
N.m
[Eq. (35)]
4.5 Bending Moment
Bending Moment
M=
4.6 Pipeline Stresses
4.6.1 Hoop Stress
Hoop Stress
SH =
104.01
MPa
Ratio to SMYS
SMYS %=
25.06%
%
[Eq. (20)]
Ratio of calculated to Allowable (Hoop)
%H =
41.77%
%
[Eq. (21)]
If SH<SH,ALL, selected wall thickness is acceptable
Check Acceptability:
[Eq. (6)]
Accepted
Ref. (1) Table 403.3.1-1
4.6.2 Longitudinal Stress
Thermal Expansion Stress: Case 1
ST1=
-149.63
MPa
[Eq. (8)]
Thermal Expansion Stress: Case 2
ST2=
49.88
MPa
[Eq. (9)]
Check Acceptability:
If (ST1, ST2)<SE,ALL, selected wall thickness is acceptable
Accepted
Ref. (1) Table 403.3.1-1
Longitudinal Stress due to Internal Pressure
SL,P =
31.20
MPa
[Eq. (7)]
Bending Stress (Tension)
SBT =
78.77
MPa
[Eq. (11)]
Bending Stress (Compression)
SBC=
-78.77
MPa
[Eq. (12)]
Longitudinal Stress due to Axial Loading
Sx=
0.00
Mpa
[Eq. (10)]
Longitudinal Stress (Sustained Loads): Case 1
SL1=
-39.7
Mpa
[Eq. (13)]
Ratio of calculated to Allowable (Longitudinal)
%L1 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 2
SL2=
Mpa
[Eq. (14)]
Ratio of calculated to Allowable (Longitudinal)
%L2 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 3
SL3=
Mpa
[Eq. (15)]
Ratio of calculated to Allowable (Longitudinal)
%L3 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 4
SL4=
Mpa
[Eq. (16)]
Ratio of calculated to Allowable (Longitudinal)
%L4 =
%
[Eq. (22)]
(1) Four cases of evaluation
11.95%
-197.2
59.40%
159.8
48.15%
2.3
0.70%
Check Acceptability:
If all ǀSLǀ<SL,ALL, selected wall thickness is acceptable
4148-DGTYP-7-17-0001
Rev.C
Accepted
Ref. (1) Table 403.3.1-1
Attachment - Wall Thickness Calculation - Stress Check
5.0 RESULTS SUMMARY
5.1 Results
5.1.1 Wall Thickness
Calculated Wall Thickness
Selected Wall Thickness
D to t Ratio
t=
0.74
mm
ts =
4.78
mm
D/t=
45.84
5.1.2 Calculated Stress Values
Max
Ratio of calculated to
Stress
Unit
Hoop (SH)
Mpa
249.00
104.01
41.77%
OK
Mpa
359.67
-149.63
41.60%
OK
Mpa
332.00
-197.2
59.40%
OK
Allowable
Calculated Value
allowable
Check
Thermal Expansion
(SE)
Worst Case Scenario
Longitudinal (SL)
Worst Case Scenario
OVERALL CHECK OF WALL THICKNESS
5.2 Notes
(1) For SI units, the calculated value shall be rounded to the nearest 5 MPa.
(2) Not Applicable for A/G Pipeline
(3) Applied for sustained loads
(4) Stress intensification factor equals 1 for straight pipe (See Ref. (1) Paragraph 402.6.2)
(5) Minimum wall thickness of pipe shall not be less than 4.8mm
4148-DGTYP-7-17-0001
Rev.C
ACCEPTED
PIPELINE DESIGN REPORT
5.3
Doc No.
4148-DGTYP-7-17-0001
Rev.:
Date:
Page
C
12/10/2021
24 of 26
Attachment 3: Results for Wall Thickness / Thinning Calculations as per ASME B31.8
CONTRACT NO: 4121 / GC191008B0
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN
PROJECT TITLE:
DUKHAN FIELDS (2019-2022) - PART B
Design Code
ASME B31.8
LOCATION: Dukhan Fields
3" Gas lift flowline
API 5L X65
MATERIAL:
UNIT
1
2
Design Pressure
P
Design Temperature
Tmax
Tmin
3
4
5
Design Factor
F
6
SMYS
S
Pipeline Design Factor = 0.72, used for Offplot area (Not Crossings ,
bar(g)
Not inside station)
142.58
kPa(g)
14258
degC
84
degC
0
0.72
7
PSI
65,000
MPa
448
8
Long. Joint Quality Factor
E
1
Refer Table 841.1.7-1 (API5L SMLS)
9
Temp. Derating Factor
T
1
Refer Table 841.1.8-1 (Temp Less than 121degC)
10
Pipe Bend Radius
R0
5D
11
Pipe Bending Inner Radius
R
4.5D
12
Pipe Thinning Ratio
n = R/D
12
Pipe Thinning Percentage
TP =(50/(n+1))
%
9.09
13
Pipe Thinning Percentage
Round up
%
10
14
Corrosion Allowance
CA
mm
3
4.5
(calculated)
(Used)
15
16
17
-
tcal / OD = Z
0.02209
P / 2*1000(SFET)
20
Calculated
21
SIZE
OD
Thickness
(without CA)
tcal= ODxZ
Required Minimum
Thickness
tcal+CA
Straight Pipe
Thickness Selected
(tsel1)
Bend
Thickness
tsel2
Selected
After
(tsel2)
Thininig
OD/tsel1
(<96)
tmin<tsel1
tmin<tsel2
22
(in)
(mm)
(mm)
(mm)
(mm)
(mm)
(mm)
Check
Check
Check
23
3
88.90
1.96
4.96
5.49
6.20
5.58
SAFE
SAFE
SAFE
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-3
CONTRACT NO: 4121 / GC191008B0
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN
PROJECT TITLE:
DUKHAN FIELDS (2019-2022) - PART B
Design Code
ASME B31.8
LOCATION: Dukhan Fields
3" Gas lift flowline
API 5L X60
MATERIAL:
UNIT
1
2
Design Pressure
P
Design Temperature
Tmax
Tmin
3
4
5
Design Factor
F
6
SMYS
S
Pipeline Design Factor = 0.6, used for Non-Culverted Crossings and
bar(g)
inside station.
142.58
kPa(g)
14258
degC
84
degC
0
0.6
7
PSI
65,000
MPa
448
8
Long. Joint Quality Factor
E
1
Refer Table 841.1.7-1 (API5L SMLS)
9
Temp. Derating Factor
T
1
Refer Table 841.1.8-1 (Temp Less than 121degC)
10
Pipe Bend Radius
R0
5D
11
Pipe Bending Inner Radius
R
4.5D
12
Pipe Thinning Ratio
n = R/D
12
Pipe Thinning Percentage
TP =(50/(n+1))
%
9.09
13
Pipe Thinning Percentage
Round up
%
10
14
Corrosion Allowance
CA
mm
3
4.5
(calculated)
(Used)
15
16
17
-
tcal / OD = Z
0.02651
P / 2*1000(SFET)
20
Calculated
21
SIZE
OD
Thickness
(without CA)
tcal= ODxZ
Required Minimum
Thickness
tcal+CA
Straight Pipe
Thickness Selected
(tsel1)
Bend
Thickness
tsel2
Selected
After
(tsel2)
Thininig
OD/tsel1
(<96)
tmin<tsel1
tmin<tsel2
22
(in)
(mm)
(mm)
(mm)
(mm)
(mm)
(mm)
Check
Check
Check
23
3
88.90
2.36
5.36
5.49
6.20
5.58
SAFE
SAFE
SAFE
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-3
CONTRACT NO: 4121 / GC191008B0
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN
PROJECT TITLE:
DUKHAN FIELDS (2019-2022) - PART B
Design Code
ASME B31.8
LOCATION: Dukhan Fields
6" Khuff Production flowline
API 5L X65
MATERIAL:
UNIT
1
2
Design Pressure
P
Design Temperature
Tmax
Tmin
3
4
5
Design Factor
F
6
SMYS
S
Pipeline Design Factor = 0.72, used for Offplot area (Not Crossings ,
bar(g)
Not inside station)
359
kPa(g)
35900
degC
84
degC
0
0.72
7
PSI
65,000
MPa
448
8
Long. Joint Quality Factor
E
1
Refer Table 841.1.7-1 (API5L SMLS)
9
Temp. Derating Factor
T
1
Refer Table 841.1.8-1 (Temp Less than 121degC)
10
Pipe Bend Radius
R0
5D
11
Pipe Bending Inner Radius
R
4.5D
12
Pipe Thinning Ratio
n = R/D
12
Pipe Thinning Percentage
TP =(50/(n+1))
%
9.09
13
Pipe Thinning Percentage
Round up
%
10
14
Corrosion Allowance
CA
mm
3
4.5
(calculated)
(Used)
15
16
17
-
tcal / OD = Z
0.05561
P / 2*1000(SFET)
20
Calculated
21
SIZE
OD
Thickness
(without CA)
tcal= ODxZ
Required Minimum
Thickness
tcal+CA
Straight Pipe
Thickness Selected
(tsel1)
Bend
Thickness
tsel2
Selected
After
(tsel2)
Thininig
OD/tsel1
(<96)
tmin<tsel1
tmin<tsel2
22
(in)
(mm)
(mm)
(mm)
(mm)
(mm)
(mm)
Check
Check
Check
23
6
168.30
9.36
12.36
14.27
15.90
14.31
SAFE
SAFE
SAFE
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-3
CONTRACT NO: 4121 / GC191008B0
PROJECT TITLE:
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN DUKHAN
Design Code
ASME B31.8
LOCATION: Stations-S, S1,MS1,MS2,MS3 and MS4
6" Khuff Production flowline
API 5L X65
MATERIAL:
UNIT
1
2
Design Pressure
P
Design Temperature
Tmax
Tmin
3
4
5
Design Factor
F
6
SMYS
S
Pipeline Design Factor = 0.6, used for Non-Culverted Crossings and
bar(g)
inside station.
359
kPa(g)
35900
degC
84
degC
0
0.6
7
PSI
65,000
MPa
448
8
Long. Joint Quality Factor
E
1
Refer Table 841.1.7-1 (API5L SMLS)
9
Temp. Derating Factor
T
1
Refer Table 841.1.8-1 (Temp Less than 121degC)
10
Pipe Bend Radius
R0
5D
11
Pipe Bending Inner Radius
R
4.5D
12
Pipe Thinning Ratio
n = R/D
12
Pipe Thinning Percentage
TP =(50/(n+1))
%
9.09
13
Pipe Thinning Percentage
Round up
%
10
14
Corrosion Allowance
CA
mm
3
4.5
(calculated)
(Used)
15
16
17
-
tcal / OD = Z
0.06674
P / 2*1000(SFET)
20
Calculated
21
SIZE
OD
Thickness
(without CA)
tcal= ODxZ
Required Minimum
Thickness
tcal+CA
Straight Pipe
Thickness Selected
(tsel1)
Bend
Thickness
tsel2
Selected
After
(tsel2)
Thininig
OD/tsel1
(<96)
tmin<tsel1
tmin<tsel2
22
(in)
(mm)
(mm)
(mm)
(mm)
(mm)
(mm)
Check
Check
Check
23
6
168.30
11.23
14.23
14.27
15.90
14.31
SAFE
SAFE
SAFE
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-3
CONTRACT NO: 4121 / GC191008B0
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN
PROJECT TITLE:
DUKHAN FIELDS (2019-2022) - PART B
Design Code
ASME B31.8
LOCATION: Dukhan Fields
6" Khuff injection flowline
API 5L X65
MATERIAL:
UNIT
1
2
Design Pressure
P
Design Temperature
Tmax
Tmin
3
4
5
Design Factor
F
6
SMYS
S
Pipeline Design Factor = 0.72, used for Offplot area (Not Crossings ,
bar(g)
Not inside station)
368.6
kPa(g)
36860
degC
84
degC
0
0.72
7
PSI
65,000
MPa
448
8
Long. Joint Quality Factor
E
1
Refer Table 841.1.7-1 (API5L SMLS)
9
Temp. Derating Factor
T
1
Refer Table 841.1.8-1 (Temp Less than 121degC)
10
Pipe Bend Radius
R0
5D
11
Pipe Bending Inner Radius
R
4.5D
12
Pipe Thinning Ratio
n = R/D
12
Pipe Thinning Percentage
TP =(50/(n+1))
%
9.09
13
Pipe Thinning Percentage
Round up
%
10
14
Corrosion Allowance
CA
mm
3
4.5
(calculated)
(Used)
15
16
17
-
tcal / OD = Z
0.05710
P / 2*1000(SFET)
20
Calculated
21
SIZE
OD
Thickness
(without CA)
tcal= ODxZ
Required Minimum
Thickness
tcal+CA
Straight Pipe
Thickness Selected
(tsel1)
Bend
Thickness
tsel2
Selected
After
(tsel2)
Thininig
OD/tsel1
(<96)
tmin<tsel1
tmin<tsel2
22
(in)
(mm)
(mm)
(mm)
(mm)
(mm)
(mm)
Check
Check
Check
23
6
168.30
9.61
12.61
14.27
16.50
14.85
SAFE
SAFE
SAFE
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-3
CONTRACT NO: 4121 / GC191008B0
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN
PROJECT TITLE:
DUKHAN FIELDS (2019-2022) - PART B
Design Code
ASME B31.8
LOCATION: Dukhan Fields
6" Khuff injection flowline
API 5L X65
MATERIAL:
UNIT
1
2
Design Pressure
P
Design Temperature
Tmax
Tmin
3
4
5
Design Factor
F
6
SMYS
S
Pipeline Design Factor = 0.6, used for Non-Culverted Crossings and
bar(g)
inside station.
368.6
kPa(g)
36860
degC
84
degC
0
0.6
7
PSI
65,000
MPa
448
8
Long. Joint Quality Factor
E
1
Refer Table 841.1.7-1 (API5L SMLS)
9
Temp. Derating Factor
T
1
Refer Table 841.1.8-1 (Temp Less than 121degC)
10
Pipe Bend Radius
R0
5D
11
Pipe Bending Inner Radius
R
4.5D
12
Pipe Thinning Ratio
n = R/D
12
Pipe Thinning Percentage
TP =(50/(n+1))
%
9.09
13
Pipe Thinning Percentage
Round up
%
10
14
Corrosion Allowance
CA
mm
3
4.5
(calculated)
(Used)
15
16
17
-
tcal / OD = Z
0.06852
P / 2*1000(SFET)
20
Calculated
21
SIZE
OD
Thickness
(without CA)
tcal= ODxZ
Required Minimum
Thickness
tcal+CA
Straight Pipe
Thickness Selected
(tsel1)
Bend
Thickness
tsel2
Selected
After
(tsel2)
Thininig
OD/tsel1
(<96)
tmin<tsel1
tmin<tsel2
22
(in)
(mm)
(mm)
(mm)
(mm)
(mm)
(mm)
Check
Check
Check
23
6
168.30
11.53
14.53
16.50
16.50
14.85
SAFE
SAFE
SAFE
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-3
CONTRACT NO: 4121 / GC191008B0
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN
PROJECT TITLE:
DUKHAN FIELDS (2019-2022) - PART B
Design Code
ASME B31.8
LOCATION: Dukhan Fields
8" RG production flowline
API 5L X52
MATERIAL:
UNIT
1
2
Design Pressure
P
Design Temperature
Tmax
Tmin
3
4
5
Design Factor
F
6
SMYS
S
Pipeline Design Factor = 0.72, used for Offplot area (Not Crossings ,
bar(g)
Not inside station)
179.3
kPa(g)
17930
degC
84
degC
0
0.72
7
PSI
52,000
MPa
359
8
Long. Joint Quality Factor
E
1
Refer Table 841.1.7-1 (API5L SMLS)
9
Temp. Derating Factor
T
1
Refer Table 841.1.8-1 (Temp Less than 121degC)
10
Pipe Bend Radius
R0
5D
11
Pipe Bending Inner Radius
R
4.5D
12
Pipe Thinning Ratio
n = R/D
12
Pipe Thinning Percentage
TP =(50/(n+1))
%
9.09
13
Pipe Thinning Percentage
Round up
%
10
14
Corrosion Allowance
CA
mm
3
4.5
(calculated)
(Used)
15
16
17
-
tcal / OD = Z
0.03472
P / 2*1000(SFET)
20
Calculated
21
SIZE
OD
Thickness
(without CA)
tcal= ODxZ
Required Minimum
Thickness
tcal+CA
Straight Pipe
Thickness Selected
(tsel1)
Bend
Thickness
tsel2
Selected
After
(tsel2)
Thininig
OD/tsel1
(<96)
tmin<tsel1
tmin<tsel2
22
(in)
(mm)
(mm)
(mm)
(mm)
(mm)
(mm)
Check
Check
Check
23
8
219.08
7.61
10.61
12.70
13.50
12.15
SAFE
SAFE
SAFE
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-3
CONTRACT NO: 4121 / GC191008B0
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN
PROJECT TITLE:
DUKHAN FIELDS (2019-2022) - PART B
Design Code
ASME B31.8
LOCATION: Dukhan Fields
8" RG production flowline
API 5L X52
MATERIAL:
UNIT
1
2
Design Pressure
P
Design Temperature
Tmax
Tmin
3
4
5
Design Factor
F
6
SMYS
S
Pipeline Design Factor = 0.6, used for Non-Culverted Crossings and
bar(g)
inside station.
179.3
kPa(g)
17930
degC
84
degC
0
0.6
7
PSI
52,000
MPa
359
8
Long. Joint Quality Factor
E
1
Refer Table 841.1.7-1 (API5L SMLS)
9
Temp. Derating Factor
T
1
Refer Table 841.1.8-1 (Temp Less than 121degC)
10
Pipe Bend Radius
R0
5D
11
Pipe Bending Inner Radius
R
4.5D
12
Pipe Thinning Ratio
n = R/D
12
Pipe Thinning Percentage
TP =(50/(n+1))
%
9.09
13
Pipe Thinning Percentage
Round up
%
10
14
Corrosion Allowance
CA
mm
3
4.5
(calculated)
(Used)
15
16
17
-
tcal / OD = Z
0.04166
P / 2*1000(SFET)
20
Calculated
21
SIZE
OD
Thickness
(without CA)
tcal= ODxZ
Required Minimum
Thickness
tcal+CA
Straight Pipe
Thickness Selected
(tsel1)
Bend
Thickness
tsel2
Selected
After
(tsel2)
Thininig
OD/tsel1
(<96)
tmin<tsel1
tmin<tsel2
22
(in)
(mm)
(mm)
(mm)
(mm)
(mm)
(mm)
Check
Check
Check
23
8
219.08
9.13
12.13
12.70
13.50
12.15
SAFE
SAFE
SAFE
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-3
CONTRACT NO: 4121 / GC191008B0
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN
PROJECT TITLE:
DUKHAN FIELDS (2019-2022) - PART B
Design Code
ASME B31.8
LOCATION: Dukhan Fields
6" RG production flowline
API 5L X60
MATERIAL:
UNIT
1
2
Design Pressure
P
Design Temperature
Tmax
Tmin
3
4
5
Design Factor
F
6
SMYS
S
Pipeline Design Factor = 0.72, used for Offplot area (Not Crossings ,
bar(g)
Not inside station)
240
kPa(g)
24000
degC
84
degC
0
0.72
7
PSI
60,000
MPa
414
8
Long. Joint Quality Factor
E
1
Refer Table 841.1.7-1 (API5L SMLS)
9
Temp. Derating Factor
T
1
Refer Table 841.1.8-1 (Temp Less than 121degC)
10
Pipe Bend Radius
R0
5D
11
Pipe Bending Inner Radius
R
4.5D
12
Pipe Thinning Ratio
n = R/D
12
Pipe Thinning Percentage
TP =(50/(n+1))
%
9.09
13
Pipe Thinning Percentage
Round up
%
10
14
Corrosion Allowance
CA
mm
3
4.5
(calculated)
(Used)
15
16
17
-
tcal / OD = Z
0.04028
P / 2*1000(SFET)
20
Calculated
21
SIZE
OD
Thickness
(without CA)
tcal= ODxZ
Required Minimum
Thickness
tcal+CA
Straight Pipe
Thickness Selected
(tsel1)
Bend
Thickness
tsel2
Selected
After
(tsel2)
Thininig
OD/tsel1
(<96)
tmin<tsel1
tmin<tsel2
(mm)
(mm)
(mm)
(mm)
Check
Check
Check
6.78
9.78
10.97
12.70
11.43
SAFE
SAFE
SAFE
8.82
11.82
14.60
14.60
13.14
SAFE
SAFE
SAFE
11.00
14.00
16.50
15.60
14.04
SAFE
SAFE
SAFE
22
(in)
(mm)
(mm)
23
6
168.30
24
8
219.08
25
10
273.01
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-3
CONTRACT NO: 4121 / GC191008B0
EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN
PROJECT TITLE:
DUKHAN FIELDS (2019-2022) - PART B
Design Code
ASME B31.8
LOCATION: Dukhan Fields
6" RG production flowline
API 5L X60
MATERIAL:
UNIT
1
2
Design Pressure
P
Design Temperature
Tmax
Tmin
3
4
5
Design Factor
F
6
SMYS
S
Pipeline Design Factor = 0.6, used for Non-Culverted Crossings and
bar(g)
inside station.
240
kPa(g)
24000
degC
84
degC
0
0.6
7
PSI
60,000
MPa
414
8
Long. Joint Quality Factor
E
1
Refer Table 841.1.7-1 (API5L SMLS)
9
Temp. Derating Factor
T
1
Refer Table 841.1.8-1 (Temp Less than 121degC)
10
Pipe Bend Radius
R0
5D
11
Pipe Bending Inner Radius
R
4.5D
12
Pipe Thinning Ratio
n = R/D
12
Pipe Thinning Percentage
TP =(50/(n+1))
%
9.09
13
Pipe Thinning Percentage
Round up
%
10
14
Corrosion Allowance
CA
mm
3
4.5
(calculated)
(Used)
15
16
17
-
tcal / OD = Z
0.04833
P / 2*1000(SFET)
20
Calculated
21
SIZE
OD
Thickness
(without CA)
tcal= ODxZ
Required Minimum
Thickness
tcal+CA
Straight Pipe
Thickness Selected
(tsel1)
Bend
Thickness
tsel2
Selected
After
(tsel2)
Thininig
OD/tsel1
(<96)
tmin<tsel1
tmin<tsel2
22
(in)
(mm)
(mm)
(mm)
(mm)
(mm)
(mm)
Check
Check
Check
23
6
168.30
8.13
11.13
12.70
12.70
11.43
SAFE
SAFE
SAFE
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-3
PIPELINE DESIGN REPORT
5.4
Doc No.
4148-DGTYP-7-17-0001
Rev.:
Date:
Page
C
12/10/2021
25 of 26
Attachment 4: Pipe Wall Thickness Stress Check as per ASME B31.8
Attachment - Wall Thickness Calculation - Stress Check
WALL THICKNESS CALCULATION SHEET- STRESS CHECK AS PER ASME B31.8
PROJECT: EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN DUKHANFIELDS (2019-2022) - PART B
LOCATION: : DUKHAN, QATAR
SYSTEM DESCRIPTION: GAS LIFT FLOWLINE / DF = 0.6
PIPE WALL THICKNESS CALCULATION TO ASME B31.8 (UNRESTRAINED)
1.0 INTRODUCTION
1.1 Description
This Excel sheet completes the wall thickness calculation for pipeline system in line with the design requirements outlined within the ASME B31.8. The sheet determines the required wall thickness for
pressure containment and stress requirements.
1.2 Codes
(1) ASME B31.8
(2) API 5L
(3) ASME B36.10
1.3 Assumptions
(1) This Excel sheet is currently set up for CARBON STEEL only.
(2) This Calculation is applicable for Above Ground, unrestrained pipelines only.
(3) Compressive stress is a negative value
(4) The temperature limit shall be -29ºC<T<232ºC as per ASME B31.8
2.0 DESIGN DATA SUMMARY
2.1 Pipeline Data
Product / Liquid Type
Gas lift Flowline
Selected Pipe Material
API 5L
Specified Minimum Yield Strength
SMYS =
450.00
MPa
Ref. API 5L Table-7
Specified Minimum Tensile Strength
SMTS
535.00
Mpa
Ref. API 5L Table-7
Modulus of Elasticity of steel
Es =
203000
MPa
Ref. (3) Table C-1 (SI)
Poisson's ratio
v=
0.30
Weld Joint Factor
E=
1
Temperature Derating Factor
T
1
Coefficient of Thermal Expansion
X65
0.0000117
α=
Grade
Ref. (1) Table 841.1.7-1
Ref Table 841.1.8-1
◦
mm/mm. C
Ref. (1) Para 832.2 (Valid up to 120ºC)
2.2 Input Data
Nominal Pipe Size
NPS =
Pipe Outside Diameter
D=
88.90
3
mm
Internal Design gage Pressure
Pi =
142.58
barg
Maximum Design Temperature
T2,MAX =
84
ºC
Minimum Design Temperature
T2,MIN =
0
ºC
Installation Temperature
T1 =
21
ºC
Design Factor
F=
0.6
Corrosion Allowance
Ca =
Water Density
rwater
3
External Force Axial Component (if any)
Fx =
0
Fatigue factor
f=
1
=
1000
in
mm
3
kg/m
N
0.33SuT at the minimum installed or operating temperature
Scold
176.55
MPa
0.33SuT at the maximum installed or operating temperature
Shot
176.55
MPa
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
Note (1)
Attachment - Wall Thickness Calculation - Stress Check
3.0 EQUATIONS
Equation
Unit
Eq. No.
Notes
Maximum Allowable Hoop Stress
SH,ALL = F.E.T.SY
[Mpa]
(1)
Ref. (1) Para. 841.1.1
Max Allowable Expansion Stress
SE,ALL = f[1.25(Scold+Shot)-SL]
[Mpa]
(2)
Ref. (1) Para. 833.8 (b)
Max Allowable Longitudinal Stress (See Note 2)
SL,ALL = 75%.SYT
[Mpa]
(3)
Ref. (1) Para. 833.6 (b)
Hoop Stress
SH = Pi.D / 20.tmin
[Mpa]
(6)
Ref. (1) Para. 805.2.3
Longitudinal Stress due to Internal Pressure
SL,P =
[Mpa]
(7)
Ref. (1) Para. 833.2 (a)
Expansion Stress
SE= ME/Z
[Mpa]
(8)
Ref. (1) Para. 833.8 (a)
Longitudinal Stress due to Axial Loading
Sx = Fx / A
[Mpa]
(10)
Ref. (1) Para. 833.2 (f)
Bending Stress (Tension)
SBT = iM / Z
[Mpa]
(11)
Ref. (1) Para. 833.2 (d)
Bending Stress (Compression)
SBC= -iM / Z
[Mpa]
(12)
Ref. (1) Para. 833.2 (d)
Longitudinal Stress (Sustained Loads): Case 1
SL1=ST1 + SL,P + SBT + Sx
[Mpa]
(13)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 2
SL2=ST1 + SL,P + SBC + Sx
[Mpa]
(14)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 3
SL3=ST2 + SL,P + SBT + Sx
[Mpa]
(15)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 4
SL4=ST2 + SL,P + SBC + Sx
[Mpa]
(16)
Ref. (1) Para. 833.3 (a)
3.1 Stresss
3.1.1 Maximum Allowable (due to Code)
3.1.2 Stresses
0.5.SH
3.1.3 Ratios
Ratio to SMYS
SMYS % = SH / SY
[%]
(20)
Ratio of calculated to Allowable (Hoop)
%H = SH / SH,ALL
[%]
(21)
Ratio of calculated to Allowable (Longitudinal)
%L = SL / SL,ALL
[%]
(22)
3.2 Wall Thickness
Calculated wall thickness
t =Pi.D / 20.SH,ALL
[mm]
(25)
Calculated wall thickness with corrosion allowance
tn = t + Ca
[mm]
(26)
Selected wall thickness
ts > tn
[mm]
(27)
Minimum wall thickness
tmin = ts - Ca
[mm]
(28)
[mm]
(29)
Ref. (1) Para. 841.1.1
Ref. (2) Table 1
3.3 Pipeline Properties
Internal Diameter of the Pipe
Din = D-2tmin
Pipe moment of Inertia
I=
Pipe section modulus
Z=2*I/D
Pipe Metal Cross Section Area
4
p (D
A=
4
- Din ) /64
2
p (D
-
2
Din )
/4
4
[m ]
(30)
3
[cm ]
(31)
2
[mm ]
(32)
3.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1= T1 - T2,MAX
[ºC]
(33)
Ref. (1) Para. 833.2 (c)
Temperature Difference: Case 2
ΔTCase2= T1 - T2,MIN
[ºC]
(34)
Ref. (1) Para. 833.2 (c)
[N.m]
(35)
[-]
(43)
3.5 Bending Moment
Bending Moment
M=Es.I/R
3.7 Stress Intensification Factor
Stress Intensification Factor
Doc. No.: 4148-DGTYP-7-17-0001
i=1
Attachment-4
Note (3)
Attachment - Wall Thickness Calculation - Stress Check
4.0 CALCULATIONS
4.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL =
270.00
MPa
[Eq. (1)]
Max Allowable Expansion Stress
SE,ALL =
103.88
MPa
[Eq. (2)]
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL =
337.50
MPa
[Eq. (3)]
4.2 Wall Thickness
Calculated wall thickness
t=
2.35
mm
[Eq. (25)]
Calculated wall thickness with corrosion allowance
tn =
5.35
mm
[Eq. (26)]
Selected wall thickness
ts =
5.49
mm
[Eq. (27)]
Minimum wall thickness
tmin =
2.49
mm
[Eq. (28)]
Check Acceptability:
If tn<ts, selected wall thickness is accepted
Accepted
4.2.1 D/t ratio for constructability and handing evaluation
D / ts =
16.19
Note (4)
4.3 Pipeline Properties
Internal Diameter
Din =
Pipe moment of Inertia
I=
0.000001
Pipe section modulus
Z=
14.20
cm
Pipe Metal Cross Section Area
A=
675.95
mm
[Eq. (32)]
83.92
mm
[Eq. (29)]
4
[Eq. (30)]
m
3
[Eq. (31)]
2
4.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1=
-63
ºC
[Eq. (33)]
Temperature Difference: Case 2
ΔTCase2=
21
ºC
[Eq. (34)]
6.42E+02
N.m
[Eq. (35)]
4.5 Bending Moment
Bending Moment
M=
4.6 Pipeline Stresses
4.6.1 Hoop Stress
Hoop Stress
SH =
254.53
MPa
Ratio to SMYS
SMYS %=
56.56%
%
[Eq. (20)]
Ratio of calculated to Allowable (Hoop)
%H =
94.27%
%
[Eq. (21)]
If SH<SH,ALL, selected wall thickness is acceptable
Check Acceptability:
[Eq. (6)]
Accepted
Ref. (1) Para.841.1.1
4.6.2 Expansion Stress
Expansion Stress
SE=
45.21
MPa
Check Acceptability:
If SE<SE.ALL, selected wall thickness is acceptable
[Eq. (8)]
Accepted
Longitudinal Stress due to Internal Pressure
SL,P =
76.36
MPa
[Eq. (7)]
Bending Stress (Tension)
SBT =
45.21
MPa
[Eq. (11)]
Bending Stress (Compression)
SBC=
-45.21
MPa
[Eq. (12)]
Longitudinal Stress due to Axial Loading
Sx=
0.00
Mpa
[Eq. (10)]
Longitudinal Stress (Sustained Loads): Case 1
SL1=
166.8
Mpa
[Eq. (13)]
Ratio of calculated to Allowable (Longitudinal)
%L1 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 2
SL2=
Mpa
[Eq. (14)]
Ratio of calculated to Allowable (Longitudinal)
%L2 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 3
SL3=
Mpa
[Eq. (15)]
Ratio of calculated to Allowable (Longitudinal)
%L3 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 4
SL4=
Mpa
[Eq. (16)]
Ratio of calculated to Allowable (Longitudinal)
%L4 =
%
[Eq. (22)]
(1) Four cases of evaluation
76.4
22.62%
121.6
36.02%
31.2
9.23%
Check Acceptability:
If all ǀSLǀ<SL,ALL, selected wall thickness is acceptable
Doc. No.: 4148-DGTYP-7-17-0001
49.41%
Attachment-4
Accepted
Ref. (1) Para. 833.3
Attachment - Wall Thickness Calculation - Stress Check
5.0 RESULTS SUMMARY
5.1 Results
5.1.1 Wall Thickness
Calculated Wall Thickness
Selected Wall Thickness
D to t Ratio
t=
2.35
mm
ts =
5.49
mm
D/t=
16.19
5.1.2 Calculated Stress Values
Max
Ratio of calculated to
Stress
Unit
Hoop (SH)
Mpa
270.00
254.53
94.27%
OK
Mpa
103.88
45.21
43.52%
OK
Mpa
337.50
31.2
9.23%
OK
Allowable
Calculated Value
allowable
Check
Thermal Expansion
(SE)
Worst Case Scenario
Longitudinal (SL)
Worst Case Scenario
OVERALL CHECK OF WALL THICKNESS
5.2 Notes
(1) Not Applicable for A/G Pipeline.
(2) Applied for sustained loads.
(3) Stress intensification factor equals 1 for straight pipe Table E-1 of ASME B31.8.
(4) Minimum wall thickness of pipe shall not be less than 4.8mm as per section 8.5 of QP standard QP STD-L017 Rv1.
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
ACCEPTED
Attachment - Wall Thickness Calculation - Stress Check
WALL THICKNESS CALCULATION SHEET- STRESS CHECK AS PER ASME B31.8
PROJECT: EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN DUKHANFIELDS (2019-2022) - PART B
LOCATION: : DUKHAN, QATAR
SYSTEM DESCRIPTION: KHUFF PRODUCTION FLOWLINE / DF = 0.6
PIPE WALL THICKNESS CALCULATION TO ASME B31.8 (UNRESTRAINED)
1.0 INTRODUCTION
1.1 Description
This Excel sheet completes the wall thickness calculation for pipeline system in line with the design requirements outlined within the ASME B31.8. The sheet determines the required wall thickness for
pressure containment and stress requirements.
1.2 Codes
(1) ASME B31.8
(2) API 5L
(3) ASME B36.10
1.3 Assumptions
(1) This Excel sheet is currently set up for CARBON STEEL only.
(2) This Calculation is applicable for Above Ground, unrestrained pipelines only.
(3) Compressive stress is a negative value
(4) The temperature limit shall be -29ºC<T<232ºC as per ASME B31.8
2.0 DESIGN DATA SUMMARY
2.1 Pipeline Data
Product / Liquid Type
Khuff Production Flowline
Selected Pipe Material
API 5L
Specified Minimum Yield Strength
SMYS =
450.00
MPa
Ref. API 5L Table-7
Specified Minimum Tensile Strength
SMTS
535.00
Mpa
Ref. API 5L Table-7
Modulus of Elasticity of steel
Es =
203000
MPa
Ref. (3) Table C-1 (SI)
Poisson's ratio
v=
Weld Joint Factor
E=
Temperature Derating Factor
T
Coefficient of Thermal Expansion
X65
Grade
0.30
1
Ref. (1) Table 841.1.7-1
0.97
0.0000117
α=
Ref Table 841.1.8-1
◦
mm/mm. C
Ref. (1) Para 832.2 (Valid up to 120ºC)
2.2 Input Data
Nominal Pipe Size
NPS =
Pipe Outside Diameter
D=
168.30
6
mm
Internal Design gage Pressure
Pi =
359
barg
Maximum Operating Temperature
T2,MAX =
150
ºC
Minimum Operating Temperature
T2,MIN =
-10
ºC
Installation Temperature
T1 =
21
ºC
Design Factor
F=
0.6
Corrosion Allowance
Ca =
Water Density
rwater
3
External Force Axial Component (if any)
Fx =
0
Fatigue factor
f=
1
=
1000
in
mm
3
kg/m
N
0.33SuT at the minimum installed or operating temperature
Scold
176.55
MPa
0.33SuT at the maximum installed or operating temperature
Shot
170.72
MPa
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
Note (1)
Attachment - Wall Thickness Calculation - Stress Check
3.0 EQUATIONS
Equation
Unit
Eq. No.
Notes
Maximum Allowable Hoop Stress
SH,ALL = F.E.T.SY
[Mpa]
(1)
Ref. (1) Para. 841.1.1
Max Allowable Expansion Stress
SE,ALL = f[1.25(Scold+Shot)-SL]
[Mpa]
(2)
Ref. (1) Para. 833.8 (b)
Max Allowable Longitudinal Stress (See Note 2)
SL,ALL = 75%.SYT
[Mpa]
(3)
Ref. (1) Para. 833.6 (b)
Hoop Stress
SH = Pi.D / 20.tmin
[Mpa]
(6)
Ref. (1) Para. 805.2.3
Longitudinal Stress due to Internal Pressure
SL,P =
[Mpa]
(7)
Ref. (1) Para. 833.2 (a)
Expansion Stress
SE= ME/Z
[Mpa]
(8)
Ref. (1) Para. 833.8 (a)
Longitudinal Stress due to Axial Loading
Sx = Fx / A
[Mpa]
(10)
Ref. (1) Para. 833.2 (f)
Bending Stress (Tension)
SBT = iM / Z
[Mpa]
(11)
Ref. (1) Para. 833.2 (d)
Bending Stress (Compression)
SBC= -iM / Z
[Mpa]
(12)
Ref. (1) Para. 833.2 (d)
Longitudinal Stress (Sustained Loads): Case 1
SL1=ST1 + SL,P + SBT + Sx
[Mpa]
(13)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 2
SL2=ST1 + SL,P + SBC + Sx
[Mpa]
(14)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 3
SL3=ST2 + SL,P + SBT + Sx
[Mpa]
(15)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 4
SL4=ST2 + SL,P + SBC + Sx
[Mpa]
(16)
Ref. (1) Para. 833.3 (a)
3.1 Stresss
3.1.1 Maximum Allowable (due to Code)
3.1.2 Stresses
0.5.SH
3.1.3 Ratios
Ratio to SMYS
SMYS % = SH / SY
[%]
(20)
Ratio of calculated to Allowable (Hoop)
%H = SH / SH,ALL
[%]
(21)
Ratio of calculated to Allowable (Longitudinal)
%L = SL / SL,ALL
[%]
(22)
3.2 Wall Thickness
Calculated wall thickness
t =Pi.D / 20.SH,ALL
[mm]
(25)
Calculated wall thickness with corrosion allowance
tn = t + Ca
[mm]
(26)
Selected wall thickness
ts > tn
[mm]
(27)
Minimum wall thickness
tmin = ts - Ca
[mm]
(28)
[mm]
(29)
Ref. (1) Para. 841.1.1
Ref. (2) Table 1
3.3 Pipeline Properties
Internal Diameter of the Pipe
Din = D-2tmin
Pipe moment of Inertia
I=
Pipe section modulus
Z=2*I/D
Pipe Metal Cross Section Area
4
p (D
A=
4
- Din ) /64
2
p (D
-
2
Din )
/4
4
[m ]
(30)
3
[cm ]
(31)
2
[mm ]
(32)
3.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1= T1 - T2,MAX
[ºC]
(33)
Ref. (1) Para. 833.2 (c)
Temperature Difference: Case 2
ΔTCase2= T1 - T2,MIN
[ºC]
(34)
Ref. (1) Para. 833.2 (c)
[N.m]
(35)
[-]
(43)
3.5 Bending Moment
Bending Moment
M=Es.I/R
3.7 Stress Intensification Factor
Stress Intensification Factor
Doc. No.: 4148-DGTYP-7-17-0001
i=1
Attachment-4
Note (3)
Attachment - Wall Thickness Calculation - Stress Check
4.0 CALCULATIONS
4.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL =
270.00
MPa
[Eq. (1)]
Max Allowable Expansion Stress
SE,ALL =
96.59
MPa
[Eq. (2)]
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL =
337.50
MPa
[Eq. (3)]
4.2 Wall Thickness
Calculated wall thickness
t=
11.19
mm
[Eq. (25)]
Calculated wall thickness with corrosion allowance
tn =
14.19
mm
[Eq. (26)]
Selected wall thickness
ts =
14.27
mm
[Eq. (27)]
Minimum wall thickness
tmin =
11.27
mm
[Eq. (28)]
Check Acceptability:
If tn<ts, selected wall thickness is accepted
Accepted
4.2.1 D/t ratio for constructability and handing evaluation
D / ts =
11.79
Note (4)
4.3 Pipeline Properties
Internal Diameter
Din =
Pipe moment of Inertia
I=
0.000017
Pipe section modulus
Z=
204.70
cm
Pipe Metal Cross Section Area
A=
5559.76
mm
[Eq. (32)]
145.76
mm
[Eq. (29)]
4
[Eq. (30)]
m
3
[Eq. (31)]
2
4.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1=
-129
ºC
[Eq. (33)]
Temperature Difference: Case 2
ΔTCase2=
31
ºC
[Eq. (34)]
1.43E+04
N.m
[Eq. (35)]
4.5 Bending Moment
Bending Moment
M=
4.6 Pipeline Stresses
4.6.1 Hoop Stress
Hoop Stress
SH =
268.06
MPa
Ratio to SMYS
SMYS %=
59.57%
%
[Eq. (20)]
Ratio of calculated to Allowable (Hoop)
%H =
99.28%
%
[Eq. (21)]
If SH<SH,ALL, selected wall thickness is acceptable
Check Acceptability:
[Eq. (6)]
Accepted
Ref. (1) Para.841.1.1
4.6.2 Expansion Stress
Expansion Stress
SE=
70.04
MPa
Check Acceptability:
If SE<SE.ALL, selected wall thickness is acceptable
[Eq. (8)]
Accepted
Longitudinal Stress due to Internal Pressure
SL,P =
80.42
MPa
[Eq. (7)]
Bending Stress (Tension)
SBT =
70.04
MPa
[Eq. (11)]
Bending Stress (Compression)
SBC=
-70.04
MPa
[Eq. (12)]
Longitudinal Stress due to Axial Loading
Sx=
0.00
Mpa
[Eq. (10)]
Longitudinal Stress (Sustained Loads): Case 1
SL1=
220.5
Mpa
[Eq. (13)]
Ratio of calculated to Allowable (Longitudinal)
%L1 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 2
SL2=
Mpa
[Eq. (14)]
Ratio of calculated to Allowable (Longitudinal)
%L2 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 3
SL3=
Mpa
[Eq. (15)]
Ratio of calculated to Allowable (Longitudinal)
%L3 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 4
SL4=
Mpa
[Eq. (16)]
Ratio of calculated to Allowable (Longitudinal)
%L4 =
%
[Eq. (22)]
(1) Four cases of evaluation
80.4
23.83%
150.5
44.58%
10.4
3.08%
Check Acceptability:
If all ǀSLǀ<SL,ALL, selected wall thickness is acceptable
Doc. No.: 4148-DGTYP-7-17-0001
65.33%
Attachment-4
Accepted
Ref. (1) Para. 833.3
Attachment - Wall Thickness Calculation - Stress Check
5.0 RESULTS SUMMARY
5.1 Results
5.1.1 Wall Thickness
t=
11.19
mm
ts =
14.27
mm
D/t=
11.79
Calculated Wall Thickness
Selected Wall Thickness
D to t Ratio
5.1.2 Calculated Stress Values
Max
Ratio of calculated to
Stress
Unit
Hoop (SH)
Mpa
270.00
268.06
99.28%
OK
Mpa
96.59
70.04
72.51%
OK
Mpa
337.50
10.4
3.08%
OK
Allowable
Calculated Value
allowable
Check
Thermal Expansion
(SE)
Worst Case Scenario
Longitudinal (SL)
Worst Case Scenario
OVERALL CHECK OF WALL THICKNESS
5.2 Notes
(1) Not Applicable for A/G Pipeline.
(2) Applied for sustained loads.
(3) Stress intensification factor equals 1 for straight pipe Table E-1 of ASME B31.8.
(4) Minimum wall thickness of pipe shall not be less than 4.8mm as per section 8.5 of QP standard QP STD-L017 Rv1.
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
ACCEPTED
Attachment - Wall Thickness Calculation - Stress Check
WALL THICKNESS CALCULATION SHEET- STRESS CHECK AS PER ASME B31.8
PROJECT: EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN DUKHANFIELDS (2019-2022) - PART B
LOCATION: : DUKHAN, QATAR
SYSTEM DESCRIPTION: KHUFF INJECTION FLOWLINE / DF = 0.72
PIPE WALL THICKNESS CALCULATION TO ASME B31.8 (UNRESTRAINED)
1.0 INTRODUCTION
1.1 Description
This Excel sheet completes the wall thickness calculation for pipeline system in line with the design requirements outlined within the ASME B31.8. The sheet determines the required wall thickness for
pressure containment and stress requirements.
1.2 Codes
(1) ASME B31.8
(2) API 5L
(3) ASME B36.10
1.3 Assumptions
(1) This Excel sheet is currently set up for CARBON STEEL only.
(2) This Calculation is applicable for Above Ground, unrestrained pipelines only.
(3) Compressive stress is a negative value
(4) The temperature limit shall be -29ºC<T<232ºC as per ASME B31.8
2.0 DESIGN DATA SUMMARY
2.1 Pipeline Data
Product / Liquid Type
Khuff Injection Flowline (DF=0.72)
Selected Pipe Material
API 5L
Specified Minimum Yield Strength
SMYS =
450.00
MPa
Ref. API 5L Table-7
Specified Minimum Tensile Strength
SMTS
535.00
Mpa
Ref. API 5L Table-7
Modulus of Elasticity of steel
Es =
203000
MPa
Ref. (3) Table C-1 (SI)
Poisson's ratio
v=
0.30
Weld Joint Factor
E=
1
Temperature Derating Factor
T
1
Coefficient of Thermal Expansion
X65
0.0000117
α=
Grade
Ref. (1) Table 841.1.7-1
Ref Table 841.1.8-1
◦
mm/mm. C
Ref. (1) Para 832.2 (Valid up to 120ºC)
2.2 Input Data
Nominal Pipe Size
NPS =
Pipe Outside Diameter
D=
168.30
6
mm
Internal Design gage Pressure
Pi =
368.6
barg
Maximum Operating Temperature
T2,MAX =
84
ºC
Minimum Operating Temperature
T2,MIN =
-10
ºC
Installation Temperature
T1 =
21
ºC
Design Factor
F=
0.72
Corrosion Allowance
Ca =
Water Density
rwater
3
External Force Axial Component (if any)
Fx =
0
Fatigue factor
f=
1
=
1000
in
mm
3
kg/m
N
0.33SuT at the minimum installed or operating temperature
Scold
176.55
MPa
0.33SuT at the maximum installed or operating temperature
Shot
176.55
MPa
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
Note (1)
Attachment - Wall Thickness Calculation - Stress Check
3.0 EQUATIONS
Equation
Unit
Eq. No.
Notes
Maximum Allowable Hoop Stress
SH,ALL = F.E.T.SY
[Mpa]
(1)
Ref. (1) Para. 841.1.1
Max Allowable Expansion Stress
SE,ALL = f[1.25(Scold+Shot)-SL]
[Mpa]
(2)
Ref. (1) Para. 833.8 (b)
Max Allowable Longitudinal Stress (See Note 2)
SL,ALL = 75%.SYT
[Mpa]
(3)
Ref. (1) Para. 833.6 (b)
Hoop Stress
SH = Pi.D / 20.tmin
[Mpa]
(6)
Ref. (1) Para. 805.2.3
Longitudinal Stress due to Internal Pressure
SL,P =
[Mpa]
(7)
Ref. (1) Para. 833.2 (a)
Expansion Stress
SE= ME/Z
[Mpa]
(8)
Ref. (1) Para. 833.8 (a)
Longitudinal Stress due to Axial Loading
Sx = Fx / A
[Mpa]
(10)
Ref. (1) Para. 833.2 (f)
Bending Stress (Tension)
SBT = iM / Z
[Mpa]
(11)
Ref. (1) Para. 833.2 (d)
Bending Stress (Compression)
SBC= -iM / Z
[Mpa]
(12)
Ref. (1) Para. 833.2 (d)
Longitudinal Stress (Sustained Loads): Case 1
SL1=ST1 + SL,P + SBT + Sx
[Mpa]
(13)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 2
SL2=ST1 + SL,P + SBC + Sx
[Mpa]
(14)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 3
SL3=ST2 + SL,P + SBT + Sx
[Mpa]
(15)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 4
SL4=ST2 + SL,P + SBC + Sx
[Mpa]
(16)
Ref. (1) Para. 833.3 (a)
3.1 Stresss
3.1.1 Maximum Allowable (due to Code)
3.1.2 Stresses
0.5.SH
3.1.3 Ratios
Ratio to SMYS
SMYS % = SH / SY
[%]
(20)
Ratio of calculated to Allowable (Hoop)
%H = SH / SH,ALL
[%]
(21)
Ratio of calculated to Allowable (Longitudinal)
%L = SL / SL,ALL
[%]
(22)
3.2 Wall Thickness
Calculated wall thickness
t =Pi.D / 20.SH,ALL
[mm]
(25)
Calculated wall thickness with corrosion allowance
tn = t + Ca
[mm]
(26)
Selected wall thickness
ts > tn
[mm]
(27)
Minimum wall thickness
tmin = ts - Ca
[mm]
(28)
[mm]
(29)
Ref. (1) Para. 841.1.1
Ref. (2) Table 1
3.3 Pipeline Properties
Internal Diameter of the Pipe
Din = D-2tmin
Pipe moment of Inertia
I=
Pipe section modulus
Z=2*I/D
Pipe Metal Cross Section Area
4
p (D
A=
4
- Din ) /64
2
p (D
-
2
Din )
/4
4
[m ]
(30)
3
[cm ]
(31)
2
[mm ]
(32)
3.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1= T1 - T2,MAX
[ºC]
(33)
Ref. (1) Para. 833.2 (c)
Temperature Difference: Case 2
ΔTCase2= T1 - T2,MIN
[ºC]
(34)
Ref. (1) Para. 833.2 (c)
[N.m]
(35)
[-]
(43)
3.5 Bending Moment
Bending Moment
M=Es.I/R
3.7 Stress Intensification Factor
Stress Intensification Factor
Doc. No.: 4148-DGTYP-7-17-0001
i=1
Attachment-4
Note (3)
Attachment - Wall Thickness Calculation - Stress Check
4.0 CALCULATIONS
4.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL =
324.00
MPa
[Eq. (1)]
Max Allowable Expansion Stress
SE,ALL =
103.88
MPa
[Eq. (2)]
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL =
337.50
MPa
[Eq. (3)]
4.2 Wall Thickness
Calculated wall thickness
t=
9.57
mm
[Eq. (25)]
Calculated wall thickness with corrosion allowance
tn =
12.57
mm
[Eq. (26)]
Selected wall thickness
ts =
14.27
mm
[Eq. (27)]
Minimum wall thickness
tmin =
11.27
mm
[Eq. (28)]
Check Acceptability:
If tn<ts, selected wall thickness is accepted
Accepted
4.2.1 D/t ratio for constructability and handing evaluation
D / ts =
11.79
Note (4)
4.3 Pipeline Properties
Internal Diameter
Din =
Pipe moment of Inertia
I=
0.000017
Pipe section modulus
Z=
204.70
cm
Pipe Metal Cross Section Area
A=
5559.76
mm
[Eq. (32)]
145.76
mm
[Eq. (29)]
4
[Eq. (30)]
m
3
[Eq. (31)]
2
4.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1=
-63
ºC
[Eq. (33)]
Temperature Difference: Case 2
ΔTCase2=
31
ºC
[Eq. (34)]
1.53E+04
N.m
[Eq. (35)]
4.5 Bending Moment
Bending Moment
M=
4.6 Pipeline Stresses
4.6.1 Hoop Stress
Hoop Stress
SH =
275.22
MPa
Ratio to SMYS
SMYS %=
61.16%
%
[Eq. (20)]
Ratio of calculated to Allowable (Hoop)
%H =
84.95%
%
[Eq. (21)]
If SH<SH,ALL, selected wall thickness is acceptable
Check Acceptability:
[Eq. (6)]
Accepted
Ref. (1) Para.841.1.1
4.6.2 Expansion Stress
Expansion Stress
SE=
74.84
MPa
Check Acceptability:
If SE<SE.ALL, selected wall thickness is acceptable
[Eq. (8)]
Accepted
Longitudinal Stress due to Internal Pressure
SL,P =
82.57
MPa
[Eq. (7)]
Bending Stress (Tension)
SBT =
74.84
MPa
[Eq. (11)]
Bending Stress (Compression)
SBC=
-74.84
MPa
[Eq. (12)]
Longitudinal Stress due to Axial Loading
Sx=
0.00
Mpa
[Eq. (10)]
Longitudinal Stress (Sustained Loads): Case 1
SL1=
232.2
Mpa
[Eq. (13)]
Ratio of calculated to Allowable (Longitudinal)
%L1 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 2
SL2=
Mpa
[Eq. (14)]
Ratio of calculated to Allowable (Longitudinal)
%L2 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 3
SL3=
Mpa
[Eq. (15)]
Ratio of calculated to Allowable (Longitudinal)
%L3 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 4
SL4=
Mpa
[Eq. (16)]
Ratio of calculated to Allowable (Longitudinal)
%L4 =
%
[Eq. (22)]
(1) Four cases of evaluation
82.6
24.46%
157.4
46.64%
7.7
2.29%
Check Acceptability:
If all ǀSLǀ<SL,ALL, selected wall thickness is acceptable
Doc. No.: 4148-DGTYP-7-17-0001
68.81%
Attachment-4
Accepted
Ref. (1) Para. 833.3
Attachment - Wall Thickness Calculation - Stress Check
5.0 RESULTS SUMMARY
5.1 Results
5.1.1 Wall Thickness
t=
9.57
mm
ts =
14.27
mm
D/t=
11.79
Calculated Wall Thickness
Selected Wall Thickness
D to t Ratio
5.1.2 Calculated Stress Values
Max
Ratio of calculated to
Stress
Unit
Hoop (SH)
Mpa
324.00
275.22
84.95%
OK
Mpa
103.88
74.84
72.05%
OK
Mpa
337.50
7.7
2.29%
OK
Allowable
Calculated Value
allowable
Check
Thermal Expansion
(SE)
Worst Case Scenario
Longitudinal (SL)
Worst Case Scenario
OVERALL CHECK OF WALL THICKNESS
5.2 Notes
(1) Not Applicable for A/G Pipeline.
(2) Applied for sustained loads.
(3) Stress intensification factor equals 1 for straight pipe Table E-1 of ASME B31.8.
(4) Minimum wall thickness of pipe shall not be less than 4.8mm as per section 8.5 of QP standard QP STD-L017 Rv1.
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
ACCEPTED
Attachment - Wall Thickness Calculation - Stress Check
WALL THICKNESS CALCULATION SHEET- STRESS CHECK AS PER ASME B31.8
PROJECT: EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN DUKHANFIELDS (2019-2022) - PART B
LOCATION: : DUKHAN, QATAR
SYSTEM DESCRIPTION: KHUFF INJECTION FLOWLINE / DF = 0.6
PIPE WALL THICKNESS CALCULATION TO ASME B31.8 (UNRESTRAINED)
1.0 INTRODUCTION
1.1 Description
This Excel sheet completes the wall thickness calculation for pipeline system in line with the design requirements outlined within the ASME B31.8. The sheet determines the required wall thickness for
pressure containment and stress requirements.
1.2 Codes
(1) ASME B31.8
(2) API 5L
(3) ASME B36.10
1.3 Assumptions
(1) This Excel sheet is currently set up for CARBON STEEL only.
(2) This Calculation is applicable for Above Ground, unrestrained pipelines only.
(3) Compressive stress is a negative value
(4) The temperature limit shall be -29ºC<T<232ºC as per ASME B31.8
2.0 DESIGN DATA SUMMARY
2.1 Pipeline Data
Product / Liquid Type
Khuff Injection Flowline (DF=0.6)
Selected Pipe Material
API 5L
Specified Minimum Yield Strength
SMYS =
450.00
MPa
Ref. API 5L Table-7
Specified Minimum Tensile Strength
SMTS
535.00
Mpa
Ref. API 5L Table-7
Modulus of Elasticity of steel
Es =
203000
MPa
Ref. (3) Table C-1 (SI)
Poisson's ratio
v=
0.30
Weld Joint Factor
E=
1
Temperature Derating Factor
T
1
Coefficient of Thermal Expansion
X65
0.0000117
α=
Grade
Ref. (1) Table 841.1.7-1
Ref Table 841.1.8-1
◦
mm/mm. C
Ref. (1) Para 832.2 (Valid up to 120ºC)
2.2 Input Data
Nominal Pipe Size
NPS =
Pipe Outside Diameter
D=
168.30
6
mm
Internal Design gage Pressure
Pi =
368.6
barg
Maximum Operating Temperature
T2,MAX =
84
ºC
Minimum Operating Temperature
T2,MIN =
-10
ºC
Installation Temperature
T1 =
21
ºC
Design Factor
F=
0.6
Corrosion Allowance
Ca =
Water Density
rwater
3
External Force Axial Component (if any)
Fx =
0
Fatigue factor
f=
1
=
1000
in
mm
3
kg/m
N
0.33SuT at the minimum installed or operating temperature
Scold
176.55
MPa
0.33SuT at the maximum installed or operating temperature
Shot
176.55
MPa
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
Note (1)
Attachment - Wall Thickness Calculation - Stress Check
3.0 EQUATIONS
Equation
Unit
Eq. No.
Notes
Maximum Allowable Hoop Stress
SH,ALL = F.E.T.SY
[Mpa]
(1)
Ref. (1) Para. 841.1.1
Max Allowable Expansion Stress
SE,ALL = f[1.25(Scold+Shot)-SL]
[Mpa]
(2)
Ref. (1) Para. 833.8 (b)
Max Allowable Longitudinal Stress (See Note 2)
SL,ALL = 75%.SYT
[Mpa]
(3)
Ref. (1) Para. 833.6 (b)
Hoop Stress
SH = Pi.D / 20.tmin
[Mpa]
(6)
Ref. (1) Para. 805.2.3
Longitudinal Stress due to Internal Pressure
SL,P =
[Mpa]
(7)
Ref. (1) Para. 833.2 (a)
Expansion Stress
SE= ME/Z
[Mpa]
(8)
Ref. (1) Para. 833.8 (a)
Longitudinal Stress due to Axial Loading
Sx = Fx / A
[Mpa]
(10)
Ref. (1) Para. 833.2 (f)
Bending Stress (Tension)
SBT = iM / Z
[Mpa]
(11)
Ref. (1) Para. 833.2 (d)
Bending Stress (Compression)
SBC= -iM / Z
[Mpa]
(12)
Ref. (1) Para. 833.2 (d)
Longitudinal Stress (Sustained Loads): Case 1
SL1=ST1 + SL,P + SBT + Sx
[Mpa]
(13)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 2
SL2=ST1 + SL,P + SBC + Sx
[Mpa]
(14)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 3
SL3=ST2 + SL,P + SBT + Sx
[Mpa]
(15)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 4
SL4=ST2 + SL,P + SBC + Sx
[Mpa]
(16)
Ref. (1) Para. 833.3 (a)
3.1 Stresss
3.1.1 Maximum Allowable (due to Code)
3.1.2 Stresses
0.5.SH
3.1.3 Ratios
Ratio to SMYS
SMYS % = SH / SY
[%]
(20)
Ratio of calculated to Allowable (Hoop)
%H = SH / SH,ALL
[%]
(21)
Ratio of calculated to Allowable (Longitudinal)
%L = SL / SL,ALL
[%]
(22)
3.2 Wall Thickness
Calculated wall thickness
t =Pi.D / 20.SH,ALL
[mm]
(25)
Calculated wall thickness with corrosion allowance
tn = t + Ca
[mm]
(26)
Selected wall thickness
ts > tn
[mm]
(27)
Minimum wall thickness
tmin = ts - Ca
[mm]
(28)
[mm]
(29)
Ref. (1) Para. 841.1.1
Ref. (2) Table 1
3.3 Pipeline Properties
Internal Diameter of the Pipe
Din = D-2tmin
Pipe moment of Inertia
I=
Pipe section modulus
Z=2*I/D
Pipe Metal Cross Section Area
4
p (D
A=
4
- Din ) /64
2
p (D
-
2
Din )
/4
4
[m ]
(30)
3
[cm ]
(31)
2
[mm ]
(32)
3.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1= T1 - T2,MAX
[ºC]
(33)
Ref. (1) Para. 833.2 (c)
Temperature Difference: Case 2
ΔTCase2= T1 - T2,MIN
[ºC]
(34)
Ref. (1) Para. 833.2 (c)
[N.m]
(35)
[-]
(43)
3.5 Bending Moment
Bending Moment
M=Es.I/R
3.7 Stress Intensification Factor
Stress Intensification Factor
Doc. No.: 4148-DGTYP-7-17-0001
i=1
Attachment-4
Note (3)
Attachment - Wall Thickness Calculation - Stress Check
4.0 CALCULATIONS
4.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL =
270.00
MPa
[Eq. (1)]
Max Allowable Expansion Stress
SE,ALL =
103.88
MPa
[Eq. (2)]
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL =
337.50
MPa
[Eq. (3)]
4.2 Wall Thickness
Calculated wall thickness
t=
11.49
mm
[Eq. (25)]
Calculated wall thickness with corrosion allowance
tn =
14.49
mm
[Eq. (26)]
Selected wall thickness
ts =
16.5
mm
[Eq. (27)]
Minimum wall thickness
tmin =
13.50
mm
[Eq. (28)]
Check Acceptability:
If tn<ts, selected wall thickness is accepted
Accepted
4.2.1 D/t ratio for constructability and handing evaluation
D / ts =
10.20
Note (4)
4.3 Pipeline Properties
Internal Diameter
Din =
Pipe moment of Inertia
I=
0.000020
Pipe section modulus
Z=
235.47
cm
Pipe Metal Cross Section Area
A=
6565.30
mm
[Eq. (32)]
141.30
mm
[Eq. (29)]
4
[Eq. (30)]
m
3
[Eq. (31)]
2
4.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1=
-63
ºC
[Eq. (33)]
Temperature Difference: Case 2
ΔTCase2=
31
ºC
[Eq. (34)]
1.65E+04
N.m
[Eq. (35)]
4.5 Bending Moment
Bending Moment
M=
4.6 Pipeline Stresses
4.6.1 Hoop Stress
Hoop Stress
SH =
229.76
MPa
Ratio to SMYS
SMYS %=
51.06%
%
[Eq. (20)]
Ratio of calculated to Allowable (Hoop)
%H =
85.10%
%
[Eq. (21)]
If SH<SH,ALL, selected wall thickness is acceptable
Check Acceptability:
[Eq. (6)]
Accepted
Ref. (1) Para.841.1.1
4.6.2 Expansion Stress
Expansion Stress
SE=
70.04
MPa
Check Acceptability:
If SE<SE.ALL, selected wall thickness is acceptable
[Eq. (8)]
Accepted
Longitudinal Stress due to Internal Pressure
SL,P =
68.93
MPa
[Eq. (7)]
Bending Stress (Tension)
SBT =
70.04
MPa
[Eq. (11)]
Bending Stress (Compression)
SBC=
-70.04
MPa
[Eq. (12)]
Longitudinal Stress due to Axial Loading
Sx=
0.00
Mpa
[Eq. (10)]
Longitudinal Stress (Sustained Loads): Case 1
SL1=
209.0
Mpa
[Eq. (13)]
Ratio of calculated to Allowable (Longitudinal)
%L1 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 2
SL2=
Mpa
[Eq. (14)]
Ratio of calculated to Allowable (Longitudinal)
%L2 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 3
SL3=
Mpa
[Eq. (15)]
Ratio of calculated to Allowable (Longitudinal)
%L3 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 4
SL4=
Mpa
[Eq. (16)]
Ratio of calculated to Allowable (Longitudinal)
%L4 =
%
[Eq. (22)]
(1) Four cases of evaluation
68.9
20.42%
139.0
41.17%
-1.1
0.33%
Check Acceptability:
If all ǀSLǀ<SL,ALL, selected wall thickness is acceptable
Doc. No.: 4148-DGTYP-7-17-0001
61.93%
Attachment-4
Accepted
Ref. (1) Para. 833.3
Attachment - Wall Thickness Calculation - Stress Check
5.0 RESULTS SUMMARY
5.1 Results
5.1.1 Wall Thickness
t=
11.49
mm
ts =
16.50
mm
D/t=
10.20
Calculated Wall Thickness
Selected Wall Thickness
D to t Ratio
5.1.2 Calculated Stress Values
Max
Ratio of calculated to
Stress
Unit
Hoop (SH)
Mpa
270.00
229.76
85.10%
OK
Mpa
103.88
70.04
67.42%
OK
Mpa
337.50
-1.1
0.33%
OK
Allowable
Calculated Value
allowable
Check
Thermal Expansion
(SE)
Worst Case Scenario
Longitudinal (SL)
Worst Case Scenario
OVERALL CHECK OF WALL THICKNESS
5.2 Notes
(1) Not Applicable for A/G Pipeline.
(2) Applied for sustained loads.
(3) Stress intensification factor equals 1 for straight pipe Table E-1 of ASME B31.8.
(4) Minimum wall thickness of pipe shall not be less than 4.8mm as per section 8.5 of QP standard QP STD-L017 Rv1.
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
ACCEPTED
Attachment - Wall Thickness Calculation - Stress Check
WALL THICKNESS CALCULATION SHEET- STRESS CHECK AS PER ASME B31.8
PROJECT: EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN DUKHANFIELDS (2019-2022) - PART B
LOCATION: : DUKHAN, QATAR
SYSTEM DESCRIPTION: RG PRODUCTION FLOWLINE / DF = 0.6
PIPE WALL THICKNESS CALCULATION TO ASME B31.8 (UNRESTRAINED)
1.0 INTRODUCTION
1.1 Description
This Excel sheet completes the wall thickness calculation for pipeline system in line with the design requirements outlined within the ASME B31.8. The sheet determines the required wall thickness for
pressure containment and stress requirements.
1.2 Codes
(1) ASME B31.8
(2) API 5L
(3) ASME B36.10
1.3 Assumptions
(1) This Excel sheet is currently set up for CARBON STEEL only.
(2) This Calculation is applicable for Above Ground, unrestrained pipelines only.
(3) Compressive stress is a negative value.
(4) The temperature limit shall be -29ºC<T<232ºC as per ASME B31.8.
2.0 DESIGN DATA SUMMARY
2.1 Pipeline Data
Product / Liquid Type
RG Production Flowline
Selected Pipe Material
API 5L
Specified Minimum Yield Strength
SMYS =
360.00
MPa
Ref. API 5L Table-7
Specified Minimum Tensile Strength
SMTS
460.00
Mpa
Ref. API 5L Table-7
Modulus of Elasticity of steel
Es =
203000
MPa
Ref. (3) Table C-1 (SI)
Poisson's ratio
v=
0.30
Weld Joint Factor
E=
1
Temperature Derating Factor
T
1
Coefficient of Thermal Expansion
X52
0.0000117
α=
Grade
Ref. (1) Table 841.1.7-1
Ref Table 841.1.8-1
◦
mm/mm. C
Ref. (1) Para 832.2 (Valid up to 120ºC)
2.2 Input Data
Nominal Pipe Size
NPS =
Pipe Outside Diameter
D=
219.10
8
mm
Internal Design gage Pressure
Pi =
179.3
barg
Maximum Operating Temperature
T2,MAX =
84
ºC
Minimum Operating Temperature
T2,MIN =
-10
ºC
Installation Temperature
T1 =
21
ºC
Design Factor
F=
0.6
Corrosion Allowance
Ca =
Water Density
rwater
3
External Force Axial Component (if any)
Fx =
0
Fatigue factor
f=
1
=
1000
in
mm
3
kg/m
N
0.33SuT at the minimum installed or operating temperature
Scold
151.80
MPa
0.33SuT at the maximum installed or operating temperature
Shot
151.80
MPa
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
Note (1)
Attachment - Wall Thickness Calculation - Stress Check
3.0 EQUATIONS
Equation
Unit
Eq. No.
Notes
Maximum Allowable Hoop Stress
SH,ALL = F.E.T.SY
[Mpa]
(1)
Ref. (1) Para. 841.1.1
Max Allowable Expansion Stress
SE,ALL = f[1.25(Scold+Shot)-SL]
[Mpa]
(2)
Ref. (1) Para. 833.8 (b)
Max Allowable Longitudinal Stress (See Note 2)
SL,ALL = 75%.SYT
[Mpa]
(3)
Ref. (1) Para. 833.6 (b)
Hoop Stress
SH = Pi.D / 20.tmin
[Mpa]
(6)
Ref. (1) Para. 805.2.3
Longitudinal Stress due to Internal Pressure
SL,P =
[Mpa]
(7)
Ref. (1) Para. 833.2 (a)
Expansion Stress
SE= ME/Z
[Mpa]
(8)
Ref. (1) Para. 833.8 (a)
Longitudinal Stress due to Axial Loading
Sx = Fx / A
[Mpa]
(10)
Ref. (1) Para. 833.2 (f)
Bending Stress (Tension)
SBT = iM / Z
[Mpa]
(11)
Ref. (1) Para. 833.2 (d)
Bending Stress (Compression)
SBC= -iM / Z
[Mpa]
(12)
Ref. (1) Para. 833.2 (d)
Longitudinal Stress (Sustained Loads): Case 1
SL1=ST1 + SL,P + SBT + Sx
[Mpa]
(13)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 2
SL2=ST1 + SL,P + SBC + Sx
[Mpa]
(14)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 3
SL3=ST2 + SL,P + SBT + Sx
[Mpa]
(15)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 4
SL4=ST2 + SL,P + SBC + Sx
[Mpa]
(16)
Ref. (1) Para. 833.3 (a)
3.1 Stresss
3.1.1 Maximum Allowable (due to Code)
3.1.2 Stresses
0.5.SH
3.1.3 Ratios
Ratio to SMYS
SMYS % = SH / SY
[%]
(20)
Ratio of calculated to Allowable (Hoop)
%H = SH / SH,ALL
[%]
(21)
Ratio of calculated to Allowable (Longitudinal)
%L = SL / SL,ALL
[%]
(22)
3.2 Wall Thickness
Calculated wall thickness
t =Pi.D / 20.SH,ALL
[mm]
(25)
Calculated wall thickness with corrosion allowance
tn = t + Ca
[mm]
(26)
Selected wall thickness
ts > tn
[mm]
(27)
Minimum wall thickness
tmin = ts - Ca
[mm]
(28)
[mm]
(29)
Ref. (1) Para. 841.1.1
Ref. (2) Table 1
3.3 Pipeline Properties
Internal Diameter of the Pipe
Din = D-2tmin
Pipe moment of Inertia
I=
Pipe section modulus
Z=2*I/D
Pipe Metal Cross Section Area
4
p (D
A=
4
- Din ) /64
2
p (D
-
2
Din )
/4
4
[m ]
(30)
3
[cm ]
(31)
2
[mm ]
(32)
3.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1= T1 - T2,MAX
[ºC]
(33)
Ref. (1) Para. 833.2 (c)
Temperature Difference: Case 2
ΔTCase2= T1 - T2,MIN
[ºC]
(34)
Ref. (1) Para. 833.2 (c)
[N.m]
(35)
[-]
(43)
3.5 Bending Moment
Bending Moment
M=Es.I/R
3.7 Stress Intensification Factor
Stress Intensification Factor
Doc. No.: 4148-DGTYP-7-17-0001
i=1
Attachment-4
Note (3)
Attachment - Wall Thickness Calculation - Stress Check
4.0 CALCULATIONS
4.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL =
216.00
MPa
[Eq. (1)]
Max Allowable Expansion Stress
SE,ALL =
109.50
MPa
[Eq. (2)]
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL =
270.00
MPa
[Eq. (3)]
4.2 Wall Thickness
Calculated wall thickness
t=
9.09
mm
[Eq. (25)]
Calculated wall thickness with corrosion allowance
tn =
12.09
mm
[Eq. (26)]
Selected wall thickness
ts =
12.7
mm
[Eq. (27)]
Minimum wall thickness
tmin =
9.70
mm
[Eq. (28)]
Check Acceptability:
If tn<ts, selected wall thickness is accepted
Accepted
4.2.1 D/t ratio for constructability and handing evaluation
D / ts =
17.25
Note (4)
4.3 Pipeline Properties
Internal Diameter
Din =
Pipe moment of Inertia
I=
0.000035
Pipe section modulus
Z=
319.95
cm
Pipe Metal Cross Section Area
A=
6381.14
mm
[Eq. (32)]
199.70
mm
[Eq. (29)]
4
[Eq. (30)]
m
3
[Eq. (31)]
2
4.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1=
-63
ºC
[Eq. (33)]
Temperature Difference: Case 2
ΔTCase2=
31
ºC
[Eq. (34)]
2.35E+04
N.m
[Eq. (35)]
4.5 Bending Moment
Bending Moment
M=
4.6 Pipeline Stresses
4.6.1 Hoop Stress
Hoop Stress
SH =
202.50
MPa
Ratio to SMYS
SMYS %=
56.25%
%
[Eq. (20)]
Ratio of calculated to Allowable (Hoop)
%H =
93.75%
%
[Eq. (21)]
If SH<SH,ALL, selected wall thickness is acceptable
Check Acceptability:
[Eq. (6)]
Accepted
Ref. (1) Para.841.1.1
4.6.2 Expansion Stress
Expansion Stress
SE=
73.46
MPa
Check Acceptability:
If SE<SE.ALL, selected wall thickness is acceptable
[Eq. (8)]
Accepted
Longitudinal Stress due to Internal Pressure
SL,P =
60.75
MPa
[Eq. (7)]
Bending Stress (Tension)
SBT =
73.46
MPa
[Eq. (11)]
Bending Stress (Compression)
SBC=
-73.46
MPa
[Eq. (12)]
Longitudinal Stress due to Axial Loading
Sx=
0.00
Mpa
[Eq. (10)]
Longitudinal Stress (Sustained Loads): Case 1
SL1=
207.7
Mpa
[Eq. (13)]
Ratio of calculated to Allowable (Longitudinal)
%L1 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 2
SL2=
Mpa
[Eq. (14)]
Ratio of calculated to Allowable (Longitudinal)
%L2 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 3
SL3=
Mpa
[Eq. (15)]
Ratio of calculated to Allowable (Longitudinal)
%L3 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 4
SL4=
Mpa
[Eq. (16)]
Ratio of calculated to Allowable (Longitudinal)
%L4 =
%
[Eq. (22)]
(1) Four cases of evaluation
60.7
22.50%
134.2
49.71%
-12.7
4.71%
Check Acceptability:
If all ǀSLǀ<SL,ALL, selected wall thickness is acceptable
Doc. No.: 4148-DGTYP-7-17-0001
76.92%
Attachment-4
Accepted
Ref. (1) Para. 833.3
Attachment - Wall Thickness Calculation - Stress Check
5.0 RESULTS SUMMARY
5.1 Results
5.1.1 Wall Thickness
t=
9.09
mm
ts =
12.70
mm
D/t=
17.25
Calculated Wall Thickness
Selected Wall Thickness
D to t Ratio
5.1.2 Calculated Stress Values
Max
Ratio of calculated to
Stress
Unit
Hoop (SH)
Mpa
216.00
202.50
93.75%
OK
Mpa
109.50
73.46
67.09%
OK
Mpa
270.00
-12.7
4.71%
OK
Allowable
Calculated Value
allowable
Check
Thermal Expansion
(SE)
Worst Case Scenario
Longitudinal (SL)
Worst Case Scenario
OVERALL CHECK OF WALL THICKNESS
5.2 Notes
(1) Not Applicable for A/G Pipeline
(2) Applied for sustained loads
(3) Stress intensification factor equals 1 for straight pipe Table E-1 of ASME B31.8
(4) Minimum wall thickness of pipe shall not be less than 4.8mm as per section 8.5 of QP standard QP STD-L017 Rv1.
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
ACCEPTED
Attachment - Wall Thickness Calculation - Stress Check
WALL THICKNESS CALCULATION SHEET- STRESS CHECK AS PER ASME B31.8
PROJECT: EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN DUKHANFIELDS (2019-2022) - PART B
LOCATION: : DUKHAN, QATAR
SYSTEM DESCRIPTION: RG INJECTION FLOWLINE / DF = 0.72
PIPE WALL THICKNESS CALCULATION TO ASME B31.8 (UNRESTRAINED)
1.0 INTRODUCTION
1.1 Description
This Excel sheet completes the wall thickness calculation for pipeline system in line with the design requirements outlined within the ASME B31.8. The sheet determines the required wall thickness for
pressure containment and stress requirements.
1.2 Codes
(1) ASME B31.8
(2) API 5L
(3) ASME B36.10
1.3 Assumptions
(1) This Excel sheet is currently set up for CARBON STEEL only.
(2) This Calculation is applicable for Above Ground, unrestrained pipelines only.
(3) Compressive stress is a negative value
(4) The temperature limit shall be -29ºC<T<232ºC as per ASME B31.8.
2.0 DESIGN DATA SUMMARY
2.1 Pipeline Data
Product / Liquid Type
RG Injection Flowline
Selected Pipe Material
API 5L
Specified Minimum Yield Strength
SMYS =
415.00
MPa
Ref. API 5L Table-7
Specified Minimum Tensile Strength
SMTS
520.00
Mpa
Ref. API 5L Table-7
Modulus of Elasticity of steel
Es =
203000
MPa
Ref. (3) Table C-1 (SI)
Poisson's ratio
v=
0.30
Weld Joint Factor
E=
1
Temperature Derating Factor
T
1
Coefficient of Thermal Expansion
X60
0.0000117
α=
Grade
Ref. (1) Table 841.1.7-1
Ref Table 841.1.8-1
◦
mm/mm. C
Ref. (1) Para 832.2 (Valid up to 120ºC)
2.2 Input Data
Nominal Pipe Size
NPS =
Pipe Outside Diameter
D=
168.30
6
mm
Internal Design gage Pressure
Pi =
240
barg
Maximum Operating Temperature
T2,MAX =
84
ºC
Minimum Operating Temperature
T2,MIN =
-10
ºC
Installation Temperature
T1 =
21
ºC
Design Factor
F=
0.72
Corrosion Allowance
Ca =
Water Density
rwater
3
External Force Axial Component (if any)
Fx =
0
Fatigue factor
f=
1
=
1000
in
mm
3
kg/m
N
0.33SuT at the minimum installed or operating temperature
Scold
171.60
MPa
0.33SuT at the maximum installed or operating temperature
Shot
171.60
MPa
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
Note (1)
Attachment - Wall Thickness Calculation - Stress Check
3.0 EQUATIONS
Equation
Unit
Eq. No.
Notes
Maximum Allowable Hoop Stress
SH,ALL = F.E.T.SY
[Mpa]
(1)
Ref. (1) Para. 841.1.1
Max Allowable Expansion Stress
SE,ALL = f[1.25(Scold+Shot)-SL]
[Mpa]
(2)
Ref. (1) Para. 833.8 (b)
Max Allowable Longitudinal Stress (See Note 2)
SL,ALL = 75%.SYT
[Mpa]
(3)
Ref. (1) Para. 833.6 (b)
Hoop Stress
SH = Pi.D / 20.tmin
[Mpa]
(6)
Ref. (1) Para. 805.2.3
Longitudinal Stress due to Internal Pressure
SL,P =
[Mpa]
(7)
Ref. (1) Para. 833.2 (a)
Expansion Stress
SE= ME/Z
[Mpa]
(8)
Ref. (1) Para. 833.8 (a)
Longitudinal Stress due to Axial Loading
Sx = Fx / A
[Mpa]
(10)
Ref. (1) Para. 833.2 (f)
Bending Stress (Tension)
SBT = iM / Z
[Mpa]
(11)
Ref. (1) Para. 833.2 (d)
Bending Stress (Compression)
SBC= -iM / Z
[Mpa]
(12)
Ref. (1) Para. 833.2 (d)
Longitudinal Stress (Sustained Loads): Case 1
SL1=ST1 + SL,P + SBT + Sx
[Mpa]
(13)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 2
SL2=ST1 + SL,P + SBC + Sx
[Mpa]
(14)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 3
SL3=ST2 + SL,P + SBT + Sx
[Mpa]
(15)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 4
SL4=ST2 + SL,P + SBC + Sx
[Mpa]
(16)
Ref. (1) Para. 833.3 (a)
3.1 Stresss
3.1.1 Maximum Allowable (due to Code)
3.1.2 Stresses
0.5.SH
3.1.3 Ratios
Ratio to SMYS
SMYS % = SH / SY
[%]
(20)
Ratio of calculated to Allowable (Hoop)
%H = SH / SH,ALL
[%]
(21)
Ratio of calculated to Allowable (Longitudinal)
%L = SL / SL,ALL
[%]
(22)
3.2 Wall Thickness
Calculated wall thickness
t =Pi.D / 20.SH,ALL
[mm]
(25)
Calculated wall thickness with corrosion allowance
tn = t + Ca
[mm]
(26)
Selected wall thickness
ts > tn
[mm]
(27)
Minimum wall thickness
tmin = ts - Ca
[mm]
(28)
[mm]
(29)
Ref. (1) Para. 841.1.1
Ref. (2) Table 1
3.3 Pipeline Properties
Internal Diameter of the Pipe
Din = D-2tmin
Pipe moment of Inertia
I=
Pipe section modulus
Z=2*I/D
Pipe Metal Cross Section Area
4
p (D
A=
4
- Din ) /64
2
p (D
-
2
Din )
/4
4
[m ]
(30)
3
[cm ]
(31)
2
[mm ]
(32)
3.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1= T1 - T2,MAX
[ºC]
(33)
Ref. (1) Para. 833.2 (c)
Temperature Difference: Case 2
ΔTCase2= T1 - T2,MIN
[ºC]
(34)
Ref. (1) Para. 833.2 (c)
[N.m]
(35)
[-]
(43)
3.5 Bending Moment
Bending Moment
M=Es.I/R
3.7 Stress Intensification Factor
Stress Intensification Factor
Doc. No.: 4148-DGTYP-7-17-0001
i=1
Attachment-4
Note (3)
Attachment - Wall Thickness Calculation - Stress Check
4.0 CALCULATIONS
4.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL =
298.80
MPa
[Eq. (1)]
Max Allowable Expansion Stress
SE,ALL =
117.75
MPa
[Eq. (2)]
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL =
311.25
MPa
[Eq. (3)]
4.2 Wall Thickness
Calculated wall thickness
t=
6.76
mm
[Eq. (25)]
Calculated wall thickness with corrosion allowance
tn =
9.76
mm
[Eq. (26)]
Selected wall thickness
ts =
10.97
mm
[Eq. (27)]
Minimum wall thickness
tmin =
7.97
mm
[Eq. (28)]
Check Acceptability:
If tn<ts, selected wall thickness is accepted
Accepted
4.2.1 D/t ratio for constructability and handing evaluation
D / ts =
15.34
Note (4)
4.3 Pipeline Properties
Internal Diameter
Din =
Pipe moment of Inertia
I=
0.000013
Pipe section modulus
Z=
153.67
cm
Pipe Metal Cross Section Area
A=
4014.42
mm
[Eq. (32)]
152.36
mm
[Eq. (29)]
4
[Eq. (30)]
m
3
[Eq. (31)]
2
4.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1=
-63
ºC
[Eq. (33)]
Temperature Difference: Case 2
ΔTCase2=
31
ºC
[Eq. (34)]
1.12E+04
N.m
[Eq. (35)]
4.5 Bending Moment
Bending Moment
M=
4.6 Pipeline Stresses
4.6.1 Hoop Stress
Hoop Stress
SH =
253.40
MPa
Ratio to SMYS
SMYS %=
61.06%
%
[Eq. (20)]
Ratio of calculated to Allowable (Hoop)
%H =
84.81%
%
[Eq. (21)]
If SH<SH,ALL, selected wall thickness is acceptable
Check Acceptability:
[Eq. (6)]
Accepted
Ref. (1) Para.841.1.1
4.6.2 Expansion Stress
Expansion Stress
SE=
72.80
MPa
Check Acceptability:
If SE<SE.ALL, selected wall thickness is acceptable
[Eq. (8)]
Accepted
Longitudinal Stress due to Internal Pressure
SL,P =
76.02
MPa
[Eq. (7)]
Bending Stress (Tension)
SBT =
72.80
MPa
[Eq. (11)]
Bending Stress (Compression)
SBC=
-72.80
MPa
[Eq. (12)]
Longitudinal Stress due to Axial Loading
Sx=
0.00
Mpa
[Eq. (10)]
Longitudinal Stress (Sustained Loads): Case 1
SL1=
221.6
Mpa
[Eq. (13)]
Ratio of calculated to Allowable (Longitudinal)
%L1 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 2
SL2=
Mpa
[Eq. (14)]
Ratio of calculated to Allowable (Longitudinal)
%L2 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 3
SL3=
Mpa
[Eq. (15)]
Ratio of calculated to Allowable (Longitudinal)
%L3 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 4
SL4=
Mpa
[Eq. (16)]
Ratio of calculated to Allowable (Longitudinal)
%L4 =
%
[Eq. (22)]
(1) Four cases of evaluation
76.0
24.42%
148.8
47.81%
3.2
1.04%
Check Acceptability:
If all ǀSLǀ<SL,ALL, selected wall thickness is acceptable
Doc. No.: 4148-DGTYP-7-17-0001
71.20%
Attachment-4
Accepted
Ref. (1) Para. 833.3
Attachment - Wall Thickness Calculation - Stress Check
5.0 RESULTS SUMMARY
5.1 Results
5.1.1 Wall Thickness
t=
6.76
mm
ts =
10.97
mm
D/t=
15.34
Calculated Wall Thickness
Selected Wall Thickness
D to t Ratio
5.1.2 Calculated Stress Values
Max
Ratio of calculated to
Stress
Unit
Hoop (SH)
Mpa
298.80
253.40
84.81%
OK
Mpa
117.75
72.80
61.82%
OK
Mpa
311.25
3.2
1.04%
OK
Allowable
Calculated Value
allowable
Check
Thermal Expansion
(SE)
Worst Case Scenario
Longitudinal (SL)
Worst Case Scenario
OVERALL CHECK OF WALL THICKNESS
5.2 Notes
(1) Not Applicable for A/G Pipeline.
(2) Applied for sustained loads.
(3) Stress intensification factor equals 1 for straight pipe Table E-1 of ASME B31.8.
(4) Minimum wall thickness of pipe shall not be less than 4.8mm as per section 8.5 of QP standard QP STD-L017 Rv1.
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
ACCEPTED
Attachment - Wall Thickness Calculation - Stress Check
WALL THICKNESS CALCULATION SHEET- STRESS CHECK AS PER ASME B31.8
PROJECT: EPIC FOR ROUTE SURVEY, DESIGN, CONSTRUCTION, INSTALLATION & HOOK-UP OF WELL FLOWLINES IN DUKHANFIELDS (2019-2022) - PART B
LOCATION: : DUKHAN, QATAR
SYSTEM DESCRIPTION: RG INJECTION FLOWLINE / DF = 0.6
PIPE WALL THICKNESS CALCULATION TO ASME B31.8 (UNRESTRAINED)
1.0 INTRODUCTION
1.1 Description
This Excel sheet completes the wall thickness calculation for pipeline system in line with the design requirements outlined within the ASME B31.8. The sheet determines the required wall thickness for
pressure containment and stress requirements.
1.2 Codes
(1) ASME B31.8
(2) API 5L
(3) ASME B36.10
1.3 Assumptions
(1) This Excel sheet is currently set up for CARBON STEEL only.
(2) This Calculation is applicable for Above Ground, unrestrained pipelines only.
(3) Compressive stress is a negative value
(4) The temperature limit shall be -29ºC<T<232ºC as per ASME B31.8.
2.0 DESIGN DATA SUMMARY
2.1 Pipeline Data
Product / Liquid Type
RG Injection Flowline
Selected Pipe Material
API 5L
Specified Minimum Yield Strength
SMYS =
415.00
MPa
Ref. API 5L Table-7
Specified Minimum Tensile Strength
SMTS
520.00
Mpa
Ref. API 5L Table-7
Modulus of Elasticity of steel
Es =
203000
MPa
Ref. (3) Table C-1 (SI)
Poisson's ratio
v=
0.30
Weld Joint Factor
E=
1
Temperature Derating Factor
T
1
Coefficient of Thermal Expansion
X60
0.0000117
α=
Grade
Ref. (1) Table 841.1.7-1
Ref Table 841.1.8-1
◦
mm/mm. C
Ref. (1) Para 832.2 (Valid up to 120ºC)
2.2 Input Data
Nominal Pipe Size
NPS =
Pipe Outside Diameter
D=
168.30
6
mm
Internal Design gage Pressure
Pi =
240
barg
Maximum Operating Temperature
T2,MAX =
84
ºC
Minimum Operating Temperature
T2,MIN =
-10
ºC
Installation Temperature
T1 =
21
ºC
Design Factor
F=
0.6
Corrosion Allowance
Ca =
Water Density
rwater
3
External Force Axial Component (if any)
Fx =
0
Fatigue factor
f=
1
=
1000
in
mm
3
kg/m
N
0.33SuT at the minimum installed or operating temperature
Scold
171.60
MPa
0.33SuT at the maximum installed or operating temperature
Shot
171.60
MPa
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
Note (1)
Attachment - Wall Thickness Calculation - Stress Check
3.0 EQUATIONS
Equation
Unit
Eq. No.
Notes
Maximum Allowable Hoop Stress
SH,ALL = F.E.T.SY
[Mpa]
(1)
Ref. (1) Para. 841.1.1
Max Allowable Expansion Stress
SE,ALL = f[1.25(Scold+Shot)-SL]
[Mpa]
(2)
Ref. (1) Para. 833.8 (b)
Max Allowable Longitudinal Stress (See Note 2)
SL,ALL = 75%.SYT
[Mpa]
(3)
Ref. (1) Para. 833.6 (b)
Hoop Stress
SH = Pi.D / 20.tmin
[Mpa]
(6)
Ref. (1) Para. 805.2.3
Longitudinal Stress due to Internal Pressure
SL,P =
[Mpa]
(7)
Ref. (1) Para. 833.2 (a)
Expansion Stress
SE= ME/Z
[Mpa]
(8)
Ref. (1) Para. 833.8 (a)
Longitudinal Stress due to Axial Loading
Sx = Fx / A
[Mpa]
(10)
Ref. (1) Para. 833.2 (f)
Bending Stress (Tension)
SBT = iM / Z
[Mpa]
(11)
Ref. (1) Para. 833.2 (d)
Bending Stress (Compression)
SBC= -iM / Z
[Mpa]
(12)
Ref. (1) Para. 833.2 (d)
Longitudinal Stress (Sustained Loads): Case 1
SL1=ST1 + SL,P + SBT + Sx
[Mpa]
(13)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 2
SL2=ST1 + SL,P + SBC + Sx
[Mpa]
(14)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 3
SL3=ST2 + SL,P + SBT + Sx
[Mpa]
(15)
Ref. (1) Para. 833.3 (a)
Longitudinal Stress (Sustained Loads): Case 4
SL4=ST2 + SL,P + SBC + Sx
[Mpa]
(16)
Ref. (1) Para. 833.3 (a)
3.1 Stresss
3.1.1 Maximum Allowable (due to Code)
3.1.2 Stresses
0.5.SH
3.1.3 Ratios
Ratio to SMYS
SMYS % = SH / SY
[%]
(20)
Ratio of calculated to Allowable (Hoop)
%H = SH / SH,ALL
[%]
(21)
Ratio of calculated to Allowable (Longitudinal)
%L = SL / SL,ALL
[%]
(22)
3.2 Wall Thickness
Calculated wall thickness
t =Pi.D / 20.SH,ALL
[mm]
(25)
Calculated wall thickness with corrosion allowance
tn = t + Ca
[mm]
(26)
Selected wall thickness
ts > tn
[mm]
(27)
Minimum wall thickness
tmin = ts - Ca
[mm]
(28)
[mm]
(29)
Ref. (1) Para. 841.1.1
Ref. (2) Table 1
3.3 Pipeline Properties
Internal Diameter of the Pipe
Din = D-2tmin
Pipe moment of Inertia
I=
Pipe section modulus
Z=2*I/D
Pipe Metal Cross Section Area
4
p (D
A=
4
- Din ) /64
2
p (D
-
2
Din )
/4
4
[m ]
(30)
3
[cm ]
(31)
2
[mm ]
(32)
3.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1= T1 - T2,MAX
[ºC]
(33)
Ref. (1) Para. 833.2 (c)
Temperature Difference: Case 2
ΔTCase2= T1 - T2,MIN
[ºC]
(34)
Ref. (1) Para. 833.2 (c)
[N.m]
(35)
[-]
(43)
3.5 Bending Moment
Bending Moment
M=Es.I/R
3.7 Stress Intensification Factor
Stress Intensification Factor
Doc. No.: 4148-DGTYP-7-17-0001
i=1
Attachment-4
Note (3)
Attachment - Wall Thickness Calculation - Stress Check
4.0 CALCULATIONS
4.1 Maximum Allowable (due to Code)
Maximum Allowable Hoop Stress
SH,ALL =
249.00
MPa
[Eq. (1)]
Max Allowable Expansion Stress
SE,ALL =
117.75
MPa
[Eq. (2)]
Max Allowable Longitudinal Stress (See Note (3))
SL,ALL =
311.25
MPa
[Eq. (3)]
4.2 Wall Thickness
Calculated wall thickness
t=
8.11
mm
[Eq. (25)]
Calculated wall thickness with corrosion allowance
tn =
11.11
mm
[Eq. (26)]
Selected wall thickness
ts =
12.7
mm
[Eq. (27)]
Minimum wall thickness
tmin =
9.70
mm
[Eq. (28)]
Check Acceptability:
If tn<ts, selected wall thickness is accepted
Accepted
4.2.1 D/t ratio for constructability and handing evaluation
D / ts =
13.25
Note (4)
4.3 Pipeline Properties
Internal Diameter
Din =
Pipe moment of Inertia
I=
0.000015
Pipe section modulus
Z=
181.26
cm
Pipe Metal Cross Section Area
A=
4833.09
mm
[Eq. (32)]
148.90
mm
[Eq. (29)]
4
[Eq. (30)]
m
3
[Eq. (31)]
2
4.4 Temperature Changes
Temperature Difference: Case 1
ΔTCase1=
-63
ºC
[Eq. (33)]
Temperature Difference: Case 2
ΔTCase2=
31
ºC
[Eq. (34)]
1.23E+04
N.m
[Eq. (35)]
4.5 Bending Moment
Bending Moment
M=
4.6 Pipeline Stresses
4.6.1 Hoop Stress
Hoop Stress
SH =
208.21
MPa
Ratio to SMYS
SMYS %=
50.17%
%
[Eq. (20)]
Ratio of calculated to Allowable (Hoop)
%H =
83.62%
%
[Eq. (21)]
If SH<SH,ALL, selected wall thickness is acceptable
Check Acceptability:
[Eq. (6)]
Accepted
Ref. (1) Para.841.1.1
4.6.2 Expansion Stress
Expansion Stress
SE=
67.88
MPa
Check Acceptability:
If SE<SE.ALL, selected wall thickness is acceptable
[Eq. (8)]
Accepted
Longitudinal Stress due to Internal Pressure
SL,P =
62.46
MPa
[Eq. (7)]
Bending Stress (Tension)
SBT =
67.88
MPa
[Eq. (11)]
Bending Stress (Compression)
SBC=
-67.88
MPa
[Eq. (12)]
Longitudinal Stress due to Axial Loading
Sx=
0.00
Mpa
[Eq. (10)]
Longitudinal Stress (Sustained Loads): Case 1
SL1=
198.2
Mpa
[Eq. (13)]
Ratio of calculated to Allowable (Longitudinal)
%L1 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 2
SL2=
Mpa
[Eq. (14)]
Ratio of calculated to Allowable (Longitudinal)
%L2 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 3
SL3=
Mpa
[Eq. (15)]
Ratio of calculated to Allowable (Longitudinal)
%L3 =
%
[Eq. (22)]
Longitudinal Stress (Sustained Loads): Case 4
SL4=
Mpa
[Eq. (16)]
Ratio of calculated to Allowable (Longitudinal)
%L4 =
%
[Eq. (22)]
(1) Four cases of evaluation
62.5
20.07%
130.3
41.88%
-5.4
1.74%
Check Acceptability:
If all ǀSLǀ<SL,ALL, selected wall thickness is acceptable
Doc. No.: 4148-DGTYP-7-17-0001
63.69%
Attachment-4
Accepted
Ref. (1) Para. 833.3
Attachment - Wall Thickness Calculation - Stress Check
5.0 RESULTS SUMMARY
5.1 Results
5.1.1 Wall Thickness
t=
8.11
mm
ts =
12.70
mm
D/t=
13.25
Calculated Wall Thickness
Selected Wall Thickness
D to t Ratio
5.1.2 Calculated Stress Values
Max
Ratio of calculated to
Stress
Unit
Hoop (SH)
Mpa
249.00
208.21
83.62%
OK
Mpa
117.75
67.88
57.65%
OK
Mpa
311.25
-5.4
1.74%
OK
Allowable
Calculated Value
allowable
Check
Thermal Expansion
(SE)
Worst Case Scenario
Longitudinal (SL)
Worst Case Scenario
OVERALL CHECK OF WALL THICKNESS
5.2 Notes
(1) Not Applicable for A/G Pipeline.
(2) Applied for sustained loads.
(3) Stress intensification factor equals 1 for straight pipe Table E-1 of ASME B31.8.
(4) Minimum wall thickness of pipe shall not be less than 4.8mm as per section 8.5 of QP standard QP STD-L017 Rv1.
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-4
ACCEPTED
PIPELINE DESIGN REPORT
5.5
Attachment 5: API RP 1102 Calculation
Doc No.
4148-DGTYP-7-17-0001
Rev.:
Date:
Page
C
12/10/2021
26 of 26
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Oil Flow line
Linepipe Material
API5L
Grade
X60
Pipe Nominal Diameter
Pipe Outside Diameter
6
D
Pipe Nom. Thickness
Maximum Operating Pressure
P
SMYS of linepipe material
Pipeline Design Factor
Longitudinal Joint Factor
Temperature Derating Factor
mm
7.11
mm
110.3
barg
60000
DF
0.6
E
1.0
Corrosion Allowance
DF Max. Allowable Effective Stress
168.28
Fa
T
6.63
in
1599.769
psi
psi
Refer to API 5L Table 7
ASME B31.4 Section 403.2.1
ASME B31.4 Table 403.2.1-1, for SMLS
3.0
mm
0.90
ASME B31.4 Table 403.3.1-1 (Due to combined stress )
1.0
Design Temperature
T2
140.0
deg F
60
degC
Installation Backfill Temperature
Corroded Wall Thickness
T1
tW
69.8
4.11
deg F
degC
mm
21
0.162
Depth of Pipe Cover
H
1200
mm
47.244
in
Bored Diameter of crossing
Bd
168.3
mm
6.625
in
Modulus of Soil Reaction
E'
0.5
ksi
Cl 4.7.2.1 API 1102
Resilient Modulus of soil
Er
10.0
ksi
Cl 4.7.2.2.3 API 1102 Figure-8 Table A-2
Soil Unit Weight-
Y
120
lb/ft3
0.0694
Poisson's Ratio
v
0.3
Pavement Type
In
lb/in3
Cl 4.7.2.1 API 1102
Flexible pavement
a) Expected stress on pipeline
Check Barlow Stress (Shi)
Cl 2.2 - Eq. 8 a API 1102
Shi = (PxD)/(2xtW)
32,751 psi
Allowable stress -DFxExTxSMYS
36,000 psi
Shi< Allowable
OK
b) Circumferential Stress Due to Earth Load (She)
Cl 2.2 - Eq. 1 API 1102
tW/D
0.0244
Khe(Earth load stiffness factor)
2155.73
H/Bd
7.13
Figure 3 - API 1102
Figure 4(soil type A) -
Be (Burial factor for circumferential
API 1102
stress from earth load)
1.22
Bd/D
1.00
Ee
0.82
SHe
=KHexBexEexYxD
989
Figure 5
Cl 2.2 - Eq. 1 API 1102
Psi
c) Impact factor F1 and Applied design Surface pressure
As per Table 1 of API-1102, for the following Conditions
H < 1.2m
D >= 305mm,Tandem axles load is the critical axle configuration for flexible pavement.
Single Axle Loads
30.00
ton
(Section 8.8.5 of QP-STD-L-017)
Pt = wheel load
10
ton
(Section 8.8.5 of QP-STD-L-017)
22046.20
lbs
47.24
in
3.940
Feet
Burial Depth
Impact Factor Fi @3.94feet
1.40
Figure 7 - API 1102
Contact area overwhich the wheel
load is applied (Ap)
Doc. No.: 4148-DGTYP-7-17-0001
144.00
Attachment-5
sq.in
Cl 4.7.2.2.1 - Eq. 2 API 1102
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Applied Design Surface Pressure(w)
w = Pt/Ap
153.10
PSI
d) Cyclic Circumfrential Stresses (dSHh)
dSHh = KHh x GHh x R x L x Fi x w
Cl 4.7.2.2.4 - Eq. 5 API 1102
for
tW/D
Er
KHh =
0.024
10
ksi
12.80
Figure 14 - API 1102
for
D
6.63
in
H
47.2
in
3.937
ft
GHh =
1.45
Figure 15 - API 1102
Single Axle R =
1.00
Table 2-API 1102
Single Axle L =
0.75
Table 2-API 1102
For FLEXIBLE PAVEMENT
dSHh
2,976 psi
e) Cyclic Longitudinal Stress (dSLh)
dSLh = KLh x GLh x R x L x Fi x w
Cl 4.7.2.2.4.2 - Eq. 6 API 1102
for
tW / D
Er
0.024
10
ksi
KLh
9.26
D
6.63
in
H
47.24
in
3.94
ft
Figure 16 - API 1102
for
GLh
1.49
Figure 17 - API 1102
Single Axle R =
1.00
Table 2 - API 1102
Single Axle L =
0.75
Table 2 - API 1102
For FLEXIBLE PAVEMENT
dSLh =
2,221 psi
f) Circumfrential Stress due to Internal Pressure, SHi
SHi = P x (D-tW) / (2 x tW)
Cl 4.7.3 Eq.7 - API 1102
p
1599.769
psi
D
6.62519685
in
tW
0.162
in
SHi =
Doc. No.: 4148-DGTYP-7-17-0001
31,951 psi
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
g) Principal Stresses S1,S2,S3
Young's Modulus of Steel , Es =
2.88E+07
Psi
Co-eff. Of thermal expn. ,
6.5E-06
per ºF
t =
Poisson's Ratio, Vs
= 0.3
S1=SHe+dSHh+SHi
35915.82 psi
Cl 4.8.1.2 Eq-9 - API 1102
S2 = dSLh– Esα(T2-T1) + Vs(SHe + SHi)
-1038.37 psi
Cl 4.8.1.2 Eq-10 - API 1102
S3 = -1 x p
Cl 4.8.1.2 Eq-11 - API 1102
S3 =
-1599.77 psi
Effective Stress Value
Seff = SQRT(0.5*[S1-S2]^2 + [S2-S3]^2 + [S3-S2]^2)
Seff
26,137 psi
Allowable Effective Stress = Fa x SMYS
Ratio of Seff / Allowable
Cl 4.8.1.2 Eq-12 - API 1102
54,000 psi
=
OK
0.48
No overstressing occurs
h) Check Weld Fatigue
Girth Weld
Design Factor
0.6
Fatigue Endurance in Girth Weld S fg =
12000.00
Allowable Sfg = Sfg x DF
(Refer Eq. 17)
psi
(From table 3 of API 1102)
7200 psi
Check dSlh < = Sfg x DF
Ratio of Actual dSlh / Allowable
0.308
OK
Longitudinal Weld endurance Limit (Sfl)
23000.00
Allowable Sfl = Sfl x DF
Refer Eq. 18
No overstressing occurs
psi
(From table 3 of API 1102)
13800 psi
Check dSHh < = Sfl x DF
Ratio of Actual dSHh / Allowable Sfl
0.22
OK
Summary
Calculated
Allowable
Stress
Stress (PSI)
(PSI)
No overstressing occurs
Factor of
safety
(FOS)
1.Barlow Stress Check
32,751
36,000
1.1
2.Principal Stresses (Seff)
26,137
54,000
2.1
3.Girt Weld Fatigue Check
2,221
7,200
3.2
4.Longitudinal Weld Fatigue Check
2,976
13,800
4.6
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Gas lift flowline
Linepipe Material
API5L
Grade
X65
Pipe Nominal Diameter
Pipe Outside Diameter
3
D
Pipe Nom. Thickness
Maximum Operating Pressure
P
SMYS of linepipe material
Pipeline Design Factor
Longitudinal Joint Factor
Temperature Derating Factor
mm
5.49
mm
142.58
barg
65000
DF
0.6
E
1.0
Corrosion Allowance
DF Max. Allowable Effective Stress
88.9
Fa
T
3.50
in
2067.952
psi
psi
ASME B31.8 AppendixD
ASME B31.8 Table 841.1.6.2
ASME B31.8 Table 841.1.7.2
3.0
mm
0.90
ASME B31.8 Section 833.3 (Due to combined stress )
1.0
Design Temperature
T2
140.0
deg F
60
degC
Installation Backfill Temperature
Corroded Wall Thickness
T1
tW
69.8
2.49
deg F
degC
mm
21
0.098
Depth of Pipe Cover
H
1200
mm
47.244
in
Bored Diameter of crossing
Bd
88.9
mm
3.500
in
Modulus of Soil Reaction
E'
0.5
ksi
Cl 4.7.2.1 API 1102
Resilient Modulus of soil
Er
10.0
ksi
Cl 4.7.2.2.3 API 1102 Figure-8 Table A-2
Soil Unit Weight-
Y
120
lb/ft3
0.0694
Poisson's Ratio
v
0.3
Pavement Type
In
lb/in3
Cl 4.7.2.1 API 1102
Flexible pavement
a) Expected stress on pipeline
Check Barlow Stress (Shi)
Cl 2.2 - Eq. 8 a API 1102
Shi = (PxD)/(2xtW)
36,916 psi
Allowable stress -DFxExTxSMYS
39,000 psi
Shi< Allowable
OK
b) Circumferential Stress Due to Earth Load (She)
Cl 2.2 - Eq. 1 API 1102
tW/D
0.0280
Khe(Earth load stiffness factor)
1645.0
H/Bd
13.50
Figure 3 - API 1102
Figure 4(soil type A) -
Be (Burial factor for circumferential
API 1102
stress from earth load)
1.36
Bd/D
1.00
Ee
0.82
SHe
=KHexBexEexYxD
445
Figure 5
Cl 2.2 - Eq. 1 API 1102
Psi
c) Impact factor F1 and Applied design Surface pressure
As per Table 1 of API-1102, for the following Conditions
H < 1.2m
D >= 305mm,Tandem axles load is the critical axle configuration for flexible pavement.
Single Axle Loads
30.00
ton
(Section 8.8.5 of QP-STD-L-017)
Pt = wheel load
10
ton
(Section 8.8.5 of QP-STD-L-017)
22046.20
lbs
47.24
in
3.940
Feet
Burial Depth
Impact Factor Fi @3.94feet
1.40
Figure 7 - API 1102
Contact area overwhich the wheel
load is applied (Ap)
Doc. No.: 4148-DGTYP-7-17-0001
144.00
Attachment-5
sq.in
Cl 4.7.2.2.1 - Eq. 2 API 1102
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Applied Design Surface Pressure(w)
w = Pt/Ap
153.10
PSI
d) Cyclic Circumfrential Stresses (dSHh)
dSHh = KHh x GHh x R x L x Fi x w
Cl 4.7.2.2.4 - Eq. 5 API 1102
for
tW/D
Er
KHh =
0.028
10
ksi
11.15
Figure 14 - API 1102
for
D
3.50
in
H
47.2
in
3.937
ft
GHh =
1.47
Figure 15 - API 1102
Single Axle R =
1.00
Table 2-API 1102
Single Axle L =
0.75
Table 2-API 1102
For FLEXIBLE PAVEMENT
dSHh
2,638 psi
e) Cyclic Longitudinal Stress (dSLh)
dSLh = KLh x GLh x R x L x Fi x w
Cl 4.7.2.2.4.2 - Eq. 6 API 1102
for
tW / D
Er
KLh
0.028
10
ksi
8.81
Figure 16 - API 1102
for
D
3.500
in
H
47.2
in
3.937
ft
GLh
1.95
Figure 17 - API 1102
Single Axle R =
1.00
Table 2 - API 1102
Single Axle L =
0.75
Table 2 - API 1102
For FLEXIBLE PAVEMENT
dSLh =
2,754 psi
f) Circumfrential Stress due to Internal Pressure, SHi
SHi = P x (D-tW) / (2 x tW)
Cl 4.7.3 Eq.7 - API 1102
p
2067.952
psi
D
3.5
in
tW
0.098
in
SHi =
Doc. No.: 4148-DGTYP-7-17-0001
35,882 psi
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
g) Principal Stresses S1,S2,S3
Young's Modulus of Steel , Es =
2.88E+07
Psi
Co-eff. Of thermal expn. ,
6.5E-06
per ºF
t =
Poisson's Ratio, Vs
= 0.3
S1=SHe+dSHh+SHi
38964.45 psi
S2 = dSLh– Esα(T2-T1) + Vs(SHe + SHi)
Cl 4.8.1.2 Eq-9 - API 1102
510.75 psi
Cl 4.8.1.2 Eq-10 - API 1102
S3 = -1 x p
Cl 4.8.1.2 Eq-11 - API 1102
S3 =
-2067.95 psi
Effective Stress Value
Seff = SQRT(0.5*[S1-S2]^2 + [S2-S3]^2 + [S3-S2]^2)
Seff
27,313 psi
Allowable Effective Stress = Fa x SMYS
Ratio of Seff / Allowable
Cl 4.8.1.2 Eq-12 - API 1102
58,500 psi
=
OK
0.47
No overstressing occurs
h) Check Weld Fatigue
Girth Weld
Design Factor
0.6
Fatigue Endurance in Girth Weld S fg =
12000.00
Allowable Sfg = Sfg x DF
(Refer Eq. 17)
psi
(From table 3 of API 1102)
7200 psi
Check dSlh < = Sfg x DF
Ratio of Actual dSlh / Allowable
0.383
OK
Longitudinal Weld endurance Limit (Sfl)
23000.00
Allowable Sfl = Sfl x DF
Refer Eq. 18
No overstressing occurs
psi
(From table 3 of API 1102)
13800 psi
Check dSHh < = Sfl x DF
Ratio of Actual dSHh / Allowable Sfl
0.19
OK
Summary
Calculated
Allowable
Stress
Stress (PSI)
(PSI)
No overstressing occurs
Factor of
safety
(FOS)
1.Barlow Stress Check
36,916
39,000
1.1
2.Principal Stresses (Seff)
27,313
58,500
2.1
3.Girt Weld Fatigue Check
2,754
7,200
2.6
4.Longitudinal Weld Fatigue Check
2,638
13,800
5.2
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
PWI flowline
Linepipe Material
API5L
Grade
X60
Pipe Nominal Diameter
Pipe Outside Diameter
4
D
Pipe Nom. Thickness
Maximum Operating Pressure
P
SMYS of linepipe material
Pipeline Design Factor
Longitudinal Joint Factor
Temperature Derating Factor
mm
7.14
mm
139.62
barg
60000
DF
0.6
E
1.0
Corrosion Allowance
DF Max. Allowable Effective Stress
114.3
Fa
T
4.50
in
2025.021
psi
psi
Refer to API 5L Table 7
ASME B31.4 Section 403.2.1
ASME B31.4 Table 403.2.1-1, for SMLS
3.0
mm
0.90
ASME B31.4 Table 403.3.1-1 (Due to combined stress )
1.0
Design Temperature
T2
140.0
deg F
60
degC
Installation Backfill Temperature
Corroded Wall Thickness
T1
tW
69.8
4.14
deg F
degC
mm
21
0.163
Depth of Pipe Cover
H
1200
mm
47.244
in
Bored Diameter of crossing
Bd
114.3
mm
4.500
in
Modulus of Soil Reaction
E'
0.5
ksi
Cl 4.7.2.1 API 1102
Resilient Modulus of soil
Er
10.0
ksi
Cl 4.7.2.2.3 API 1102 Figure-8 Table A-2
Soil Unit Weight-
Y
120
lb/ft3
0.0694
Poisson's Ratio
v
0.3
Pavement Type
In
lb/in3
Cl 4.7.2.1 API 1102
Flexible pavement
a) Expected stress on pipeline
Check Barlow Stress (Shi)
Cl 2.2 - Eq. 8 a API 1102
Shi = (PxD)/(2xtW)
27,954 psi
Allowable stress -DFxExTxSMYS
36,000 psi
Shi< Allowable
OK
b) Circumferential Stress Due to Earth Load (She)
Cl 2.2 - Eq. 1 API 1102
tW/D
0.0362
Khe(Earth load stiffness factor)
1062.67
H/Bd
10.50
Figure 3 - API 1102
Figure 4(soil type A) -
Be (Burial factor for circumferential
API 1102
stress from earth load)
1.32
Bd/D
1.00
Ee
0.82
SHe
=KHexBexEexYxD
359
Figure 5
Cl 2.2 - Eq. 1 API 1102
Psi
c) Impact factor F1 and Applied design Surface pressure
As per Table 1 of API-1102, for the following Conditions
H < 1.2m
D >= 305mm,Tandem axles load is the critical axle configuration for flexible pavement.
Single Axle Loads
30.00
ton
(Section 8.8.5 of QP-STD-L-017)
Pt = wheel load
10
ton
(Section 8.8.5 of QP-STD-L-017)
22046.20
lbs
47.24
in
3.940
Feet
Burial Depth
Impact Factor Fi @3.94feet
1.40
Figure 7 - API 1102
Contact area overwhich the wheel
load is applied (Ap)
Doc. No.: 4148-DGTYP-7-17-0001
144.00
Attachment-5
sq.in
Cl 4.7.2.2.1 - Eq. 2 API 1102
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Applied Design Surface Pressure(w)
w = Pt/Ap
153.10
PSI
d) Cyclic Circumfrential Stresses (dSHh)
dSHh = KHh x GHh x R x L x Fi x w
Cl 4.7.2.2.4 - Eq. 5 API 1102
for
tW/D
Er
0.036
10
ksi
KHh =
8.38
D
4.50
in
H
47.2
in
3.937
ft
Figure 14 - API 1102
for
GHh =
1.48
Figure 15 - API 1102
Single Axle R =
1.00
Table 2-API 1102
Single Axle L =
0.75
Table 2-API 1102
For FLEXIBLE PAVEMENT
dSHh
1,988 psi
e) Cyclic Longitudinal Stress (dSLh)
dSLh = KLh x GLh x R x L x Fi x w
Cl 4.7.2.2.4.2 - Eq. 6 API 1102
for
tW / D
Er
KLh
0.036
10
ksi
7.37
Figure 16 - API 1102
for
D
4.500
in
H
47.2
in
3.937
ft
GLh
1.78
Figure 17 - API 1102
Single Axle R =
1.00
Table 2 - API 1102
Single Axle L =
0.75
Table 2 - API 1102
For FLEXIBLE PAVEMENT
dSLh =
2,104 psi
f) Circumfrential Stress due to Internal Pressure, SHi
SHi = P x (D-tW) / (2 x tW)
Cl 4.7.3 Eq.7 - API 1102
p
2025.021
psi
D
4.5
in
tW
0.163
in
SHi =
Doc. No.: 4148-DGTYP-7-17-0001
26,942 psi
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
g) Principal Stresses S1,S2,S3
Young's Modulus of Steel , Es =
2.88E+07
Psi
Co-eff. Of thermal expn. ,
6.5E-06
per ºF
t =
Poisson's Ratio, Vs
= 0.3
S1=SHe+dSHh+SHi
29289.12 psi
Cl 4.8.1.2 Eq-9 - API 1102
S2 = dSLh– Esα(T2-T1) + Vs(SHe + SHi)
-2847.53 psi
Cl 4.8.1.2 Eq-10 - API 1102
S3 = -1 x p
Cl 4.8.1.2 Eq-11 - API 1102
S3 =
-2025.02 psi
Effective Stress Value
Seff = SQRT(0.5*[S1-S2]^2 + [S2-S3]^2 + [S3-S2]^2)
Seff
22,739 psi
Allowable Effective Stress = Fa x SMYS
Ratio of Seff / Allowable
Cl 4.8.1.2 Eq-12 - API 1102
54,000 psi
=
OK
0.42
No overstressing occurs
h) Check Weld Fatigue
Girth Weld
Design Factor
0.6
Fatigue Endurance in Girth Weld S fg =
12000.00
Allowable Sfg = Sfg x DF
(Refer Eq. 17)
psi
(From table 3 of API 1102)
7200 psi
Check dSlh < = Sfg x DF
Ratio of Actual dSlh / Allowable
0.292
OK
Longitudinal Weld endurance Limit (Sfl)
23000.00
Allowable Sfl = Sfl x DF
Refer Eq. 18
No overstressing occurs
psi
(From table 3 of API 1102)
13800 psi
Check dSHh < = Sfl x DF
Ratio of Actual dSHh / Allowable Sfl
0.14
OK
Summary
Calculated
Allowable
Stress
Stress (PSI)
(PSI)
No overstressing occurs
Factor of
safety
(FOS)
1.Barlow Stress Check
27,954
36,000
1.3
2.Principal Stresses (Seff)
22,739
54,000
2.4
3.Girt Weld Fatigue Check
2,104
7,200
3.4
4.Longitudinal Weld Fatigue Check
1,988
13,800
6.9
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Source well flowline
Linepipe Material
API5L
Grade
X60
Pipe Nominal Diameter
Pipe Outside Diameter
8
D
Pipe Nom. Thickness
Maximum Operating Pressure
P
SMYS of linepipe material
Pipeline Design Factor
Longitudinal Joint Factor
Temperature Derating Factor
mm
5.56
mm
43.40
barg
60000
DF
0.6
E
1.0
Corrosion Allowance
DF Max. Allowable Effective Stress
219.1
Fa
T
8.63
in
629.465
psi
psi
Refer to API 5L Table 7
ASME B31.4 Section 403.2.1
ASME B31.4 Table 403.2.1-1, for SMLS
3.0
mm
0.90
ASME B31.4 Table 403.3.1-1 (Due to combined stress )
1.0
Design Temperature
T2
140.0
deg F
60
degC
Installation Backfill Temperature
Corroded Wall Thickness
T1
tW
69.8
2.56
deg F
degC
mm
21
0.101
Depth of Pipe Cover
H
1200
mm
47.244
in
Bored Diameter of crossing
Bd
219.1
mm
8.625
in
Modulus of Soil Reaction
E'
0.5
ksi
Cl 4.7.2.1 API 1102
Resilient Modulus of soil
Er
10.0
ksi
Cl 4.7.2.2.3 API 1102 Figure-8 Table A-2
Soil Unit Weight-
Y
120
lb/ft3
0.0694
Poisson's Ratio
v
0.3
Pavement Type
In
lb/in3
Cl 4.7.2.1 API 1102
Flexible pavement
a) Expected stress on pipeline
Check Barlow Stress (Shi)
Cl 2.2 - Eq. 8 a API 1102
Shi = (PxD)/(2xtW)
26,934 psi
Allowable stress -DFxExTxSMYS
36,000 psi
Shi< Allowable
OK
b) Circumferential Stress Due to Earth Load (She)
Cl 2.2 - Eq. 1 API 1102
tW/D
0.0117
Khe(Earth load stiffness factor)
5904.51
H/Bd
5.48
Figure 3 - API 1102
Figure 4(soil type A) -
Be (Burial factor for circumferential
API 1102
stress from earth load)
1.11
Bd/D
1.00
Ee
0.82
SHe
=KHexBexEexYxD
3202
Figure 5
Cl 2.2 - Eq. 1 API 1102
Psi
c) Impact factor F1 and Applied design Surface pressure
As per Table 1 of API-1102, for the following Conditions
H < 1.2m
D >= 305mm,Tandem axles load is the critical axle configuration for flexible pavement.
Single Axle Loads
30.00
ton
(Section 8.8.5 of QP-STD-L-017)
Pt = wheel load
10
ton
(Section 8.8.5 of QP-STD-L-017)
22046.20
lbs
47.24
in
3.940
Feet
Burial Depth
Impact Factor Fi @3.94feet
1.40
Figure 7 - API 1102
Contact area overwhich the wheel
load is applied (Ap)
Doc. No.: 4148-DGTYP-7-17-0001
144.00
Attachment-5
sq.in
Cl 4.7.2.2.1 - Eq. 2 API 1102
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Applied Design Surface Pressure(w)
w = Pt/Ap
153.10
PSI
d) Cyclic Circumfrential Stresses (dSHh)
dSHh = KHh x GHh x R x L x Fi x w
Cl 4.7.2.2.4 - Eq. 5 API 1102
for
tW/D
Er
KHh =
0.012
10
ksi
14.16
Figure 14 - API 1102
for
D
8.63
in
H
47.2
in
3.937
ft
GHh =
1.37
Figure 15 - API 1102
Single Axle R =
1.00
Table 2-API 1102
Single Axle L =
0.75
Table 2-API 1102
For FLEXIBLE PAVEMENT
dSHh
3,118 psi
e) Cyclic Longitudinal Stress (dSLh)
dSLh = KLh x GLh x R x L x Fi x w
Cl 4.7.2.2.4.2 - Eq. 6 API 1102
for
tW / D
Er
0.012
10
ksi
KLh
9.99
D
8.63
in
H
47.2
in
3.937
ft
Figure 16 - API 1102
for
GLh
1.30
Figure 17 - API 1102
Single Axle R =
1.00
Table 2 - API 1102
Single Axle L =
0.75
Table 2 - API 1102
For FLEXIBLE PAVEMENT
dSLh =
2,092 psi
f) Circumfrential Stress due to Internal Pressure, SHi
SHi = P x (D-tW) / (2 x tW)
Cl 4.7.3 Eq.7 - API 1102
p
629.465
psi
D
8.62519685
in
tW
0.101
in
SHi =
Doc. No.: 4148-DGTYP-7-17-0001
26,619 psi
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
g) Principal Stresses S1,S2,S3
Young's Modulus of Steel , Es =
2.88E+07
Psi
Co-eff. Of thermal expn. ,
6.5E-06
per ºF
t =
Poisson's Ratio, Vs
= 0.3
S1=SHe+dSHh+SHi
32939.90 psi
Cl 4.8.1.2 Eq-9 - API 1102
S2 = dSLh– Esα(T2-T1) + Vs(SHe + SHi)
-2102.50 psi
Cl 4.8.1.2 Eq-10 - API 1102
S3 = -1 x p
Cl 4.8.1.2 Eq-11 - API 1102
S3 =
-629.46 psi
Effective Stress Value
Seff = SQRT(0.5*[S1-S2]^2 + [S2-S3]^2 + [S3-S2]^2)
Seff
24,823 psi
Allowable Effective Stress = Fa x SMYS
Ratio of Seff / Allowable
Cl 4.8.1.2 Eq-12 - API 1102
54,000 psi
=
OK
0.46
No overstressing occurs
h) Check Weld Fatigue
Girth Weld
Design Factor
0.6
Fatigue Endurance in Girth Weld S fg =
12000.00
Allowable Sfg = Sfg x DF
(Refer Eq. 17)
psi
(From table 3 of API 1102)
7200 psi
Check dSlh < = Sfg x DF
Ratio of Actual dSlh / Allowable
0.291
OK
Longitudinal Weld endurance Limit (Sfl)
23000.00
Allowable Sfl = Sfl x DF
Refer Eq. 18
No overstressing occurs
psi
(From table 3 of API 1102)
13800 psi
Check dSHh < = Sfl x DF
Ratio of Actual dSHh / Allowable Sfl
0.23
OK
Summary
Calculated
Allowable
Stress
Stress (PSI)
(PSI)
No overstressing occurs
Factor of
safety
(FOS)
1.Barlow Stress Check
26,934
36,000
1.3
2.Principal Stresses (Seff)
24,823
54,000
2.2
3.Girt Weld Fatigue Check
2,092
7,200
3.4
4.Longitudinal Weld Fatigue Check
3,118
13,800
4.4
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Recycle well flowline
Linepipe Material
API5L
Grade
X60
Pipe Nominal Diameter
Pipe Outside Diameter
8
D
Pipe Nom. Thickness
Maximum Operating Pressure
P
SMYS of linepipe material
Pipeline Design Factor
Longitudinal Joint Factor
Temperature Derating Factor
mm
4.80
mm
16.90
barg
60000
DF
0.6
E
1.0
Corrosion Allowance
DF Max. Allowable Effective Stress
219.1
Fa
T
8.63
in
245.114
psi
psi
Refer to API 5L Table 7
ASME B31.4 Section 403.2.1
ASME B31.4 Table 403.2.1-1, for SMLS
3.0
mm
0.90
ASME B31.4 Table 403.3.1-1 (Due to combined stress )
1.0
Design Temperature
T2
140.0
deg F
60
degC
Installation Backfill Temperature
Corroded Wall Thickness
T1
tW
69.8
1.80
deg F
degC
mm
21
0.071
Depth of Pipe Cover
H
1200
mm
47.244
in
Bored Diameter of crossing
Bd
219.1
mm
8.625
in
Modulus of Soil Reaction
E'
0.5
ksi
Cl 4.7.2.1 API 1102
Resilient Modulus of soil
Er
10.0
ksi
Cl 4.7.2.2.3 API 1102 Figure-8 Table A-2
Soil Unit Weight-
Y
120
lb/ft3
0.0694
Poisson's Ratio
v
0.3
Pavement Type
In
lb/in3
Cl 4.7.2.1 API 1102
Flexible pavement
a) Expected stress on pipeline
Check Barlow Stress (Shi)
Cl 2.2 - Eq. 8 a API 1102
Shi = (PxD)/(2xtW)
14,917 psi
Allowable stress -DFxExTxSMYS
36,000 psi
Shi< Allowable
OK
b) Circumferential Stress Due to Earth Load (She)
Cl 2.2 - Eq. 1 API 1102
tW/D
0.0082
Khe(Earth load stiffness factor)
7270.64
H/Bd
5.48
Figure 3 - API 1102
Figure 4(soil type A) -
Be (Burial factor for circumferential
API 1102
stress from earth load)
1.11
Bd/D
1.00
Ee
0.82
SHe
=KHexBexEexYxD
3943
Figure 5
Cl 2.2 - Eq. 1 API 1102
Psi
c) Impact factor F1 and Applied design Surface pressure
As per Table 1 of API-1102, for the following Conditions
H < 1.2m
D >= 305mm,Tandem axles load is the critical axle configuration for flexible pavement.
Single Axle Loads
30.00
ton
(Section 8.8.5 of QP-STD-L-017)
Pt = wheel load
10
ton
(Section 8.8.5 of QP-STD-L-017)
22046.20
lbs
47.24
in
3.940
Feet
Burial Depth
Impact Factor Fi @3.94feet
1.40
Figure 7 - API 1102
Contact area overwhich the wheel
load is applied (Ap)
Doc. No.: 4148-DGTYP-7-17-0001
144.00
Attachment-5
sq.in
Cl 4.7.2.2.1 - Eq. 2 API 1102
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Applied Design Surface Pressure(w)
w = Pt/Ap
153.10
PSI
d) Cyclic Circumfrential Stresses (dSHh)
dSHh = KHh x GHh x R x L x Fi x w
Cl 4.7.2.2.4 - Eq. 5 API 1102
for
tW/D
Er
KHh =
0.008
10
ksi
12.05
Figure 14 - API 1102
for
D
8.63
in
H
47.2
in
3.937
ft
GHh =
1.37
Figure 15 - API 1102
Single Axle R =
1.00
Table 2-API 1102
Single Axle L =
0.75
Table 2-API 1102
For FLEXIBLE PAVEMENT
dSHh
2,653 psi
e) Cyclic Longitudinal Stress (dSLh)
dSLh = KLh x GLh x R x L x Fi x w
Cl 4.7.2.2.4.2 - Eq. 6 API 1102
for
tW / D
Er
0.008
10
ksi
KLh
9.45
D
8.63
in
H
47.2
in
3.937
ft
Figure 16 - API 1102
for
GLh
1.30
Figure 17 - API 1102
Single Axle R =
1.00
Table 2 - API 1102
Single Axle L =
0.75
Table 2 - API 1102
For FLEXIBLE PAVEMENT
dSLh =
1,981 psi
f) Circumfrential Stress due to Internal Pressure, SHi
SHi = P x (D-tW) / (2 x tW)
Cl 4.7.3 Eq.7 - API 1102
p
245.114
psi
D
8.62519685
in
tW
0.071
in
SHi =
Doc. No.: 4148-DGTYP-7-17-0001
14,794 psi
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
g) Principal Stresses S1,S2,S3
Young's Modulus of Steel , Es =
2.88E+07
Psi
Co-eff. Of thermal expn. ,
6.5E-06
per ºF
t =
Poisson's Ratio, Vs
= 0.3
S1=SHe+dSHh+SHi
21390.36 psi
Cl 4.8.1.2 Eq-9 - API 1102
S2 = dSLh– Esα(T2-T1) + Vs(SHe + SHi)
-5539.31 psi
Cl 4.8.1.2 Eq-10 - API 1102
S3 = -1 x p
Cl 4.8.1.2 Eq-11 - API 1102
S3 =
-245.11 psi
Effective Stress Value
Seff = SQRT(0.5*[S1-S2]^2 + [S2-S3]^2 + [S3-S2]^2)
Seff
19,765 psi
Allowable Effective Stress = Fa x SMYS
Ratio of Seff / Allowable
Cl 4.8.1.2 Eq-12 - API 1102
54,000 psi
=
OK
0.37
No overstressing occurs
h) Check Weld Fatigue
Girth Weld
Design Factor
0.6
Fatigue Endurance in Girth Weld S fg =
12000.00
Allowable Sfg = Sfg x DF
(Refer Eq. 17)
psi
(From table 3 of API 1102)
7200 psi
Check dSlh < = Sfg x DF
Ratio of Actual dSlh / Allowable
0.275
OK
Longitudinal Weld endurance Limit (Sfl)
23000.00
Allowable Sfl = Sfl x DF
Refer Eq. 18
No overstressing occurs
psi
(From table 3 of API 1102)
13800 psi
Check dSHh < = Sfl x DF
Ratio of Actual dSHh / Allowable Sfl
0.19
OK
Summary
Calculated
Allowable
Stress
Stress (PSI)
(PSI)
No overstressing occurs
Factor of
safety
(FOS)
1.Barlow Stress Check
14,917
36,000
2.4
2.Principal Stresses (Seff)
19,765
54,000
2.7
3.Girt Weld Fatigue Check
1,981
7,200
3.6
4.Longitudinal Weld Fatigue Check
2,653
13,800
5.2
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Khuff Production flowline
Linepipe Material
API5L
Grade
X65
Pipe Nominal Diameter
Pipe Outside Diameter
6
D
Pipe Nom. Thickness
Maximum Operating Pressure
P
SMYS of linepipe material
Pipeline Design Factor
Longitudinal Joint Factor
Temperature Derating Factor
mm
14.27
mm
359.00
barg
65000
DF
0.6
E
1.0
Corrosion Allowance
DF Max. Allowable Effective Stress
168.28
Fa
T
6.63
in
5206.864
psi
psi
ASME B31.8 AppendixD
ASME B31.8 Table 841.1.6.2
ASME B31.8 Table 841.1.7.2
3.0
mm
0.90
ASME B31.8 Section 833.3 (Due to combined stress )
1.0
Design Temperature
T2
140.0
deg F
60
degC
Installation Backfill Temperature
Corroded Wall Thickness
T1
tW
69.8
11.27
deg F
degC
mm
21
0.444
Depth of Pipe Cover
H
1200
mm
47.244
in
Bored Diameter of crossing
Bd
168.3
mm
6.625
in
Modulus of Soil Reaction
E'
0.5
ksi
Cl 4.7.2.1 API 1102
Resilient Modulus of soil
Er
10.0
ksi
Cl 4.7.2.2.3 API 1102 Figure-8 Table A-2
Soil Unit Weight-
Y
120
lb/ft3
0.0694
Poisson's Ratio
v
0.3
Pavement Type
In
lb/in3
Cl 4.7.2.1 API 1102
Flexible pavement
a) Expected stress on pipeline
Check Barlow Stress (Shi)
Cl 2.2 - Eq. 8 a API 1102
Shi = (PxD)/(2xtW)
38,874 psi
Allowable stress -DFxExTxSMYS
39,000 psi
Shi< Allowable
OK
b) Circumferential Stress Due to Earth Load (She)
Cl 2.2 - Eq. 1 API 1102
tW/D
0.0670
Khe(Earth load stiffness factor)
347.58
H/Bd
7.13
Figure 3 - API 1102
Figure 4(soil type A) -
Be (Burial factor for circumferential
API 1102
stress from earth load)
1.22
Bd/D
1.00
Ee
0.82
SHe
=KHexBexEexYxD
159
Figure 5
Cl 2.2 - Eq. 1 API 1102
Psi
c) Impact factor F1 and Applied design Surface pressure
As per Table 1 of API-1102, for the following Conditions
H < 1.2m
D >= 305mm,Tandem axles load is the critical axle configuration for flexible pavement.
Single Axle Loads
30.00
ton
(Section 8.8.5 of QP-STD-L-017)
Pt = wheel load
10
ton
(Section 8.8.5 of QP-STD-L-017)
22046.20
lbs
47.24
in
3.940
Feet
Burial Depth
Impact Factor Fi @3.94feet
1.40
Figure 7 - API 1102
Contact area overwhich the wheel
load is applied (Ap)
Doc. No.: 4148-DGTYP-7-17-0001
144.00
Attachment-5
sq.in
Cl 4.7.2.2.1 - Eq. 2 API 1102
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Applied Design Surface Pressure(w)
w = Pt/Ap
153.10
PSI
d) Cyclic Circumfrential Stresses (dSHh)
dSHh = KHh x GHh x R x L x Fi x w
Cl 4.7.2.2.4 - Eq. 5 API 1102
for
tW/D
Er
0.067
10
ksi
KHh =
2.90
D
6.63
in
H
47.2
in
3.937
ft
Figure 14 - API 1102
for
GHh =
1.45
Figure 15 - API 1102
Single Axle R =
1.00
Table 2-API 1102
Single Axle L =
0.75
Table 2-API 1102
For FLEXIBLE PAVEMENT
dSHh
674 psi
e) Cyclic Longitudinal Stress (dSLh)
dSLh = KLh x GLh x R x L x Fi x w
Cl 4.7.2.2.4.2 - Eq. 6 API 1102
for
tW / D
Er
0.067
10
ksi
KLh
4.93
D
6.63
in
H
47.2
in
3.937
ft
Figure 16 - API 1102
for
GLh
1.49
Figure 17 - API 1102
Single Axle R =
1.00
Table 2 - API 1102
Single Axle L =
0.75
Table 2 - API 1102
For FLEXIBLE PAVEMENT
dSLh =
1,182 psi
f) Circumfrential Stress due to Internal Pressure, SHi
SHi = P x (D-tW) / (2 x tW)
Cl 4.7.3 Eq.7 - API 1102
p
5206.864
psi
D
6.62519685
in
tW
0.444
in
SHi =
Doc. No.: 4148-DGTYP-7-17-0001
36,270 psi
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
g) Principal Stresses S1,S2,S3
Young's Modulus of Steel , Es =
2.88E+07
Psi
Co-eff. Of thermal expn. ,
6.5E-06
per ºF
t =
Poisson's Ratio, Vs
= 0.3
S1=SHe+dSHh+SHi
37103.84 psi
Cl 4.8.1.2 Eq-9 - API 1102
S2 = dSLh– Esα(T2-T1) + Vs(SHe + SHi)
-1030.83 psi
Cl 4.8.1.2 Eq-10 - API 1102
S3 = -1 x p
Cl 4.8.1.2 Eq-11 - API 1102
S3 =
-5206.86 psi
Effective Stress Value
Seff = SQRT(0.5*[S1-S2]^2 + [S2-S3]^2 + [S3-S2]^2)
Seff
27,287 psi
Allowable Effective Stress = Fa x SMYS
Ratio of Seff / Allowable
Cl 4.8.1.2 Eq-12 - API 1102
58,500 psi
=
OK
0.47
No overstressing occurs
h) Check Weld Fatigue
Girth Weld
Design Factor
0.6
Fatigue Endurance in Girth Weld S fg =
12000.00
Allowable Sfg = Sfg x DF
(Refer Eq. 17)
psi
(From table 3 of API 1102)
7200 psi
Check dSlh < = Sfg x DF
Ratio of Actual dSlh / Allowable
0.164
OK
Longitudinal Weld endurance Limit (Sfl)
23000.00
Allowable Sfl = Sfl x DF
Refer Eq. 18
No overstressing occurs
psi
(From table 3 of API 1102)
13800 psi
Check dSHh < = Sfl x DF
Ratio of Actual dSHh / Allowable Sfl
0.05
OK
Summary
Calculated
Allowable
Stress
Stress (PSI)
(PSI)
No overstressing occurs
Factor of
safety
(FOS)
1.Barlow Stress Check
38,874
39,000
1.0
2.Principal Stresses (Seff)
27,287
58,500
2.1
1,182
7,200
674
13,800
3.Girt Weld Fatigue Check
4.Longitudinal Weld Fatigue Check
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-5
6.1
20.5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Khuff injection flowline
Linepipe Material
API5L
Grade
X65
Pipe Nominal Diameter
Pipe Outside Diameter
6
D
Pipe Nom. Thickness
Maximum Operating Pressure
P
SMYS of linepipe material
Pipeline Design Factor
Longitudinal Joint Factor
Temperature Derating Factor
mm
16.50
mm
368.60
barg
65000
DF
0.6
E
1.0
Corrosion Allowance
DF Max. Allowable Effective Stress
168.28
Fa
T
6.63
in
5346.101
psi
psi
ASME B31.8 AppendixD
ASME B31.8 Table 841.1.6.2
ASME B31.8 Table 841.1.7.2
3.0
mm
0.90
ASME B31.8 Section 833.3 (Due to combined stress )
1.0
Design Temperature
T2
140.0
deg F
60
degC
Installation Backfill Temperature
Corroded Wall Thickness
T1
tW
69.8
13.50
deg F
degC
mm
21
0.531
Depth of Pipe Cover
H
1200
mm
47.244
in
Bored Diameter of crossing
Bd
168.3
mm
6.625
in
Modulus of Soil Reaction
E'
0.5
ksi
Cl 4.7.2.1 API 1102
Resilient Modulus of soil
Er
10.0
ksi
Cl 4.7.2.2.3 API 1102 Figure-8 Table A-2
Soil Unit Weight-
Y
120
lb/ft3
0.0694
Poisson's Ratio
v
0.3
Pavement Type
In
lb/in3
Cl 4.7.2.1 API 1102
Flexible pavement
a) Expected stress on pipeline
Check Barlow Stress (Shi)
Cl 2.2 - Eq. 8 a API 1102
Shi = (PxD)/(2xtW)
33,320 psi
Allowable stress -DFxExTxSMYS
39,000 psi
Shi< Allowable
OK
b) Circumferential Stress Due to Earth Load (She)
Cl 2.2 - Eq. 1 API 1102
tW/D
0.0802
Khe(Earth load stiffness factor)
209.2
H/Bd
7.13
Figure 3 - API 1102
Figure 4(soil type A) -
Be (Burial factor for circumferential
API 1102
stress from earth load)
1.22
Bd/D
1.00
Ee
0.82
SHe
=KHexBexEexYxD
96
Figure 5
Cl 2.2 - Eq. 1 API 1102
Psi
c) Impact factor F1 and Applied design Surface pressure
As per Table 1 of API-1102, for the following Conditions
H < 1.2m
D >= 305mm,Tandem axles load is the critical axle configuration for flexible pavement.
Single Axle Loads
30.00
ton
(Section 8.8.5 of QP-STD-L-017)
Pt = wheel load
10
ton
(Section 8.8.5 of QP-STD-L-017)
22046.20
lbs
47.24
in
3.940
Feet
Burial Depth
Impact Factor Fi @3.94feet
1.40
Figure 7 - API 1102
Contact area overwhich the wheel
load is applied (Ap)
Doc. No.: 4148-DGTYP-7-17-0001
144.00
Attachment-5
sq.in
Cl 4.7.2.2.1 - Eq. 2 API 1102
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Applied Design Surface Pressure(w)
w = Pt/Ap
153.10
PSI
d) Cyclic Circumfrential Stresses (dSHh)
dSHh = KHh x GHh x R x L x Fi x w
Cl 4.7.2.2.4 - Eq. 5 API 1102
for
tW/D
Er
0.080
10
ksi
KHh =
2.01
D
6.63
in
H
47.2
in
3.937
ft
Figure 14 - API 1102
for
GHh =
1.43
Figure 15 - API 1102
Single Axle R =
1.00
Table 2-API 1102
Single Axle L =
0.75
Table 2-API 1102
For FLEXIBLE PAVEMENT
dSHh
463 psi
e) Cyclic Longitudinal Stress (dSLh)
dSLh = KLh x GLh x R x L x Fi x w
Cl 4.7.2.2.4.2 - Eq. 6 API 1102
for
tW / D
Er
0.080
10
ksi
KLh
4.74
D
6.63
in
H
47.2
in
3.937
ft
Figure 16 - API 1102
for
GLh
1.49
Figure 17 - API 1102
Single Axle R =
1.00
Table 2 - API 1102
Single Axle L =
0.75
Table 2 - API 1102
For FLEXIBLE PAVEMENT
dSLh =
1,137 psi
f) Circumfrential Stress due to Internal Pressure, SHi
SHi = P x (D-tW) / (2 x tW)
Cl 4.7.3 Eq.7 - API 1102
p
5346.101
psi
D
6.62519685
in
tW
0.531
in
SHi =
Doc. No.: 4148-DGTYP-7-17-0001
30,647 psi
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
g) Principal Stresses S1,S2,S3
Young's Modulus of Steel , Es =
2.88E+07
Psi
Co-eff. Of thermal expn. ,
6.5E-06
per ºF
t =
Poisson's Ratio, Vs
= 0.3
S1=SHe+dSHh+SHi
31206.16 psi
Cl 4.8.1.2 Eq-9 - API 1102
S2 = dSLh– Esα(T2-T1) + Vs(SHe + SHi)
-2781.97 psi
Cl 4.8.1.2 Eq-10 - API 1102
S3 = -1 x p
Cl 4.8.1.2 Eq-11 - API 1102
S3 =
-5346.10 psi
Effective Stress Value
Seff = SQRT(0.5*[S1-S2]^2 + [S2-S3]^2 + [S3-S2]^2)
Seff
24,170 psi
Allowable Effective Stress = Fa x SMYS
Ratio of Seff / Allowable
Cl 4.8.1.2 Eq-12 - API 1102
58,500 psi
=
OK
0.41
No overstressing occurs
h) Check Weld Fatigue
Girth Weld
Design Factor
0.6
Fatigue Endurance in Girth Weld S fg =
12000.00
Allowable Sfg = Sfg x DF
(Refer Eq. 17)
psi
(From table 3 of API 1102)
7200 psi
Check dSlh < = Sfg x DF
Ratio of Actual dSlh / Allowable
0.158
OK
Longitudinal Weld endurance Limit (Sfl)
23000.00
Allowable Sfl = Sfl x DF
Refer Eq. 18
No overstressing occurs
psi
(From table 3 of API 1102)
13800 psi
Check dSHh < = Sfl x DF
Ratio of Actual dSHh / Allowable Sfl
0.03
OK
Summary
Calculated
Allowable
Stress
Stress (PSI)
(PSI)
No overstressing occurs
Factor of
safety
(FOS)
1.Barlow Stress Check
33,320
39,000
1.2
2.Principal Stresses (Seff)
24,170
58,500
2.4
1,137
7,200
463
13,800
3.Girt Weld Fatigue Check
4.Longitudinal Weld Fatigue Check
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-5
6.3
29.8
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
RG production flowline
Linepipe Material
API5L
Grade
X52
Pipe Nominal Diameter
Pipe Outside Diameter
8
D
Pipe Nom. Thickness
Maximum Operating Pressure
P
SMYS of linepipe material
Pipeline Design Factor
Longitudinal Joint Factor
Temperature Derating Factor
mm
12.70
mm
179.30
barg
52000
DF
0.6
E
1.0
Corrosion Allowance
DF Max. Allowable Effective Stress
219.08
Fa
T
8.63
in
2600.531
psi
psi
ASME B31.8 AppendixD
ASME B31.8 Table 841.1.6.2
ASME B31.8 Table 841.1.7.2
3.0
mm
0.90
ASME B31.8 Section 833.3 (Due to combined stress )
1.0
Design Temperature
T2
140.0
deg F
60
degC
Installation Backfill Temperature
Corroded Wall Thickness
T1
tW
69.8
9.70
deg F
degC
mm
21
0.382
Depth of Pipe Cover
H
1200
mm
47.244
in
Bored Diameter of crossing
Bd
219.1
mm
8.625
in
Modulus of Soil Reaction
E'
0.5
ksi
Cl 4.7.2.1 API 1102
Resilient Modulus of soil
Er
10.0
ksi
Cl 4.7.2.2.3 API 1102 Figure-8 Table A-2
Soil Unit Weight-
Y
120
lb/ft3
0.0694
Poisson's Ratio
v
0.3
Pavement Type
In
lb/in3
Cl 4.7.2.1 API 1102
Flexible pavement
a) Expected stress on pipeline
Check Barlow Stress (Shi)
Cl 2.2 - Eq. 8 a API 1102
Shi = (PxD)/(2xtW)
29,367 psi
Allowable stress -DFxExTxSMYS
31,200 psi
Shi< Allowable
OK
b) Circumferential Stress Due to Earth Load (She)
Cl 2.2 - Eq. 1 API 1102
tW/D
0.0443
Khe(Earth load stiffness factor)
758.8
H/Bd
5.48
Figure 3 - API 1102
Figure 4(soil type A) -
Be (Burial factor for circumferential
API 1102
stress from earth load)
1.11
Bd/D
1.00
Ee
0.82
SHe
=KHexBexEexYxD
412
Figure 5
Cl 2.2 - Eq. 1 API 1102
Psi
c) Impact factor F1 and Applied design Surface pressure
As per Table 1 of API-1102, for the following Conditions
H < 1.2m
D >= 305mm,Tandem axles load is the critical axle configuration for flexible pavement.
Single Axle Loads
30.00
ton
(Section 8.8.5 of QP-STD-L-017)
Pt = wheel load
10
ton
(Section 8.8.5 of QP-STD-L-017)
22046.20
lbs
47.24
in
3.940
Feet
Burial Depth
Impact Factor Fi @3.94feet
1.40
Figure 7 - API 1102
Contact area overwhich the wheel
load is applied (Ap)
Doc. No.: 4148-DGTYP-7-17-0001
144.00
Attachment-5
sq.in
Cl 4.7.2.2.1 - Eq. 2 API 1102
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Applied Design Surface Pressure(w)
w = Pt/Ap
153.10
PSI
d) Cyclic Circumfrential Stresses (dSHh)
dSHh = KHh x GHh x R x L x Fi x w
Cl 4.7.2.2.4 - Eq. 5 API 1102
for
tW/D
Er
0.044
10
ksi
KHh =
6.51
D
8.63
in
H
47.2
in
3.937
ft
Figure 14 - API 1102
for
GHh =
1.37
Figure 15 - API 1102
Single Axle R =
1.00
Table 2-API 1102
Single Axle L =
0.75
Table 2-API 1102
For FLEXIBLE PAVEMENT
dSHh
1,434 psi
e) Cyclic Longitudinal Stress (dSLh)
dSLh = KLh x GLh x R x L x Fi x w
Cl 4.7.2.2.4.2 - Eq. 6 API 1102
for
tW / D
Er
0.044
10
ksi
KLh
6.38
D
8.63
in
H
47.2
in
3.937
ft
Figure 16 - API 1102
for
GLh
1.30
Figure 17 - API 1102
Single Axle R =
1.00
Table 2 - API 1102
Single Axle L =
0.75
Table 2 - API 1102
For FLEXIBLE PAVEMENT
dSLh =
1,337 psi
f) Circumfrential Stress due to Internal Pressure, SHi
SHi = P x (D-tW) / (2 x tW)
Cl 4.7.3 Eq.7 - API 1102
p
2600.531
psi
D
8.62519685
in
tW
0.382
in
SHi =
Doc. No.: 4148-DGTYP-7-17-0001
28,067 psi
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
g) Principal Stresses S1,S2,S3
Young's Modulus of Steel , Es =
2.88E+07
Psi
Co-eff. Of thermal expn. ,
6.5E-06
per ºF
t =
Poisson's Ratio, Vs
= 0.3
S1=SHe+dSHh+SHi
29912.67 psi
Cl 4.8.1.2 Eq-9 - API 1102
S2 = dSLh– Esα(T2-T1) + Vs(SHe + SHi)
-3261.32 psi
Cl 4.8.1.2 Eq-10 - API 1102
S3 = -1 x p
Cl 4.8.1.2 Eq-11 - API 1102
S3 =
-2600.53 psi
Effective Stress Value
Seff = SQRT(0.5*[S1-S2]^2 + [S2-S3]^2 + [S3-S2]^2)
Seff
23,467 psi
Allowable Effective Stress = Fa x SMYS
Ratio of Seff / Allowable
Cl 4.8.1.2 Eq-12 - API 1102
46,800 psi
=
OK
0.50
No overstressing occurs
h) Check Weld Fatigue
Girth Weld
Design Factor
0.6
Fatigue Endurance in Girth Weld S fg =
12000.00
Allowable Sfg = Sfg x DF
(Refer Eq. 17)
psi
(From table 3 of API 1102)
7200 psi
Check dSlh < = Sfg x DF
Ratio of Actual dSlh / Allowable
0.186
OK
Longitudinal Weld endurance Limit (Sfl)
23000.00
Allowable Sfl = Sfl x DF
Refer Eq. 18
No overstressing occurs
psi
(From table 3 of API 1102)
13800 psi
Check dSHh < = Sfl x DF
Ratio of Actual dSHh / Allowable Sfl
0.10
OK
Summary
Calculated
Allowable
Stress
Stress (PSI)
(PSI)
No overstressing occurs
Factor of
safety
(FOS)
1.Barlow Stress Check
29,367
31,200
1.1
2.Principal Stresses (Seff)
23,467
46,800
2.0
3.Girt Weld Fatigue Check
1,337
7,200
5.4
4.Longitudinal Weld Fatigue Check
1,434
13,800
9.6
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
RG injection flowline
Linepipe Material
API5L
Grade
X60
Pipe Nominal Diameter
Pipe Outside Diameter
6
D
Pipe Nom. Thickness
Maximum Operating Pressure
P
SMYS of linepipe material
Pipeline Design Factor
Longitudinal Joint Factor
Temperature Derating Factor
mm
12.70
mm
240.00
barg
60000
DF
0.6
E
1.0
Corrosion Allowance
DF Max. Allowable Effective Stress
168.28
Fa
T
6.63
in
3480.912
psi
psi
ASME B31.8 AppendixD
ASME B31.8 Table 841.1.6.2
ASME B31.8 Table 841.1.7.2
3.0
mm
0.90
ASME B31.8 Section 833.3 (Due to combined stress )
1.0
Design Temperature
T2
140.0
deg F
60
degC
Installation Backfill Temperature
Corroded Wall Thickness
T1
tW
69.8
9.70
deg F
degC
mm
21
0.382
Depth of Pipe Cover
H
1200
mm
47.244
in
Bored Diameter of crossing
Bd
168.3
mm
6.625
in
Modulus of Soil Reaction
E'
0.5
ksi
Cl 4.7.2.1 API 1102
Resilient Modulus of soil
Er
10.0
ksi
Cl 4.7.2.2.3 API 1102 Figure-8 Table A-2
Soil Unit Weight-
Y
120
lb/ft3
0.0694
Poisson's Ratio
v
0.3
Pavement Type
In
lb/in3
Cl 4.7.2.1 API 1102
Flexible pavement
a) Expected stress on pipeline
Check Barlow Stress (Shi)
Cl 2.2 - Eq. 8 a API 1102
Shi = (PxD)/(2xtW)
30,194 psi
Allowable stress -DFxExTxSMYS
36,000 psi
Shi< Allowable
OK
b) Circumferential Stress Due to Earth Load (She)
Cl 2.2 - Eq. 1 API 1102
tW/D
0.0576
Khe(Earth load stiffness factor)
520.8
H/Bd
7.13
Figure 3 - API 1102
Figure 4(soil type A) -
Be (Burial factor for circumferential
API 1102
stress from earth load)
1.22
Bd/D
1.00
Ee
0.82
SHe
=KHexBexEexYxD
239
Figure 5
Cl 2.2 - Eq. 1 API 1102
Psi
c) Impact factor F1 and Applied design Surface pressure
As per Table 1 of API-1102, for the following Conditions
H < 1.2m
D >= 305mm,Tandem axles load is the critical axle configuration for flexible pavement.
Single Axle Loads
30.00
ton
(Section 8.8.5 of QP-STD-L-017)
Pt = wheel load
10
ton
(Section 8.8.5 of QP-STD-L-017)
22046.20
lbs
47.24
in
3.940
Feet
Burial Depth
Impact Factor Fi @3.94feet
1.40
Figure 7 - API 1102
Contact area overwhich the wheel
load is applied (Ap)
Doc. No.: 4148-DGTYP-7-17-0001
144.00
Attachment-5
sq.in
Cl 4.7.2.2.1 - Eq. 2 API 1102
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
Applied Design Surface Pressure(w)
w = Pt/Ap
153.10
PSI
d) Cyclic Circumfrential Stresses (dSHh)
dSHh = KHh x GHh x R x L x Fi x w
Cl 4.7.2.2.4 - Eq. 5 API 1102
for
tW/D
Er
0.058
10
ksi
KHh =
4.06
D
6.63
in
H
47.2
in
3.937
ft
Figure 14 - API 1102
for
GHh =
1.45
Figure 15 - API 1102
Single Axle R =
1.00
Table 2-API 1102
Single Axle L =
0.75
Table 2-API 1102
For FLEXIBLE PAVEMENT
dSHh
943 psi
e) Cyclic Longitudinal Stress (dSLh)
dSLh = KLh x GLh x R x L x Fi x w
Cl 4.7.2.2.4.2 - Eq. 6 API 1102
for
tW / D
Er
0.058
10
ksi
KLh
5.29
D
6.63
in
H
47.2
in
3.937
ft
Figure 16 - API 1102
for
GLh
1.49
Figure 17 - API 1102
Single Axle R =
1.00
Table 2 - API 1102
Single Axle L =
0.75
Table 2 - API 1102
For FLEXIBLE PAVEMENT
dSLh =
1,270 psi
f) Circumfrential Stress due to Internal Pressure, SHi
SHi = P x (D-tW) / (2 x tW)
Cl 4.7.3 Eq.7 - API 1102
p
3480.912
psi
D
6.62519685
in
tW
0.382
in
SHi =
Doc. No.: 4148-DGTYP-7-17-0001
28,454 psi
Attachment-5
PIPELINE WALL THICKNESS CHECK AT CROSSINGS AS PER API RP 1102
g) Principal Stresses S1,S2,S3
Young's Modulus of Steel , Es =
2.88E+07
Psi
Co-eff. Of thermal expn. ,
6.5E-06
per ºF
t =
Poisson's Ratio, Vs
= 0.3
S1=SHe+dSHh+SHi
29635.93 psi
Cl 4.8.1.2 Eq-9 - API 1102
S2 = dSLh– Esα(T2-T1) + Vs(SHe + SHi)
-3263.93 psi
Cl 4.8.1.2 Eq-10 - API 1102
S3 = -1 x p
Cl 4.8.1.2 Eq-11 - API 1102
S3 =
-3480.91 psi
Effective Stress Value
Seff = SQRT(0.5*[S1-S2]^2 + [S2-S3]^2 + [S3-S2]^2)
Seff
23,265 psi
Allowable Effective Stress = Fa x SMYS
Ratio of Seff / Allowable
Cl 4.8.1.2 Eq-12 - API 1102
54,000 psi
=
OK
0.43
No overstressing occurs
h) Check Weld Fatigue
Girth Weld
Design Factor
0.6
Fatigue Endurance in Girth Weld S fg =
12000.00
Allowable Sfg = Sfg x DF
(Refer Eq. 17)
psi
(From table 3 of API 1102)
7200 psi
Check dSlh < = Sfg x DF
Ratio of Actual dSlh / Allowable
0.176
OK
Longitudinal Weld endurance Limit (Sfl)
23000.00
Allowable Sfl = Sfl x DF
Refer Eq. 18
No overstressing occurs
psi
(From table 3 of API 1102)
13800 psi
Check dSHh < = Sfl x DF
Ratio of Actual dSHh / Allowable Sfl
0.07
OK
Summary
Calculated
Allowable
Stress
Stress (PSI)
(PSI)
No overstressing occurs
Factor of
safety
(FOS)
1.Barlow Stress Check
30,194
36,000
1.2
2.Principal Stresses (Seff)
23,265
54,000
2.3
1,270
7,200
943
13,800
3.Girt Weld Fatigue Check
4.Longitudinal Weld Fatigue Check
Doc. No.: 4148-DGTYP-7-17-0001
Attachment-5
5.7
14.6