OMAE 2008-57047 Offshore Drilling Riser VIV Suppression...
Transcript of OMAE 2008-57047 Offshore Drilling Riser VIV Suppression...
1OMAE2008-57047
OMAE 2008-57047 Offshore Drilling Riser VIV Suppression Devices
What’s Available to Operators?Samuel Taggart & Mike Tognarelli –
BP America June 2008
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Deepwater Drilling in Loop Currents
Operational Issues :
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Types of drill rig – DP and Moored – manoeuvrability
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In combination with hurricane season – retrieval ability
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Production drilling over subsea architecture – consequential damage
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Unproductive drilling time – 2005 many tens of millions of dollars
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Improving Drilling Operations in High Currents
A company equipment review produced two main areas of interest :
1. Riser devices that decrease drag and suppress VIV
2. Development of improved mechanical drilling riser centraliser - Increases the operational window for retrieval of riser- Particularly important during hurricane season- To be deployed for operation in 2008
This paper will address the work done in the area of available devices for drag reduction and suppression of VIV
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FLOW DEVICES –
Summary History
Types of flow improving devices:
Passive Devices
• fairings, shrouds, etc.
Active Devices
• Air, water jetting,etc
Drilling Riser hard up against
diverter housing in a 2 knot current
The BENEFITS
• Reduce drag - Riser top and bottom angle
• Suppress VIV – Riser vibrations
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Some Passive Devices
Passive Devices
• Fairings (rigid)• Deformable Shrouds• Buoyancy Modules
• Distribution• Helical Grooved
• Axial Rod Shrouds• Perforated Shrouds• Windings / helical wraps• Hoops / Spaced Spoilers• Fins / Bumper Bars• Splitter plates• Bumps / Waves AIMS Splitter
Full fairing
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Passive Devices, cont’d
Inverted Helically Grooved buoyancy
Wavy Buoyancy profileAxial Rod Shrouds
Perforated Cylindrical Shroud
Lankhorst Fins on Drilling Riser
Helical Rope Wrap
Hoops / Spaced Spoilers
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Operational Device Review -
Findings
Nearer Term most favourable options for operation
1. Fairings (rigid) – various designs and associated performance claims2. Fairings (flexible) – prototype construction underway3. Fins / Bumper bars – designs in use4. Helical Wraps – previously used as temporary mitigation
All but one in use today on GoM Drill Rigs
Benefit Decision for Deployment
a. Performance – dynamic behaviour benefit ?b. Robustness – survivabilityc. Marine logistics – container transfer , storage and available work areasd. Deployment/Recovery efficiency – time management GoM Hurricane impact e. Mechanical Handling – Crew resources, cross lifting, rig modificationsf. Health/Safety/Environment – dropped objects, failure risks and consequence
Need to perform an Operational Benefit Analysis – Numeric (Time / Cost)
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Fairings –
Need for Performance Acceptance
To help understand and clarify Fairing Performance against Claims
1. Establish a performance acceptance criteria for fairing products(i.e. see paper for specifics)
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Drag Reduction level set•
VIV Suppression , Stability and Motion Amplitude
2. Invite suppliers to put forward products for large scale BP proving tests
Two fairing suppliers came forward with products
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AIMS Inc. – Dual Fin Splitter Fairing•
Trelleborg Offshore – RiserFin Fairing
3. A 3rd company Allbrown also requested proof of concept tests on their flexible fairing -
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Fairings –
Acceptance Model Tests
• Performed at Institute for Ocean Technology in St. John’s – Free Vibration on Springs
• Specific deepwater drilling riser (OD=1.33m) scaled to 0.24 for tests
• Model test matrix targeted for full scale ranges of Re and VrnModel Cylinder
0.00
5.00
10.00
15.00
20.00
25.00
1.00E+04 1.00E+05 1.00E+06 1.00E+07
Reynolds Number
Red
uced
vel
ocity
0.25 Hz0.50 Hz0.75Hz1.00Hz1.50Hz2.00Hz3.00Hz
`
• Comprehensive fixed and freely vibrating tests performed • Bare pipe benchmarking tests• 2 Off fairing type acceptance test sets
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AIMS Dual Fin Splitter -
ADFS
AIMS Splitters Installed and Prepped for Testing
(88% Coverage Including Dummy Section)
Fairing SectionThrust collar
Endplate
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Trelleborg RiserFin Fairing
Fairing Section
Thrust collar
Endplate
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Fairing Results + Conclusions
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Both Fairing Products tested satisfied the ‘Acceptance Criteria’ for Drag Reduction and VIV suppression
• Typical drag coefficient (Cd) were around 0.6 with good VIV suppressionDrag Cofficient vs. Reynolds Number
AIMS Fairing
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
1
0 200000 400000 600000 800000 1000000 1200000 1400000 1600000 1800000Reynolds Number (Re)
Dra
g C
oeffi
cien
t (C
D)
Fixed (rough)Free (rough)Fixed (polished)
Drag Coefficient vs. Reynolds NumberCRP Fairing - Free Vibration
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
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0 200000 400000 600000 800000 1000000 1200000 1400000 1600000Reynolds Number (Re)
Dra
g C
oeffi
cien
t (C
d)
Free Test Poly. (Free Test )
Amplitude ration vs. Nominal Reduced VelocityAIMS Fairing
0.00
0.02
0.04
0.06
0.08
0.10
0 5 10 15 20 25 30Nominal Reduced Velocity (U*)
Am
plitu
de R
atio
(A*)
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VT Fairing –
Concept Proving
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Operational target is to get over some of the downside impact of working with rigid fairing – lighter , flexible , easy storage , less work area demand
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Concept proving model tests completed at University of Southampton – limited Re range tested
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Results showed that VT highly effective at suppressing VIV with reduced dynamic drag loading
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Full Scale Operational Experience
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Model tests indicate benefit but how do fairings perform for real ?
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BP measuring and monitoring behaviour of deepwater drilling risers for a number of years
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Two drilling campaigns have been under taken with different types of fairings (SGSI designs)
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Indications are that the fairings did suppress VIV behaviour in higher current situations
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GSF Explorer Drilling Riser
Fairings Data:
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7 buoyant joints equipped with fairings
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Shell Global Solutions, Inc. (SGSI) -
full wrap fairings
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Chord/Diameter (C/D) Ratio: 1.5
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Length: 6 ft
Monitoring Data:
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9 months of monitoring
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VIV occurs 1.6% of time
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Max current below 0.5 knots except for period of 21st
July to 27th
July 07 when a max current speed of 2.1
knots observed
11 Slick Joints WT =0.875"
BOP
LMRP
Lower FJ
21 joints 3000ft rating Buoyancy
13.0 ft ––––––
Seabed
39.0 ft ––––––
62.8 ft ––––––
1187.8 ft ––––––
MSL 4595 ft
Well head
4 Slick Joints WT =0.750"
887.8 ft ––––––
1637.8 ft ––––––
Drill Floor
Intermediate FJ
Termination Joint & Pup
Tensioner Ring
Outer Barrel
Inner Barrel & Pup Joint
Diverter & Upper FJ
4542.8 ft ––––––
4669 ft
4620 ft ––––––
4647.8 ft ––––––
4412.8 ft ––––––
6 joints 5000ft rating Buoyancy
3887.8 ft ––––––
7 joints 3000ft rating Buoyancy with Fairings
Staggered section 4 jts 3000ft rating Buoyancy 5 jts Slick
3212.8 ft ––––––
36” & 28” Conductor (157.5 ft)
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Ocean Confidence
Drilling
Riser
Fairings Data:
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14 buoyant joints equipped with fairings
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SGSI -
tailfin fairings
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Chord/Diameter (C/D) Ratio: 1.45
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Length: 6 ft
Monitoring Data:
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2 months of monitoring
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VIV occurs 4.1% of time
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Max current speed: 0.95 knots
35 ft Termination Joint
BOP
LMRP
Lower FJ
10 ft ––––––
Seabed
63 ft ––––––
473 ft ––––––
MSL 4065 ft
5 Slick Joints
2273 ft ––––––
Drill Floor
Intermediate FJTermination Joint & Pup Joints
Tensioner Ring
Outer Barrel
Inner Barrel
Diverter & Upper FJ
4033 ft ––––––
4153 ft
4112 ft ––––––
4135 ft ––––––
3998 ft ––––––
24 joints 5000ft rating Buoyancy
3173 ft ––––––
Well head
98 ft ––––––
12 joints 3000ft rating Buoyancy (3 Top joints with Fairings)
11 joints 2000ft rating Buoyancy (with Fairings)
1125 ft of Fairings
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Conclusions
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Fairing performance has been demonstrated to various levels of rigor
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The final choice for fairing use on a drilling riser for a particular well location tends to be a pure
Cost / Benefit Decision
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Recommendations:
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Operability analyses using fairing performance data
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Cost-benefit analysis: “saved”
downtime vs. “lost”
trip time and handling / storage issues
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Attention to minimizing “lost”
time in fairing designs