2009w_engi_8673_a02_solution.pdf
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ENGI 8673 Subsea Pipeline Engineering
Faculty of Engineering and Applied Science
Shawn Kenny, Ph.D., P.Eng. Winter 2009
Assignment #2 Page 1 of 1
ASSIGNMENT #2(DUE: MARCH 2,2009)
Instructions: To demonstrate comprehension of the subject matter and to prepare for the finalexamination, include a handwritten sample calculation for each unique calculation required in each
problem. For repetitive calculations, the use of electronic calculation packages (e.g. Excel, Matlab) are
allowed. Sufficient information, which may include text, tables or figures, must be included to demonstrate
the problem set requirements have been satisfied.Problem 2-1 An arctic offshore gravity base platform has an oil riser traversing within the in-air working
space and is supported by an anchor block. The pipeline has a 273.1mm nominal outside diameter with
9.525 mm wall thickness. The material properties include an elastic modulus of 205 GPa, Poissons ratio
of 0.3 and coefficient of thermal expansion of 1.1510-5
m/m/C. The installation tie-in temperature is
-25 C and the operating temperature is 75C. The design pressure is 12 MPa. As the distance from the
design pressure reference height to the pipeline elevation is typically small, the effects of a static fluidcolumn on internal pressure can be ignored. Calculate the longitudinal stress, equivalent stress and
deflection for the pipeline within the anchor block. If the linepipe is DNV SMLS 360, does the pipeline fail
the von Mises stress check? [50]
Problem 2-2 For the pipeline in Problem 1-1, calculate the virtual anchor length, axial end displacement
and axial stress at the anchor point for a buried pipeline. For these calculation assume the pipeline has
no concrete coating or anti-corrosion coating. Assume a undrained cohesive soil strength of 25kPa and
0.25 adhesion factor. Does the pipeline fail the von Mises stress check? [50]
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EN 8673 Subsea Pipeline Engineering Assignment 2Problem 2-02
Winter 2009
DEFINED UNITS
MPa 106Pa kPa 10
3Pa GPa 10
9Pa C K kN 10
3N
PIPELINE SYSTEM PARAMETERS
Nominal Outside Diameter Do 273.1mm
Initial Selection Nominal Wall Thickness (Sec.5 C203 Table 5-3) tnom 9.525mm
External Corrosion Protection Coating Thickness tcpc 0mm
Fabrication Process (Sec.7 B300 Table 7-1) [SMLS, HFW, SAW] FAB "SMLS"
Corrosion Allowance (Sec.6 D203) tcorr 3mm
Elastic Modulus E 205GPa
Specified Minimum Yield Stress (Sec.7 B300 Table 7-5) SMYS 450MPa
Speciifed Minimum Tensile Stress (Sec.7 B300 Table 7-5) SMTS 535MPa
Coefficient of Thermal Expansion T 1.15 10
5
C1
Poisson's Ratio 0.3
Pipeline Route Length Lp 2.5km
Linepipe Density s 7850kg m3
Concrete Coating Thickness tc 0mm
Concrete Coating Density c 3050kg m3
OPERATATIONAL PARAMETERS
API Gravity API 38
Product Contents Density
cont 1000 kg m3
141.5
131.5 API cont 835m
3kg
Design Pressure (Gauge) Pd 12MPa
Design Pressure Reference Level href 0m
Operational Temperature To 75 C
Tie-in Temperature Tti 25 C
Maximum Water Depth hl 0m
Seawater Density w 1025kg m3
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EN 8673 Subsea Pipeline Engineering Assignment 2Problem 2-02
Winter 2009
GEOTECHNICAL PARAMETERS
Undrained Shear Strength Cu 25kPa
Adhesion Factor soil 0.25
SOIL RESISTANCE PARAMETERS
Soil Axial Restraint per Unit Length (Eqn B-1 ALA 2001)
f Do Cu soil f 5.36 kN m1
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EN 8673 Subsea Pipeline Engineering Assignment 2Problem 2-02
Winter 2009
DNV OS-F101 PARTIAL FACTORS AND DESIGN PARAMETERS
Material Strength Factor - Operations (Sec.5 C306 Table 5-6) U_o 0.96
Wall Thickness Fabrication Tolerance(Sec.7 G307 Table 7-18)
tfab 0.5mm FAB "SMLS"=
tnom 4mmif0.125 tnom FAB "SMLS"= tnom 4mmif
0.125 tnom FAB "SMLS"= tnom 10mmif
0.100 tnom FAB "SMLS"= tnom 25mmif
3mm FAB "SMLS"= tnom 30mmif
0.4mm FAB "HFW"= tnom 6mmif
0.7mm FAB "HFW"= tnom 6mmif
1.0mm FAB "HFW"= tnom 15mmif
0.5mm FAB "SAW"= tnom
6mmif
0.7mm FAB "SAW"= tnom 6mmif
1.0mm FAB "SAW"= tnom 10mmif
1.0mm FAB "SAW"= tnom 20mmif
tfab 1.2 mm
Material Derating (Sec.5 C300 Figure 2)
SMYS_o 0MPa To 50Cif
To 50 C 30MPa
50 C
50 C To 100Cif
30MPa To 100 C 40MPa100 C
otherwise
SMYS_o 15.00 MPa
SMTS_o 0MPa To 50Cif
To 50 C 30MPa
50 C
50 C To 100Cif
30MPa To 100 C 40MPa
100 C
otherwise
SMYS_o 15.00 MPa
fy_o SMYS SMYS_o( ) U_o fy_o 418 MPa
fu_o SMTS SMTS_o( ) U_o fu_o 499 MPa
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EN 8673 Subsea Pipeline Engineering Assignment 2Problem 2-02
Winter 2009
ENGINEERING ANALYSIS
PIPELINE GEOMETRIC PROPERTIES
Inside Pipeline Diameter (Operations Case)
Di_o Do 2 tnom tcorr tfab Di_o 262.4 mm
Inside Pipeline Radius (Operations Case)
Ri_o 0.5 Di_o Ri_o 131.2 mm
Mean Pipeline Radius
Rm 0.5 Do tnom Rm 131.8 mm
External Hydrostatic Pressure
Pe w g hl Pe 0.00 MPa
HOOP STRESS (THIN WALL THEORY)
hPd cont g href hl Di_o Pe Do
2 tnom tcorr tfab h 295.2 MPa
DISTANCE TO VIRTUAL ANCHOR POINT
- Equation 9 of Palmer and Ling (1981) OTC4067
- Eqn (12.17) L12 Guidance Note
z Pd Rm
2
f1 2
2 tnom
Pd RmE T To Tti
z 396m
Virtual Anchor Length Check
zchk "VIRTUAL ANCHOR OK" z 0.5 Lpif
"RECALCULATE" otherwise
zchk "VIRTUAL ANCHOR OK"
AXIAL END DISPLACEMENT
Eqn (12.19) L12 Guidance Note
endPd Rm
2 E tnom1 2( ) T To Tti
z
f z2
4 E Rm tnom end 260 mm
Axial End Displacement [Equation 12 - Palmer and Ling (1981) OTC 4067]
Palmer
Rm E tnom T To Tti 2
f1
Pd Rm1
2
E tnom T To Tti
2
Palmer 260 mm
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EN 8673 Subsea Pipeline Engineering Assignment 2Problem 2-02
Winter 2009
LONGITUDINAL STRESS
- Eqn (12.16) L12 Guidance Note
Axial Stress (For X =Z)
l
Pd Rm
tnom
E T
To Tti
l 185.9
MPa
EQUIVALENT STRESS CHECK
eq h2
h l l2
eq 420.2 MPa
eqchk "EQUIVALENT STRESS OK" eq 0.9 fy_oif
"INCREASE WALL THICKNESS" otherwise
eqchk "INCREASE WALL THICKNESS"
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