Examination of 13%Cr flowlines in rledninger... · PDF fileTitle of presentation in...
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Transcript of Examination of 13%Cr flowlines in rledninger... · PDF fileTitle of presentation in...
Examination of 13%Cr
flowlines in service.
P-til 9 dec. 2009
2Title of presentation in Header and Footer
Subjects
► HISC sensitivity
► NDT Techniques for Inspection of Flowlines in Service
• During start up of one of the flowlines at the Aasgard field in year 2001 a leak was
detected at one of the anode pads. That gave uncertainty for safety of the remaining
flowlines and an initiative for an inspection campaign was taken by the Aasgard
management.
Weld toe
initiation
Macro fracture
IC fracture
Crack detection
K-101
3Title of presentation in Header and Footer
13Cr Flowline history
► Gullfaks Satellites was the first project where Statoil used 13%Cr steel for
flowlines. These pipes were laid in the summer 1997 without any difficulties and
have been safely in operation since
► During laying of the first flowlines at Åsgard in Mars/April 1998 the first incident
due to hydrogen delayed cracking arose. A crack occurred in the HAZ for one of
the tie-in welds about one hour after reeling on the vessel drum.
4Title of presentation in Header and Footer
13Cr Flowline history
► One of the flowlines installed at Åsgard in year 2000 was at the seabed
for some months before it could be set into production.
► That pipe was pressure tested several times due to leaks at flanges and
necessary repairs.
► After successful repair (at the flanges), a leak was observed when the
flowline should be set into production.
Fracture position and appearance
5Title of presentation in Header and Footer
13Cr Flowline history
► It was at that time unknown that cathodic
protection could cause a hydrogen level in
stainless steels as duplex and 13%Cr
sufficient to initiate cracks (HISC) under
normal service operation!
► As the incidents occurred for loads below the
allowed design stresses, an increased
uncertainty for the flowlines quality arose. In
2004/05 it was therefore decided to perform an
UT-inspection of nearly all flowlines laid in the
second laying phase at the Åsgard field.
► The UT examination was done by means of a
cable based crawler with a head consisting of
TOFD probes.
6Title of presentation in Header and Footer
Calibration of the UT tool
►Qualification of the NDT tool was
performed by means of spark eroded
defects in different position around
anode pads.
► The correlation found between the
spark eroded defects and the TOFD
measurements were excellent with
height accuracy within ± 0,5mm and
length accuracy within ± 10mm.
V
2
V
3
3
3
3
4V
1
3
234mm
14mm
238mm
1 2
1 214 2&3
7Title of presentation in Header and Footer
Spark eroded defects
for calibration.
8Title of presentation in Header and Footer
Calibration results
Flange Pad
Weld
No.
*Axial
Position
Length
Toe/Toe
Defect
No. **
Depth
mm
Length
mm
Adjacent PE
Thickness
Defect
Height
Clock
Pos.
File Name
Depth / Length (if different)
1 0
1.1 197 1-U 14.5 10 15.5 1.0 12:00 SCAN_13_75mm_TOFD4.scn
1.2 296 99 1-D 14.4 49 15.6 1.2 SCAN_10mm_TOFD4.scn
2.1 437 2-U 15.0 28 15.9 0.9 SCAN_22_5mm_TOFD2.scn
2.2 531 94 2-D 14.8 43 16.0 1.2 SCAN_20mm_TOFD2.scn
2 728
3.1 926 N/A N/A N/A 01:30
3.2 1020 94 3-D 14.9 30 15.9 1.0 SCAN_17_5mm_TOFD4.scn /
SCAN_17_5mm_TOFD2.scn
4.1 1163 4-U 14.2 25 15.9 1.7 07:30 SCAN_25mm_TOFD4.scn /
SCAN_25mm_TOFD1.scn
4.2 1260 97 4-D 14.1 48 16.1 2.0 SCAN_25mm_TOFD4.scn /
SCAN_20mm_TOFD1.scn
3 1453
5.1 1652 5-U 13.7 31 15.7 2.0 03:00 SCAN_17_5mm_TOFD2.scn /
SCAN_17_5mm_TOFD1.scn
5.2 1751 99 5-D 13.9 40 15.9 2.0 SCAN_20mm_TOFD2.scn /
6.1 1889 6-U 13.0 34 16.0 3.0 09:00 SCAN_22_5mm_TOFD4.scn /
SCAN_22_5mm_TOFD3.scn
6.2 1988 99 6-D 12.9 52 15.9 3.0 SCAN_22_5mm_TOFD4.scn /
SCAN_22_5mm_TOFD3.scn
Deviation Spark-UT measures: Green: L ±10%, H ±0,5mm. Yellow: L >±10%
9Title of presentation in Header and Footer
Offshore inspection results.
► Shortly summarized, the offshore UT inspection detected minor defects at
more than 50% of all inspected anode pads. (Shown in a later view)
► However, the most demanding defects were observed around the spare
electrical heating connection plates.
• As some of these defects were reported to run 360° around the pipe, a guillotine fracture
become possible, close to the Åsgard FPSO!
10Title of presentation in Header and Footer
UT inspection results, pads
Line Year Inspected Cat 1
<2mm
deep
Cat 2
(<25%WT)
Cat 3
(<50%WT)
Cat 4
(>50%WT)
J-101 2005 112 18 0 2
J-102 2005 110 11 0 0
N-101 2005 108 6 1 0
N-102 2005 106 1 0 2
H-101 2005 83 5 0 0
H-102 2005 85 12 1 0
K-101 re-inspection 2005 12 2 0 0
M-101 2005 62 7 0 0
AB-101 2005 55 0 0 0
J-101 re-inspection 113 18 0 2 re-insp
J-102 re-inspection 2006 110 15 0 0
P-101 2006 90 12 0 0
P-102 2006 96 6 0 0
Total number of indications 920 83 2 4
11Title of presentation in Header and Footer
UT inspection results, external DEH connection plates
Pipeline Ext. Features
Nos
Defect size
EF1
Defect size
EF2
B-scan
performed
Defect
propagation
J-101 2 1,3mm 2,0mm Yes 360°
J-102 1 1,1mm NA Yes 360°
H-101 2 0,5mm 0,6mm Yes 360°
H-101 2 1,7mm 1,5mm Yes Partly
N-101 2 1,7mm 3,0mm Partly
N-102 2 1,8mm 1,4mm Partly
12Title of presentation in Header and Footer
Onshore studies
►As the offshore situation was confusing it become necessary to establish a
better correlation between the pipes service conditions and life time
assuming a crack was initiated.
►An important observation is that only six defects with height of more than
50% of the wall thickness were observed.
►Additionally, the re-inspection of the J-101 performed after a time lapse of
about 10 months did not give any crack propagation!
• That was unexpected, and caused doubt about the UT-TOFD accuracy.
►A research programme was therefore established to study the effect of
stress alteration, pressure and temperature on life time and crack growth.
► The R&D programme should therefore re-qualify the UT (TOFD) technique
used offshore.
• That should be performed by means of fatigue initiated defects, believed to be more
realistic than the spark eroded failure.
13Title of presentation in Header and Footer
Onshore studies
► The R&D programme was therefore divided into different phases.
• Welding of test pipes
• Initiation of minor fatigue cracks
• NDT test spool trials
• Fatigue testing.
►Retrieving of different pipe segment from flowline J-101 where the
inspection had given more than 100 defect indications.
• Metallographic examination both for the retrieved pipe segments and the test pipes.
14Title of presentation in Header and Footer
Onshore studies
► Welding of test pipes
• Welding of pads and external features were performed using the same WPS as used for
through the project.
– However, the weld bead sequence were logged, as it could influence the HAZ mechanical properties,
through sensitization.
Sensitiv?
Ref. JFE.
15Title of presentation in Header and Footer
Initiation of minor fatigue cracks
► To establish realistic defects for recheck of the UT system 6 m long pipes were
loaded in a resonance machine at NTNU (Technical University in Trondheim)
until cracks were initiated at the fillet weld toes, aiming 0,5-1,0mm deep.
► These test pipes should later be used for crack growth analyses under cathodic
protection and different service conditions.
16Title of presentation in Header and Footer
Typical set-up parameters for crack initiation.
Crack initiation parameters:
•f ≤ 44Hz
•R = -1; Δσ≤260MPa
Dye pen for detection
of cracks
17Title of presentation in Header and Footer
Initiation of minor fatigue cracks
► After a few initial trials we succeeded in making shallow fatigue cracks.
18Title of presentation in Header and Footer
Spool set-up for UT (TOFD) inspection
NDT test spool trialsTEST-SPOOL
Launcher
Pipe: L3 Pipe: L4 Pipe: L5 Pipe: L6 Pipe: L1 Pipe: L2 Pipe: L7
Ring-Weld type: Ring-Weld type: Ring-Weld type: Ring-Weld type: Ring-Weld type: Ring-Weld type: Ring-Weld type:
Ikke slipt Ikke slipt Ikke slipt Ikke slipt Ikke slipt Ikke slipt Slipt
Sensitiv sveis Sensitiv sveis Sveist Sveist Sensitiv sveis Sensitiv sveis Sveist
Total lengde på test-rør ( utenom launcher/reciever ) : 61m
Pipe (1m) from Åsgard R101 - DJ 12177 - Pipe 24768.
Cut from ML Weld no.: W2.24 with anode pad / bracket
4 3 2-2 2-1 1-2 1-1
Pipe 2 ( med pad )
Pipe / Pad from Statoil Sensitiv sveis AGR Test-pipe
19Title of presentation in Header and Footer
Reported defects size
EF No. Indication length
(mm)
Indication height
(mm)
No of indications
1 8-142 0,9-4,0 11
2 12-112 0,8-3,2 4
3 <10-54 1,3-2,4 6
4 13-92 0,8-5,6 8
5 10-75 0,9-1,8 6
6 15-150 0,9-2,1 6
7 17-118 0,9-1,5 8
20Title of presentation in Header and Footer
Typical fatigue defects
21Title of presentation in Header and Footer
Spare DEH cable plate, connection to pipes
~59 mm
L7-1 L7-2
No cracks at +25 mm
Weldment L7-1 and L7-2;
No crack findings (some
porosity)
Indicated defect in this
position.
22Title of presentation in Header and Footer
Examples for accuracy for defect detection.
322 mm 276 mm 240 mm
220 mmTOFD max depth of 1.5 mm at 262 mm
195276
Puls Eccho
DP
258268TOFD
322 299
23Title of presentation in Header and Footer
Conclusion from onshore analyses.
TOFD results Puse echo results
In practice no defect less than 2mm in depth is reliable
Estimated maximum crack depth (mm) Estimated maximum crack depth (mm)
24Title of presentation in Header and Footer
Fatigue testing
► Full scale fatigue jig set up.
25Title of presentation in Header and Footer
Examples for the fatigue test results
As expected increased
temperature reduce the
HISC effect
26Title of presentation in Header and Footer
Load frequency effect
The Hydrogen effect will depend of the
Load frequency. However,
test results indicate a “low” effect
for the design life calculation.
Frequency reduction of 1/100 increase
Crack growth speed with a factor ten(?)
27Title of presentation in Header and Footer
Results for retrieved pads and EFs
TOFD Pulse
Depth Length
No
.
Anode
pad
P.Side T.side P.side T.side
Depth
Comments
2 HP I 3 HP II
34A 1,9 2,5 33 62 0 4
34B 2,1 2,3 61 68 0 35A 2,6 2,0 68 61 0 5
35B 1,3 0,8 58 48 0 36A 2,7 2,1 60 58 0 6
36B 1,2 1,7 47 67 0 41A 0,9 1,2 44 35 0 7
41B 1,8 1,5 63 47 0 EF 0,7 2,0 800 800 0 57A 0,7 0,7 36 20 0 57B 2,0 1,1 54 68 0 58A 1,0 1,6 8 26 0 58B 1,0 1,0 4 5 0 59A 1,4 1,3 15 61 0 59B 1,2 1,0 39 58 0 60A 1,1 1,9 63 9 0 60B 1,2 1,5 41 55 0
8
CC 1,75 228 0
9 CC at-
temp.
end
1,85 215 0
Values most probably from
the outside of the weld rather
than the pipewall
1,1mm deep crack
Only one defect observe on macros!
28Title of presentation in Header and Footer
Summary (1)
► Based on the study presented and additional information from other studies the
life time calculation is shown below.
29Title of presentation in Header and Footer
Summary (2)
► Until to day after 9-11 years in service no leak have been observed, and through a
normal yearly inspection programme the probability for a leak is negligible.
► The study has also shown that a brittle guillotine fracture is unlikely, due to an
uneven hydrogen profile through the pipe wall. In case a crack will propagate
through the pipe wall, a minor leak will arise before a full rupture can occur.