Pipeline Design & Installation Systems Rigid pipeline subsea tie-backs – new operational challenges
Paul Georgeson – Operations Support ManagerWood Group Kenny
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- Overview
- Materials
- Inspection
- Monitored data
- Maintenance
and repair
Agenda
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Assets
FlowlinesPipelines
2013-172013-17
820820820820 km
2,400 2,400 2,400 2,400 km
Source: Douglas Westwood
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Areas
Source: Geological Survey of Queensland
Operational regions
- predominantly Carnarvon
basin
- expanding into:
- Browse
- Bonaparte
- possibly Canning and the
Bight
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ChallengesConsiderations for operations
- New depths, cold seawater, hydrates
- Scarp crossings (through, around, over)
- Pipelines passing through new regions
- Design lives > 30 years
- FLNG operating regimes
- Aggressive fluids - CO2, H2S
- High temperatures
Scarp crossing
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Tem
pera
ture
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Materials
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Corrosion
- water (wet gas) + CO2 = carbonic acid (pH 3.8)
- increased temperature and pressure = increased reaction rates
Erosion
- Velocities in excess of 30 m/s
Has led to
- change of materials from carbon steel to a CRA
- chemical injection
- pH stabilisation - change nature of the produced fluid
- corrosion inhibitors - barriers via injected film formers
Material selection - internals
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Lined and clad pipe and spools, various CRA materials primarily 316L, 625, 22cr
Weld materials, can be driven by contractor experience / preference:
- 622 root, 686 fill and cap
- 625
- 309L
- 22 Cr
Design considerations:
- Qualification / historical design temperatures of CRA material
- Overmatching challenge for some nickel weld consumables at high temperature
Corrosion resistant alloys
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Hydrates
- Driving key decisions around external coatings for wet gas flowlines
- Rapid cooling -> hydrates
Wax
- Keep temperatures above wax appearance temperature
Top of line corrosion
- Prevent condensation and water drop out by keeping hot
Has led to
- Keep it hot -> insulated lines, MLPP
- Let it cool -> continuous MEG injection, MEG regeneration plants
Material selection - externals
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Inspection
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Operations – In-line inspection (ILI)
- confirm internal pipeline condition via in-line inspection
- work with regulators / licence requirements
- manage challenges with schedule and plant considerations
such as liquids arrival (flow assurance)
- utilise subsea corrosion / erosion monitor data and
production chemistry data to justify ILI timings
Pre operations
- sample during dewatering for water chemistry and
bacteria / biocide residuals
Corrosion / erosion
Source: Rosen
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Expansion
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Planned buckle ‘design’
- DIs – displacement initiators (dumb or mechanical)
- ZRBs – zero radius bends
Expansion
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Considerations – pre start-up
- Pre start-up inspections, checking for:
- burial around touch down points
- third party interaction
- Possible interventions to remove
seabed material built up around touch
down points
- Recording details of spans either side of
DI
Expansion
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Expansion
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Operations to specify data collection
- global positional data - specifically
buckle shape (x, y, z) survey data
- seabed heights adjacent to pipe and
at set distance from top of pipe
- lateral displacement at DI
- axial movement at DI
- conditions of DI surfaces due to
movement
Expansion
Pipeline crossing DI
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Operations considerations
- global location check campaign to
campaign (drafting, GIS, cloud point
data, etc)
- compare positional data at DI to
operational conditions at the time of
survey / inspection
- run FEA models of buckle shape (x, y, z)
from survey / inspection data – check
stresses and strains
Expansion
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Asymmetry in the expansion / contraction
Drivers:
- Temperature transient
- Seabed slope
- End tension
- Liquid hold up
Axial walking
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Operations to specify data collection
- check location of structure on
foundation - end terminations
designed to move
- check position of spool / flowline
interface flange / connector
- future intervention if required
Axial walking
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Operations
- record complete operational history of start-up / shut downs and link to
structure locations
- understand spool loads based on position of structure (and associated
connector) and location of spool / flowline connector
- model future movements to ensure they remain within design parameters
or plan for any intervention requirements
Axial walking
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Monitored data
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Managing data is key, especially with long design lives
Make systems as automated as possible
- Define integrity operating windows (IOWs)
- Production chemistry
- MEG system + pH stabilisation / corrosion inhibitors
- Water chemistry
- Erosion / corrosion monitoring systems
- Velocities / temperatures / pressures
Regular reporting / dash boards summarising data and asset condition
Data management
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Data recovered from interventions
- monitoring of spans / structures / spools
- collect data for pipelines / riser motions in operations where there are fatigue
concerns
Understand met ocean conditions
- impact of currents, solitons, tides, cyclones on subsea assets
Understand influence of operations on assets
- impact of production regimes, slugging, flow rates on motions / vibrations
Data collection from interventions
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Maintenance and Repair
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Reaching critical mass for:
- formation of a ‘repair club’
- equipment sharing
- tool pool
Still CRA repair challenges
Storage and location of CRA and CS pipe will be important
Smaller pipelines may be as critical as the production system (4 - 8” MEG / Utility lines)
Significantly high pressures in smaller lines, worth spending time considering spares /
repairs options
Pipelines
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- Number of operational challenges which are pushing industry boundaries
- Pre-start up data capture critical to understanding asset baseline condition and
managing future decisions
- Management and analysis of inspection and monitored data will be key in early field
life, ensure all calibration work undertaken (project to ops)
- Legislative framework to be managed
- Longer term larger interventions will be critical and require significant planning
- Challenge to industry to ensure Operators get the support and value required
In summary..