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Agenda
• Why Casing Directional Drilling
• Using a drilling test facility
• Surface and downhole tools
• 7 5/8-in. test objectives and results
• 10 ¾-in. test objectives and results
• Conclusions• On to Eldfisk
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Types of Casing Drilling 2000+ Casing Sections
51%
31%
18%
Non-Retrievable
Liner Drill ing
(TD liners and
trouble zones)
Non-Retrievable
Casing Drill ing(conductors, vertical to TD
and drillable bits)
Retrievable
Casing Drill ing
(directional, distance andformation evaluation)
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O1
O3O2
CD
(SPE 79862)
Casing While Drill ing
Eliminates Lost Circulation Problems at Lobo
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Key Question
“ Can the straight hole benefitsrealized in the Lobo Field be
transferred to directional drillingoffshore?”
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Casing Drill ing Benefits
• Casing while Drilling reduces trouble time (losses,
sloughing and sticking). . . . The “smear effect”
• ConocoPhillips and others want to apply this benefit
to high cost environments (North Sea, Alaska, Gulf of
Mexico) - Efficiency savings typically are 15%
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2005 Test Plan Objectives• Objectives
1.Prove casing directional drilling capability with rotarysteerables in larger hole sizes.
2.Directionally drill with the new casing sizes similar toEldfisk (10-3/4” & 7-5/8”)
3.Provide information for training and regulatoryprocess that will ensure a successful introduction intooffshore Norway.
4.Perform casing drilling operations on a non-Tesco rig.
5.Test benefits of casing drilling to reduce NPT outsideof South Texas.
6.Evaluate ability of casing drilling to make drillingoperations cheaper.
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Split Block
Swivel with space for
Wireline BOP
Top Drive System
Casing Drive System
10 ¾-in. casing
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7 5/8-in. Casing Drive System
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10 ¾-in. Casing Drive System
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Downhole Tools
• Casing Profile Nipple (CPN)
• Drill Lock Assembly – connects BHA to
Casing
• Straight Hole Motor
• Underreamer
• MWD – must be battery powered• Rotary Steerable System
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internal
tandem
stabilizer
Casing Dir.
Dril ling BHA
Non-Directional
Motor
Motor Bit Box
9-7/8“ Under-reamer
Roller Reamer
Stabilizer
MWD
System
Vibration subRotary Steerable
System
PDC Bit
7-5/8"
casing
shoe
DLA STD Vertical
Dril ling BHA
Underreamer
Tandem
Stabilizer
PDC Bit
Casing While Drill ing BHA Designs
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7 5/8-in. DLA
(Drill Lock Assembly)being added to the
BHA
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Housing Sub for Vibration Sensors
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Testing Objectives
• 7-5/8” test mainly to test the function of thenew DLA’s - both setting and retrieval
• 10-3/4” test mainly to prove directionalperformance and gain drilling mechanics
data
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7-5/8” Test Plan
• Run and retrieve Drill Lock at 0, 45 and 90degrees
• Drill 1000’ of lateral
• Turn at 1.0 deg/100’ right
• Turn at 3.0 deg/100’ left
• Collect Drilling Mechanics data
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7-5/8” Test Results
• Over half the test time and cost devoted to
rig up and down of equipment• DP retrieval cancelled – tool not designed
for purpose
• High solids mud test not done – first testdemonstrated where solids could settle
• DLA performance good in all angles• Test highlighted the need for wire release
from the running or retrieval tools
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0
500
1000
1500
2000
2500
0 500 1000 1500 2000 2500 3000 3500
Displacement (azi=152) (ft )
T V D
( f t )
Test 5
Drill 850 ft HZ
Test 1
Test 2
Test 3
Test 4
Horizontal Well Trajectory for 7 5/8”
Casing Directional Drilling (CDD) Tests
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Landing the Bit 7 5/8” CDD Test
0
50
100
150
200
297 298 299 300 301 302 303 304
Rig Time (hrs)
v a r i o u s
3820
3840
3860
3880
3900
3920
3940
D
e p t h s
( f t )
torque
pump
pressure
RPMs
depths
Landing
Under-reamer
Drilling ahead
flowShock sub
G’s
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0
2000
4000
6000
294 300 306 312 318 324 330
Rig Time (hrs)
R S
S S H K / m i n
0
10
20
30
40
50
60
70
80
V i b
s u b G ' s
Landing
Under-reamer RSS
shocks
Vib subG’s
Shock Data for Entire 7 5/8-in. CDD run
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10-3/4” Test Plan
• Test set and retrieve new 10-3/4” Drill
Lock
• Dress off kick off plug
• Kick off from vertical and build at a lowbuild rate between 0.5 to 1.0 deg/100’
• Increase build rate to 3.0 to 3.5 deg/100’
• Build to 50 deg and turn 50 deg azimuth
• Collect Drilling Mechanics Data
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10-3/4” Test Results
• Majority of the test was taken up indetermining DLA/CPN deficiencies
• Only 842’ drilled
• Further field testing of the 10-3/4” DLAwas done to qualify redesign
• Directional control was demonstrated to be
similar to DP drilling• Motor speed and torque output at low
flows is still an issue
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10-3/4” Test Results - 2
• Downhole recorded mechanics data
revealed trends that need to be followed
up on
• Significant time and cost required to outfitthe rig and then rig down
• Test site allowed the project to be
managed for 12 and 24 hour coverage
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0
500
1000
1500
2000
2500
3000
3500
4000
4500
-500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000Disp azi=167 (ft)
T V D
( f t )
Plan View Trajectory at Cameron
for 10 3/4” Casing Directional Drilling Tests
13 3/8” csg @2003ft
KOP: Build to 50 deg testing different rates (planned)
TD 5000ft
Casing Directional Drilling
9 ½” pilot hole
12 ¾” under-reamed hole
Actual Total Depth of the test was 2966 ft, with 15
degrees of inclination built.
(planned depth)
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Directional Drilling Observations
• Directional performance went well, as expected.
• The low curve rate test at 0.5 deg/100ft had a
0.9 deg/100ft rate
• The high curve rate test at 3.5 deg/100ft had a
3.4 deg/100ft rate
• Higher curve rates are possible as results were
not seen for a 100% setting of the RSS.• No rotary steerable system damage was seen or
reported.
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Directional Performance 7 5/8” CDD Test
80
82
84
86
88
90
92
94
96
98
3600 3800 4000 4200 4400 4600
MD (ft)
I N C L
( d e g )
140
142
144
146
148
150
152
154
156
158
A Z I ( d e g )
Tool setting108@
40%
Tool setting
247@60%
Tool setting
0@10%
Inclination
Azimuth
Left Turn TestPlan: 3.0 deg/100ft
Actual 4.3
deg/100ft
Hold Test
L ef t
Ri gh t
Right Turn Test
Plan: 1.0 deg/100ft
Actual: 1.4 deg/100ft
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10-3/4” Directional Performance
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Conclusions• The two casing directional drilling tests were a cost
effective “dress rehearsal” for Eldfisk Norway.
• CDD technology was successfully transferred tonew casing sizes.
• Modifications to downhole tools have been made
and successfully tested (Lobo March 06).• A rotary steerable system in the pilot hole provides
effective directional control in CDD.
• Vibrations in the BHA are better understood, theireffects have been reduced, but they are still aconcern.
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On to Eldfisk
• Two directional wells to +/- 50 degrees arescheduled for Oct 2006.
• 10 ¾-in. CDD to 5100 ft (MD)• 7 ¾-in. CDD to 11800 ft (MD)
• Wells to be drilled from a common
wellhead.
Rig Modifications – Winch Platform &
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Rig Modifications Winch Platform &
Traction Winch System
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Rig Modifications – Crown Sheaves
Rig Modifications – Wireline BOP & Split
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Rig Modifications Wireline BOP & Split
Block
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From Texas to Norway 2/7 Eldfisk Bravo