Download - Hthp Expansion - Jpk
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Design Solutions for
Reducing End Expansion
Use Pipe in Pipe
Increase Spool Capacity
Increase Axial Friction Trench and Bury
Site specific pipe-soil Geotechnical Investigation
Weight Coating
Spot rock dump / mattresses Fins/ Strakes/Spiders
Pipe Anchors
Lateral Buckling
Snake Lay
Buckle Initiator
Sleepers
Buoyancy
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Pipe in Pipe
Pros:
Proven technology
Insulation can be included
Provides physical protection Can be snaked laid
Less prone to pipe walking
Suited to deep and shallow water
Cons:
Increased pipe weight
Complex field joints
Reduced lay rate
Cost:
Cost of pipe in pipe is high due to cost of outer pipe andreduced lay rate.
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Typical Expansion Movements
For Pipe in Pipe and Single Pipe
0
2
4
6
8
10
12
100 60 30
Operating Temperature (C)
PipelineEnd
Expansion(m)
Single Pipe, 0.3 friction
Single Pipe, 0.6 friction
PIP, 0.3 friction
PIP, 0.6 friction
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Typical Anchor Lengths
For Pipe in Pipe and Single Pipe
0
5
10
15
20
25
100 60 30
Operating Temperature (C)
PipelineAnch
orLength(km)
Single Pipe, 0.3 friction
Single Pipe, 0.6 friction
PIP, 0.3 frictionPIP, 0.6 friction
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Increase Spool / Jumper Expansion Capacity
Pros:
Proven technology
Limit state methods can be used
Cons:
Connector capacities limited
Expansion exceeds possible spool capacity
Time needed to develop new connectors
Cost:
Cost of longer spools is low
Cost of developing new connectors is high
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Increase Axial Friction
Trench and Bury
Pros:
Will reduce pipeline expansion
Cons:
Deep water trenching is difficult
Cannot inspect the pipeline once it is buried
Susceptibility to upheaval buckling
Prohibitive cost of deep water trenching spread Increased temperature due to insulating effect of
backfill
Uncertainty over backfill geotechnical properties
Cost: Cost of trenching is high due to spread costs.
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Increase Axial Friction
Site specific pipe-soil Geotechnical Investigation
Pros:
Improved confidence in friction factors
Makes design of lateral buckling based solution
easier
Cons:
Time required to collect and interpret data
Cost:
Cost of gathering site specific data is low due tomarginal vessel and equipment cost
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Increase Axial Friction
Weight Coating
Pros:
Will reduce end expansions Will help guarantee controlled buckles occur
Will reduce feed-in to buckles
Cons:
Increased likelihood of uncontrolled lateral buckling due
to higher axial forces Increased lateral friction factors will result in higher
strains at buckle locations
Difficulty in installing weight-coated pipelines
Cost: Cost of concrete coating or clump weights is medium
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Increase Axial Friction
Spot rock dump / mattresses
Pros:
Can reduce end expansions Can help guarantee controlled buckles occur
Can reduce feed-in to buckles
Can eliminate potential for uncontrolled buckles
Cons: Large quantities of rock required to counter settlement
Increased installation time and cost (especially for
mattresses)
Specialist vessels required (deepwater fall pipe)Cost:
Cost of rock dumping is high due to spread costs
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Increase Axial Friction
Fins/Strakes/Spiders
Pros:
Embedment can mobilise additional soil friction
Cons:
Units have to be suitable for deployment over
lay barge stinger
Limited track record
Cost:
Cost of fins is medium assuming no delay in
pipe lay.
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Increase Axial Friction
Pipe Anchors
Pros:
Anchors are being proposed to prevent pipewalking in deepwater
Cons:
Limited track record
High anchor loads
Anchors will be large and heavy
Subsea connection of anchor to pipeline hard toachieve
Fishing interaction in shallow water
Cost: Cost of anchors is high due to fabrication cost and
installation cost
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Lateral Buckling
Snake Lay
Pros:
Proven track record in shallow water
Cons:
Difficult to achieve tight lay radii in deepwater
Insufficient axial friction to guarantee buckle initiation Uncertainty over soil-pipe interaction in soft soils
Lateral buckles may overstress pipeline
Cost: Cost of snake lay is medium associated with
engineering and slightly longer pipe length.
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Pipe in Pipe Snaked Lay
Penguin Production Line
Shell North Sea
34 Bends
28 Buckle Sites
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Pipe in Pipe Snaked Lay
Pipeline Snake Geometry
Penguin Production Line
Pipelay Shape to
Approx. Scale
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Pipe in Pipe Snaked Lay
Penguin Production Line
Operational Feedback
Feed-Back
Operation
First Oil 4/1/2003
3 months - high spec survey
All Buckle Sites Formed
80 bara, 93 C at DC5
2 Short Sections Buckled?
Video Record along routeBoulders swept away
9 months - high spec survey
Satisfactory
Shutdown for Brent Safety
Late September 2003
Started Up again last week
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Pipe in Pipe Snaked Lay
Penguin Production Line
Installer Feedback
Feedback
InstallationSaipem - Castoro Sei
ROV Touch down Monitoring
ROV moved some boulders
As-installed survey
Buckle Sites ~ 1500m Rad+/- 2m of target laydown
No embedded boulders
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SPD 4
Phase 1
PLEM 2
PLEM 1
Phases 2 & 3
SPD7
SPD8
SPD9
South Pars Development
Field Layout
SP6-1
&2
SP7-
1&2
SP8
-1&2
80m
80m
Phase 6, 7 & 8
pipelines
Condensate line
N
SPD 3
Phases 4 & 5
3 identical NNM wellhead platforms
Transporting 3-phase wet gas toshore
Via 3, 110km long, subsea 32trunklines
Each with a 4 MEG injectionpiggyback line.
Single Line Snaked Lay
South Parrs Trunklines
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Pipeline Route Length = 110km
Platform
(KP 110)
Shore
(KP0.0)KP80
Rough Seabed
KP50
Snaked Lay
KP30
Free Span
Feed-in
Below Critical
Buckling Limit
Pipeline Temperature Profile 4C89C
Single Line Snaked Lay
South Parrs
Route Length Buckling Mitigation
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Single Line Snaked Lay
South Parrs
Nested Snaked Lay Pipeline Routes and Buckle Sites
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Single Line Snaked Lay
South Parrs
Snaked Lay Pre-Buckle Shapes
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Single Line Snaked Lay
South Parrs
Buckle Formations Approaching Platforms
40 x Magn i f i ca t i on o f l a te ra l d i sp lacem en ts a long the SP6 , 7 and 8 p ipe l i nes
2,945,000
2,950,000
2,955,000
2,960,000
2,965,000
2,970,000
2,975,000
618,000 620,000 622,000 624 ,000 626,000 628,000 630,000 632,000 634,000 636,000
E a s t in g s ( m )
Northings(m)
50 concrete wt coat
Extg pipeline
70 concrete weight coat
Platform
Extg SP2
pipeline
Extg SP3
pipeline
SPD 9(KP110.5)
SPD 7
(KP95.4)
SPD 8
(KP101.8)
KP80
KP88
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Single Line Snaked Lay
South Parrs
3D Image of Snaked Lay Pipeline Route
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12 by 23km stainless steel pipeline
Reeled installation
Flow assurance for 95 deg C inlet
7 lateral buckle sites
Single layer insulation
Friction sensitivity studies
Ratcheting,fatigue, creep and buckle interaction code checks
Strain based acceptance criteria
Shell International verification
Single Line Buckle Initiator
Echo Yodel Flowline
Woodside Energy - West Australia
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Single Line Buckle Init iator
Echo Yodel
Pipeline Route
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Single Line Buckle Init iator
Echo Yodal
Buckle Init iator Geometry
Perodic Lateral Buc kl ing Init iat ion Feature (1000m Radius o f Curvature)
0
2
4
6
8
10
12
14
0 50 100 150 200 250 300 350 400 450 500 550 600 650 700 750 800
Distance (m)
Amplitud
e(m)
1000m Radius
IP2 (411.521, 13.700)
2000m
Radius
2000m
Radius
375.0m IP2 to IP3375.0m IP1 to IP2
IP1 (36.521,0.0) IP3 (786.521, 0.0)
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Single Line Buckle Init iator
Echo Yodel
As Built Survey
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Single Line Buckle Init iator
Echo Yodel
Operational Lateral Buckling
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Lateral Buckling
Lay Over Sleepers
Pros:
Proven technology in deepwater and shallow water
Better control on how the pipeline buckles than snake layonly
Hybrid designs available
Cons:
Bearing design of sleepers for low strength soils Insufficient axial friction to guarantee buckle initiation.
Fatigue in spans induced by sleepers
Buckles may overstress pipeline
Interaction with fishing in shallow waterCost:
Cost is high due to fabrication and deployment of sleepers
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Lateral Buckling
Post buckle survey profile for a 14-inch CRA pipe (long trigger)
L l B kli
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Lateral Buckling
Post Buckle Survey Profile for a 24-inch CRA Pipe
(Short Trigger)
L t l
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Pipe in Pipe
Sleepers
Lateral
Buckling
Sleepers
L t l B kli
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Lateral Buckling
Lay Over Sleepers
Water Injection Lateral Buckling Analysis
Lateral Buckling
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Lateral Buckling
Lay Over Sleepers
Water Injection Lateral Buckling Results
DNV Utili ty Check for i75 Route (Sensi tivity)
0.2
0.4
0.6
0.8
1.0
1.2
0 5000 10000 15000 2000
KP (m)
DNVUtility
High FrictionHigh Lateral Low AxialLow FrictionLow Lateral High Axial
Lateral Buckling
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Lateral Buckling
Lay Over Sleepers
Water Injection Expansion Results
PIPELINE DESCRIPTION NO INITIATORS WITH INITIATORS
Hot End - FLET 3.4 2.0
ITA 0.6 0.6I65Cold End - FLET 0.6 0.6
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Lateral Buckling
Layover Sleeper with Trigger
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Lateral Buckling
Buoyancy
Pros:
Better control on how the pipeline buckles thansnake lay only.
Cons: Not proven technology
Difficulty passing buoyancy though lay bargefiring line
Insufficient axial friction to guarantee buckle
initiation. Fatigue in spans induced by buoyancy
Buckles may overstress pipeline
Interaction with fishing in shallow water
Cost: Cost is medium due to fabrication and attachment
of buoyancy
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Key Findings
A range of design solutions exist for reducing HT expansion movements
Low cost solutions include
Increase Spool Capacity proven Site specific pipe-soil Geotechnical Investigation proven
Medium cost solutions include
Snake Lay - proven
Buckle Initiator - proven Weight Coating - proven
Fins/Strakes/Spiders limited experience
Buoyancy limited experience
High cost solutions include
Use Pipe in Pipe - proven Trench and Bury - proven
Spot rock dump / mattresses limited experience
Sleepers - proven
Pipe Anchors limited experience
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Any Questions