Emergency Pipeline Repair System - oilpera.com O N F I D E N T I A L Equipment for Tapping 1 Tapping...
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C O N F I D E N T I A L
Emergency Pipeline Repair System
London Presentation Lloyds OPERA Group
1
Lloyds OPERA Group
by George Lim
Business Development Manager, T.D. Williamson
London, April 24, 2012
C O N F I D E N T I A L
1 Who is T.D.Williamson?
2 What is EPRS?
3 Onshore EPRS3 Onshore EPRS
4 Offshore EPRS
C O N F I D E N T I A L
* Pioneers in Hot Tapping & Plugging * Pioneers in Pigging * 90 years old ** Onshore and Offshore * Global presence * HQ in Tu lsa, Oklahoma, USA *
T.D. Williamson Inc� Specialized equipment, tools, technologies, products and services� Internal inspection, maintenance and intervention of “live” lines � For oil & gas and process industries, water and industrial businesses
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C O N F I D E N T I A L
1 Who is T.D.Williamson?
2 What is EPRS?
3 Onshore EPRS3 Onshore EPRS
4 Offshore EPRS
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C O N F I D E N T I A L
CatastrophicFailure ASSESS EXECUTEMOBILIZEPROCURE
• Repair• Base location• Materials• Damage
Emergency Pipeline Repair
EPRS ?
Make safe• Repair• Recommission• Restore flow
• Base location• Service contracts• Organization
• Materials• Equipment
Spreads• Resources• Technology
• Damage identification & evaluation
• Repair scenarios
• Business Interruption• Exposure of people, asset, environment
• High reactive costs• Regulator intervention
• Insurance issues• Share value impact
• CNN
• Business Interruption• Exposure of people, asset, environment
• High reactive costs• Regulator intervention
• Insurance issues• Share value impact
• CNN
Extended Downtime
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C O N F I D E N T I A L
EXECUTE
• Repair• Base location
ASSESS MOBILIZEPROCURE
• Materials• Damage • Repair• Recommission• Restore flow
• Base location• Service contracts• Organization
• Materials• Equipment
Spreads• Resources• Technology
• Damage identification & evaluation
• Repair scenarios
How To Minimize Downtime?Do the Assessment, Procurement and Mobilization
before any emergency arises
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C O N F I D E N T I A L
CatastrophicFailureASSESS MOBILIZEPROCURE
• Base location• Materials• Damage
EXECUTE
• Repair
Emergency
Emergency Pipeline Repair SystemEPRS
Make safe• Base location• Service contracts• Organization
• Materials• Equipment
Spreads• Resources• Technology
• Damage identification & evaluation
• Repair scenarios
• Repair• Recommission• Restore flow
EPRS results in operational readiness
Capacity to swiftly restore flow in an emergency
Short downtime
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C O N F I D E N T I A L
1 Who is T.D.Williamson?
2 What is EPRS?
3 Onshore EPRS3 Onshore EPRS
4 Offshore EPRS
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C O N F I D E N T I A L
ONSHORE
• Corrosion• Impact - accidental, malicious• Natural Hazards - earthquakes, landslides• Structural• Intervention – illegal taps
Damage Mechanism
• Intervention – illegal taps
• Catastrophic failure: o Unexpected damage requiring immediate response o Pipeline normally in shutdown condition
• Integrity risk:o Monitored risk and a planned repairo Pipeline normally in operating condition
Damage Consequence
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C O N F I D E N T I A L
� Repair Composites Technologies – such as Res-Q®
� Welded Sleeves or Leak Repair Clamps
� Hot Tap and STOPPLE® / By-Pass Methods
Repair ScenariosONSHORE
Pass Methods
� Cold Cutting and Pipe Replacement
� Tie-In of New Tested Pipe
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C O N F I D E N T I A L
� Equipment: Aligned & Maintained?
� Technicians: Trained & Certified?
Equipment, Materials, Resources ?
ONSHORE What Do You Need?
� Technicians: Trained & Certified?
� Response Time & Geographic Locations ?
� Repair & Rehabilitation Methods
� Local Inventory vs. Needs
� Health / Safety / Environmental
� Applications Engineering Support11
C O N F I D E N T I A L
Current EPRS Capacity vs. Actual Needs
Gap Analysis
TDW Emergency Response Concept
Equipment TechniciansFittings / Clamps / Composites
Planning
Establishing Optimal Capacity12
C O N F I D E N T I A L
Master Document: Gap Analysis of Current Capacity
T.D. WILLIAMSON MASTER PIPELINE INTERVENTION GAP ANALYSIS
CUSTOMER PDVSA SAN TOMEOPERATING UNIT ING. MANTENIMIENTO Sealing Elements Equipment Spares
CONTACT FRANKLIN MATA58-414-190655 (Cel)/ 58-283-2301698 (Of)
DATE 06/14/2006REVISION
Sealing Elements Equipment Spares
ARE.ED 3LATERAL ARECUNA
16" N/A 450.LBS 100° F 1714 x N/A N/A YES YES YES YES YES NO YES YES YES YES N/A NO
ARE.ED 4LATERAL ARECUNA
16" N/A 550.LBS 100° F 13592 x N/A N/A YES YES YES YES YES NO YES YES YES YES N/A NO
OED- 16LATERAL ARECUNA
6" N/A 440.LBS 440° F 3335 x N/A N/A YES YES YES NO YES NO NO YES YES NO N/A NO
OED- 20LATERAL MEREY
6" N/A 500.LBS 500° F 258 x N/A N/A YES YES YES NO YES NO NO YES YES NO N/A NO
Welded Sleeves
Composite Wraps
Hot Tap StoppleRepair Clamps
Repair & Rehabiliation
Hot TapSINGLE Stopple
DOUBLE Stopple
PER WALL THICKNESS (*)
Cutters, Pilots, Etc. (**)
Hot Tap StoppleWall Thick
Inches
Crude Oil
Natrl Gas
Technicians
Start
Pipe Location
Daily Production BBD / mfcm
Fittings
Pipe Contents Fittings TechniciansEquipment
Repair & Rehabiliation
Pipe Description
Nominal Pipe Size
Inches
Operating Condtions
Max Op Press. (Psi)
Max Op Temp
(F)H2S %
OED- 20MEREY
6" N/A 500.LBS 500° F 258 x N/A N/A YES YES YES NO YES NO NO YES YES NO N/A NO
LED-13LATERAL
ADAS10" N/A 600.LBS 120° 2400 x N/A N/A YES YES YES NO YES NO NO YES YES NO N/A NO
MED-20LATERAL MEREY
20" N/A 500.LBS 126° 82000 x N/A N/A YES YES YES NO NO NO NO YES YES NO N/A NO
MED-20LATERAL MEREY
12" N/A 550.LBS 126° DOS LINEAS 10200 x N/A N/A YES YES YES NO YES NO NO YES YES YES N/A NO
OED-27LATERAL MEREY
12"N/A
400.LBS 118° 154 x N/A N/A YES YES YES NO YES NO NO YES YES YES N/A NO
MED-15LATERAL
BARE12" N/A 700.LBS 114° 1287 x N/A N/A YES YES YES NO YES NO NO YES YES YES N/A NO
MED -4LATERAL MEREY
6" N/A 400.LBS 120° 726 x N/A N/A YES YES YES NO YES NO NO YES YES NO N/A NO
MED-18LATERAL MEREY
6" N/A 600.LBS 122° 2803 x N/A N/A YES YES YES NO YES NO NO YES YES NO N/A NO
LATERAL DE GUARA
P. T. O 24" N/A 200 LBS 90° 4500 x N/A N/A YES YES YES NO YES NO NO YES YES NO N/A NO
OED-11 P. T. O 4" N/A 120.LBS 102° 956 x N/A N/A YES YES YES NO YES NO NO YES YES NO N/A NO
COB P. T. O 36" 36" N/A 500 LBS 116° 190,000 x N/A N/A NO NO NO NO NO NO NO YES YES NO NO NO
PTOKM 127 (T-51) 30"
N/A710 LBS 102° 449,000 x N/A N/A YES YES YES NO NO NO NO YES YES YES N/A NO
C O N F I D E N T I A L
Equipment for Tapping
1 Tapping Machine TM 2400 complete
1 SANDWICH Valve adapter 48" 600#
1 Cutter holder 46"
2 STOPPLE Cutter 46"
2 Pilot drill 46"
Equipment for Bypass
1 Tapping Machine TM 2400 complete
1 SANDWICH Valve adapter 36" 600#
1 Cutter holder 12" to 30"
2 Standard Cutter 36"
2 Pilot drill 36"
2 SANDWICH Valve 36" 600#
TDW STOPPLE Equipment to perform 3 Double STOPPLE ® position operations on 46“ 600# steel pipes with 36" bypass
Consumables
6 STOPPLE Fitting 46X48" 600 RF
6 LOCK-O-RING Plug 48"
6 Blind flange set 48" 600 RF
12 STOPPLE Sealing element 46"
6 Coupon reinforcement 46"
6 LOCK-O-RING Fitting 46" x 36" 600 RF
Example of Equipment Needed
2 Pilot drill 46"
2 SANDWICH Valve 48" 600#
Equipment for Plugging
2 STOPPLE Hydraulic cylinder
2 STOPPLE Housing 48" 600#
2 STOPPLE Plugging head 46"
Equipment for Completion
1 LOCK-O-RING Plug holder
1 LOCK-O-RING Bypass gauge
2 SANDWICH Valve 36" 600#
1 LOCK-O-RING Plug holder 12" to 36"
1 LOCK-O-RING Bypass gauge
Equipment for equalization1 Drilling Machine T-101
1 Carrying case for T-101
1 Drive socket
1 Air motor for T-101
1 Threaded valve adapter 2"
2 Drill 1 7/16"
2 Full bore valve 2"
1 Plug holder
6 LOCK-O-RING Fitting 46" x 36" 600 RF
6 LOCK-O-RING Plug 36"
6 Blind flange set 36" 600 RF
6 THREAD-O-RING Fitting 2" complete
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You need to knowwhat to buy
C O N F I D E N T I A L
Technician Skills Inventory: Gap Analysis
TECHNICIAN KNOWLEDGE AND SKILLS INVENTORYT.D. WILLIAMSON PIPELINE INTERVENTION GAP ANALYSIS
CUSTOMER PDVSA SAN TOMÉOPERATING UNIT ING. MANTENIMIENTOCONTACT FRANKLIN MATA 58-414-190655 (Cel)/ 58-283-2301698 (Of)DATE 06/14/2006
EXPERIENCE: YES / NO
EQUIPMENT KNOWLEDGE
OPERATION & PROCEDURE KNOWLEDGE
FACTORY TRAINED
FIELD AUDIT DATE
CERTIFICATION DATE
YES YES YES NO NO NO
IDENTIFICATION NUMBER: C.I.: 8.971.860, AGE 39
JUAN BRONT (TECHNICIAN: 6 YEARS, MECHANIC: 6 YEARS)
HOT TAP & STOPPLE EQUIPMENTT-101 Drilling Machine YES YES YES NO NO NO
YES YES YES NO NO NOYES YES YES NO NO NOYES YES YES NO NO NOYES YES YES NO NO NOYES YES YES NO NO NOYES YES YES NO NO NOYES YES YES NO NO NOYES YES YES NO NO NOYES YES YES NO NO NO
Pipeline Medium Pressure TempGas:Liquid: Sour Water 80 PSI 140 ° FCrude oil 650 PSI 140 ° FLPG: 600 PSI 80 ° FHi-Flow:Gasoline 80 PSI 80 ° FDiesel
SHORTSTOPP 60 Plugging Machine
STOPPLE Plugging (less than 500 psi)SHORTSTOPP 60 Plugging Machine
Hydraulic Cilinder 6" - 12"
Hydraulic Cilinder 24" - 36"
660/760 Tapping Machine1200 Tapping Machine
T-101 Drilling Machine360 Tapping Machine
Hydraulic Cilinder 14" - 22"
C O N F I D E N T I A L
Technicians Training & Certification by TDW
� Hot Tapping & Plugging Equipment
� Selection of Equipment Mix: Size, Pressure, Etc.
� Basic Maintenance of Key ComponentsComponents
� Trouble Shooting� Application engineering � HSE Training� Written Exams
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C O N F I D E N T I A L
ONSHORE
Service Centre Set Up
o Customer ownedo TDW premises – “Fire Station”
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C O N F I D E N T I A L
Equipment Maintenance by TDW
� Restoration & Certification of Original TDW Equipment by Factory Standards (OEM)
� Detailed Diagnostics� Validation of Equipment Performance
with Written Test Protocols� 1-Year Guarantee: Labor & Parts� Maintenance Records
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C O N F I D E N T I A L
• Operational :– 24 hour x 365 day emergency cover– Mobilisation within an agreed time– Agreed repair methodologies– Detailed work plans for each emergency– TDW Trained and Certified Technicians– Full Personnel Safety Compliance– Job Safety Analysis
TDW Emergency Response Services
– Job Safety Analysis– OEM Maintained equipment– Fully auditable service
• Commercial :– Multi-year contract for operation and maintenance– Agreement based on 24 hour availability– Agreed rates for retention, per operation and / or
maintenance activities
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C O N F I D E N T I A L
Scope of EPRS Services:
In-Country Equipment & Personnel
– Site assessment– Project Management– Training & drills– Excavation and civil acivities, including site reinstatement
Long Term Partnerships
Comprehensivescope
– Excavation and civil acivities, including site reinstatement– HT&P Equipment & Fittings, – Welding, NDT and cold cutting– Coating removal and re-coating– Pressure testing– SmartPlug TM
– Res-Q ® Wrap– Repair clamps– Pigging & In-line Inspection
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C O N F I D E N T I A L
Asia Pacific� Turkey – Botas
o Customer owned equipment, TDW operatedo TDW personnel & local subcontractorso Fixed annual fee for Maintaining Readiness o Call-off services per incident on reimbursable basis
� Singapore – Exxon Mobil
TDW Current Emergency Response Contracts
Variety of Contract Types
� Singapore – Exxon Mobil o TDW is “Fire Station” for a process industry customero Service Centre at 15 minutes driving distance from the refinerieso 5-year Frame Agreement for call-off services
� Australia – consortium of pipeline operatorso Partnering by 5 local Transmission companieso Pooling of equipment owned by the customerso TDW provides ER services, operates and maintains the equipment
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C O N F I D E N T I A L
South America� Venezuela – PDVSA
o Customer owned equipment, TDW suppliedo Customer owned service centres, Technicianso TDW provides maintenance, Technician training & certification
USA
TDW Current Emergency Response Contracts
USA� Alaska – Alyeska
o Customer owned equipment, TDW operated
Europe� France
o General call-off support
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C O N F I D E N T I A L
Case Study Onshore EPRS
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C O N F I D E N T I A L
BTC Pipeline
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Key features� From Baku – Tiblisi – Ceyhan� Consortium of 11 operators
� 1768 km long and 42”, 34” and 12” diameters� Crossing 3 countries, mountain ranges up to 2,830 metres
� Traverses 3000 roads, railways, utility lines – above/below ground� Crosses 1500 water courses up to 500 metres wide
� 1million b/d
C O N F I D E N T I A L
Loss of containment by
Damage Scenarios
Put in place a system for response and repair under unpredictable circumstances and emergency situations
TDW Services
• Supply of equipment & materials• Call-off services per incident
Purpose of EPRS Contract
• Corrosion• Malicious damage• Illegal fittings• Earthquakes• Landslides
• Call-off services per incident• Maintain Readiness • In-country point of contact• Initial mobilization 4 hours• 24 hours working• 5 + 2 year contract(Owner to supply specified material)
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C O N F I D E N T I A L
Day 1 : Fire at BVS
� 26km of 42” pipe affected
� Assessment team arrived 11 hoursafter first notification
� Equipment & manpower within 24 hours of instruction
Key Events
of instruction� Specialists from Europe within 60 hours
of instruction� Determined the strategy and time
frame with customer� Identified single point contact� Ensured back-up/contingency plans� Damage successfully repaired
� Pipeline shutdown for 15 days26
C O N F I D E N T I A L
25 Illegal taps removed
• Manageable associated hazards• Low / medium risk• Predictable location• Known quantity (generally)• Easier planning
Pipe preparations
1
Integrity Risks
Welded fitting prior to hot tapRecovery of illegal feature1
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C O N F I D E N T I A L
Valve condition assessment42” double STOPPLE® Job with bypass
Site activities normal operations
8” bypass for temporary capping
Coating removal andre-coating
Pre-heating and welding
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C O N F I D E N T I A L
• Single point contact at each base• ‘One-step-ahead’ strategy very effective• Range of repair procedures • Sub-contractor base needs strengthening• Strategic placement of equipment along
Key Lessons Learned
• Strategic placement of equipment along pipeline
• Dedicated EPRS packages at critical stations • Increased inventory across the board• Formalise maintenance activities
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C O N F I D E N T I A L
1 Who is T.D.Williamson?
2 What is EPRS?
3 Onshore EPRS3 Onshore EPRS
4 Offshore EPRS
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Main difference Offshore vs. Onshore pipelines:
Difficult Accessibility
C O N F I D E N T I A L
0
100
200
Sha
llow
300
400
500
600
700
800
900
1,000
1,100
Dee
p W
ater
Wat
er D
epth
[m]
British Gas SIMIAN/SIENNA 105 km 1,040 m
Texaco GEMINI 45 km 1,063 m
British Gas SCARAB/SAFFRON 90 km 650 m
Enterprise CORRIB 97 km 350 m
Shell EUROPA Norsk Hydro ORMEN LANGE
Statoil SNØHVIT170 km350 m
Reliance KG D6100 km1000 m
Nord stream1000 km210 m
Diver limit
Example of a pipeline profile
Trends in Offshore Pipelines
1,100
1,200
1,300
1,400
1,500
1,600
1,700
1,800
1,900
2,000
2,100 Ultr
a D
eep
Wat
er
Wat
er D
epth
[m]
2,200
0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200
Tie-back Distance [km]
ExxonMobil MICA 47 km 1,326 m
TOTAL CANYON EXPRESS 92 km 2,198 m
1,040 m
Shell MENSA 109 km 1,615 m
Shell EUROPA32 km
1,158 m
Gas development
Oil development
Norsk Hydro ORMEN LANGE120 km1,100 m
Longer pipelines
Deeper water
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C O N F I D E N T I A L
Incidents of Offshore Pipelines/Risers Gulf of Mexi coto 2004
601
500
600
700N
umbe
r of I
ncid
ents
Occurrence Index
Damage AssessmentOFFSHORE
322
218 210153 137
67 65 4217 10
0
100
200
300
400
Corro
sion
(Inte
rnal
)
Natur
al H
azar
ds
Impa
ctUnk
nown
Corro
sion
(Ext
erna
l)
Structu
ral (
Design
)M
ater
ial D
efec
tLin
e Plug
gage
Ancho
ring
Constr
uctio
nEro
sion
Failure Cause
Num
ber o
f Inc
iden
tsto
tal 1
842
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C O N F I D E N T I A L
Corrosion Dry Buckle
Paraffin Scale Hydrate Plugs
Failure Mechanisms & Damage types
Anchor DragsImpact Damage33
C O N F I D E N T I A L
BP CATS Anchor Drag
Anchor Damage Example
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Transmed Anchor Drag
Kvitebjorn Anchor Drag
RECENT ANCHOR DRAGS
High (difficult) Detection IndexDamage not seen in 2006Damage detected in 2007
BP CATS Anchor Drag
C O N F I D E N T I A L
50100150200250300350400450500
Risk Priority Index= Occurrence x Severity x Detection
Risk Priority Index (Operational) – GoM
• Highest index of 350 to 450: Anchor snag
• Others with high RPI : Buckling; Dropped objects
• Corrosion nowhere to be seen
High Risk Priority Index
OFFSHORE
050
Ancho
r Sna
g (Wet
Buckle
)
Ancho
r Sna
g (Dry
Buckle)
Thermal B
uckli
ng (D
ry)
Dropp
ed O
bject N
ear P
latfor
m (W
et)
Dropp
ed O
bject A
way F
rom
Platfo
rm (W
et)
Thermal B
uckli
ng (W
et)
Dropp
ed O
bject N
ear P
latfor
m (D
ry)
Mud
slide B
reak (
Miss
issipi
Cany
on)
Paraffin
Acc
umula
tion
Dropp
ed O
bject A
way F
rom
Platfo
rm (D
ry)
Inlin
e Equ
ipmen
t Fail
ure:
valve
s, fla
nges e
tc
Dropp
ed O
bject N
ear P
latfor
m (D
ent)
Dropp
ed O
bject A
way F
rom
Platfo
rm (D
ent)
Hydra
te For
mati
on
Source: Deep Water RUPE Report 35
C O N F I D E N T I A L
Pipe content management
Find the Damage
Damage Assessment
Damage Finding / Locating System
Pin hole leak;Piggable dent
Minor Internal Blockage
Wax or HydratesNon-piggable dent;
Rupture
Major
Suspend Flow
Rupture?
Bypass
NO YES
Suspend Flow
Controlled DECOM
Uncontrolled Flooding
Continue Flow(Shallow water)
Replace pipeFabr/ Lay
Repair
management
No Cut out
Leak RepairClamp
StructuralClamp
No Cut out
Chem Injection System(+ Hot Tap)
Re-commissioning
Cut out
HyperbaricWeld
FlangesIn-Line
ConnectorsSurface
Lift&Tie-in
Re-commissioning
Hot Tap Stopple
Pipeline Isolation
Short - by DSV Long - by Laybarge
C O N F I D E N T I A L
Temporary Isolationto preserve inventory
SmartPlug® Isolation – Preventive Measure
Repair Scenario – Damage Limitation
Operated
by
Total
24” SmartPlug in
new line being laid
36” SmartPlug in
existing export line 37
Total
C O N F I D E N T I A L
TDW Remotely OperatedClamp Installation Tool
Repair Clamp
Repair Scenario – Minor Damage
38
C O N F I D E N T I A L
Bypass – with Hot Tap & STOPPLE isolation
Required Material & Equipment:
• Hot Tap & Plugging
Repair Scenario – Major Damage
Leak Cut-Out – with SmartPlug isolation
39
• Hot Tap & Plugging • Fittings• Clamps• Isolation Technology• Marine spread
C O N F I D E N T I A L
Surface Tie-in
Repair Scenario – Major Damage
• Cut out damaged section• Recover each end onto
laybarge• Re-lay with overlap• Lift both ends & weld• Lay over
40
Required Material & Equipment:
• Isolation technologies• Marine spread
C O N F I D E N T I A L
Deep Water Pipeline Repair DW RUPE
Repair Scenario – Deep Water
Source: Deep Water RUPE Report 41
C O N F I D E N T I A L
Deep Water Flowline Repair DW RUPE
Repair Scenario – Deep Water
42
C O N F I D E N T I A L
Typical EPRS Pre-investments
� EPRS Study : - Establish Risk Priority - Establish overall EPRS scenarios and needs
� Saving Time : - Establish Framework Agreement for aerial / subsea surveys - Pre-invest in critical Long Lead materials,
e.g. line pipe; clamps; fittings.
Critical
� Impact – Anchors, Dropped objects� Leak study – rupture, water ingress� Decomm/Re-comm� Repair options – isolation, cut-outs� Procurement – materials, spreads� Project organization
Offshore
e.g. line pipe; clamps; fittings.
� Saving Costs : - Framework Agreement for marine spread & equipment -- Develop Repair Scenarios for rapid execution (SmartPlug Tool)
� Saving Pipe Inventory : - Pre-invest in Isolation, Bypass , Hot Tap equipment- Pre-invest in Decommissioning/Re-commissioning needs
43
C O N F I D E N T I A L
Case Study Offshore EPRS
44
C O N F I D E N T I A L
An operator in Malaysia identified a leaking clamp on a 24-inch subsea gas pipeline operating at 750 psi in 70 metres water depth. TDW launched two SmartPlug isolation tools separated by inhibited
seawater to straddle the defect to allow it to be cut and replaced.
After the cut, each end of the pipeline which was isolated at 750 psi was lifted to the surface in order to weld a flange onto the pipeline,
because the operator did not want to install gripped flanges.
After the cut, each end of the pipeline which was isolated at 750 psi was lifted to the surface in order to weld a flange onto the pipeline,
because the operator did not want to install gripped flanges.
Mini Case Study: Malaysia Midline Repair
After lowering the ends, a spool piece was inserted and bolted to the flanges.
After lowering the ends, a spool piece was inserted and bolted to the flanges.
45
C O N F I D E N T I A L
Mazara
Case Study: TransMed Anchor Drag
46
C O N F I D E N T I A L
TransMed Pipeline System
1 S
2 S
Damage Consequence
Line 3S completely severed Line 2S dented and lifted out of trench
Line 3S completely severed Line 2S dented and lifted out of trench
3 S
4 S
Blue : Pipelines before the incidentRed : Pipelines after the anchor drag
47
C O N F I D E N T I A L
Damage Consequence
Cut out sections of the damaged 26” gas lineCompelling evidence of the severe consequences of anchor drags
Cut out sections of the damaged 26” gas lineCompelling evidence of the severe consequences of anchor drags
48
C O N F I D E N T I A L
POST-EVENT SCENARIO ANALYSIS
Damage Type Characterization
Physical Characterization
Pipeline Operating Condition
Expected Downtime Range
Downtime Mitigation Measures
Pigable Dent (Buckle) |
< 10% reduction in P/L I.D.
Pipe remains dry and pressurized
None initially, 4 weeks during
Temporary Repair clamp
Repair Scenario
This was an emergency repair, no EPRS was in place
(Buckle) | in P/L I.D. and pressurized weeks during repair and RTO
clamp
Unpiggable Dent (Buckle)
20” Line
> 10% reduction in P/L I.D.
Pipeline remains dry and pressurized
2 weeks initially during damage assessment, then 6 weeks during repair and RTO
Temporary repair clamp
Rupture
26” Line
Unpigable inline, penetration of pipeline wall
Release of gas, possible localized flooding of pipeline
Immediate shut-down, 10 weeks to repair and RTO
49
C O N F I D E N T I A L
Surface Tie-in
• Prepare pipeline
Repair Option selected – Surface Tie-In
• Prepare pipeline• Cut out damaged section• Recover each end onto
laybarge• Re-lay with overlap• Lift both ends & weld• Lay over
50
• Equipment delivery wasrequested to be in 6 weeks• The company chose a totally diverless repair
C O N F I D E N T I A L
TDW SmartLift ™ Customised SmartLift TM
Pipeline Recovery Tools.Inserted at the cut end
Functions:
Isolation Option to manage pipeline inventory
Functions:- Isolation tool- Pig launcher/receiver- Lifting head
51
C O N F I D E N T I A L
Summary Repair Sequence
52
C O N F I D E N T I A L
Details of 20” Isolation sequence
• Run & set Barrier pigs
Dent
• Pigs running into PRT catcher• PRT ready for lifting operation
• PRT inserted
53
• Pipeline cut
C O N F I D E N T I A L
Specialized 20” Barrier Pig
•Estimated 14% Reduction at dent location.•Pig designed for 20% reduction. (16” ID)
TDW SmartTrack TM system - critical to the isolation :
� ATEX approved transponder mounted in pig body� ATEX approved transponder mounted in pig body� Two-way through-wall communication� Electromagnetic signals� Wireless communication - transponder & transceiver� +/- 5cm accuracy.� Data provided through-wall on internal pressures
Remote transceiverTopside Transceiver& PDA Eexd
54
C O N F I D E N T I A L
Diverless Installation
SmartLift TM Pipeline Recovery Tools
55
C O N F I D E N T I A L
Pigging Activity
Recovery of Barrier Pig & PRTOn-board Pig Detection Screen
� Pigging distances 150km in dry gas� Zero on-site safety incidents
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C O N F I D E N T I A L
Decommissioning / Recommissioning Spread
� 700t of Equipment� 2 x Air/N2 Spreads capable ofdelivering 6000 scf/m 70 bar and dewpoint of - 40oC
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C O N F I D E N T I A L
� Growing trend among operators to develop an EPRS
� Planning and essential investments must be made in advance
� Differences in approach between Onshore & Offshore EPRS:
o Focus for Onshore on:� Investment in equipment , inventory, resources
Overall Conclusions Onshore & Offshore
� Investment in equipment , inventory, resources
o Focus for Offshore on:� EPRS Study – complex scenarios� Realistic emergency cases ranked by Risk Priority Index� Frame Agreements to cut long response times� Management of pipeline inventory: isolation & bypass vs.
DECOMM/RECOMM
� Common point between Onshore & Offshore EPRS:
Think Ahead 58