Frequently asked questions
We have created this list of frequently asked questions about CAN technology and the operational benefits.
These are designed to provide a top level overview, so please get in touch if you would like further information or wish to discuss any specific questions regarding the use of CAN.
WHY use CAN?
CAN has been proven in 20 installations to benefit:
- Cost optimisation:
- Reduces costs through reduced rig time for top-hole drilling and conductor installation
- Creates a cost effective single/dual well template
- Risk mitigation:
- Reduces risks on mobilization, lifting and handling of heavy conductor pipe
- Improves fatigue management and increased load carrying capacity
- Environmental footprint reduction:
- Eliminates cuttings and cement disposal from conductor installation
- Reduces CO2 and NOX emissions due to rig time reduction
- Technical enabler:
- Enables shallow kick offs for shallow reservoirs
- Solves the challenge of wellhead support in soft seabed conditions
What is the financial value case / cost savings?
- Removes 1-3 rig days from the schedule resulting in saved rig time
- Simplified and more rig-efficient P&A
- Reduced rig time / drilling scope
- Onshore pre-mounting of SURF & SPS-equipment
- Reduced project execution time
- Accelerated first oil
- Non-productive time risk reduction
How does the CAN technology reduce risks?
- Pre-installed conductors result in:
No risk of conductor equipment or cementing failure issues
Better control of inclination issues => (WOC / re-spud)
Better control of fatigue issues and related reduced operability
Less equipment and services means:
No mobilization or handling of spud bottom hole assembly & conductor equipment
No conductor cementing operations
No cementing crew for conductor, less bulk/equipment handling on the rig or supply vessel
Simplified and reduced rig time for P&A
Reduction of ‘Open Water operations’ (= spud to running Riser/BOP)
Reduces risks of WOW, ROV and other NPT during spud
What is the HSE value case?
- Risk management according to the ALARP principle
- Reduced mobilization and lifting/handling of heavy equipment (supply base, vessel & rig)
- Reduced environmental footprint
- Reduced volume of cuttings requiring disposal
- No cement or mud for conductor
- Proven functionality with Riserless Mud Recovery equipment
What is the projected time from PO to delivery?
Development wells: 16-24 weeks (this is based on the assumption of 1-3 units, delivery time for more units available on request)
What are the manufacturing locations?
To date CAN's have been manufactured in Norway and Indonesia, however the CAN is suitable for local content, if fit for purpose fabrication is available.
What water depths has CAN been run in?
Projects to date have been carried out in water depths from 100-1500 m.
What is the shallowest kickoff from a CAN?
What seabed conditions are suitable for a CAN?
It's possible to install a CAN in a variety of seabed conditions and we use NGI, Norwegian Geotechnical Institute, for all geotechnical engineering to determine the suitability of the seabed for a CAN. NGI has performed geotechnical design and installation of more than 700 suction anchors globally, both for the oil and gas industry as well as for offshore wind.
To date most CAN installations have been performed in clay type formations:
- Clay 20 installations
- Soft calcareous limestone 1 installation
- Mixed layers of sand and clay 1 installation
- Sand 1 installation
If you have further questions about CAN technology or our subsea solutions then please get in touch.