perforacion direcconal
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An Introduction toDirectional Drilling, For
Technical ProfessionalsTony Pink
Drilling Training Manager,Schlumberger
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Historical background
What is Directional Drilling?
Why do we need Directional Drilling?
How do we deflect wells from vertical?- Jetting
- Whipstocks
- PowerPak* Motors
- PowerDrive* Rotary Steerable system
Introductio
n
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-the 1930s
1st controlled directional wells drilled
(initially for unethical proposes, to cross property lines)
- Huntington Beach, California
- 1934
Controlled DD was used to kill a wild well.
Beginning of controlled DD Conroe, Texas
Historical Background
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Significant Events
Measurementdevelopment
1930 Magnetic Single Shot
(survey after drilling)
1970s Steering Tool
(survey while drilling)
1980 MWD
(mud pulse telemetry - nowireline)
1980s LWD
(log quality MWD)
1990s GeoSteering
Drilling Tooldevelopment
1960s Mud Motor
(versatile kick off tool)
1980s Steerable Motor
1988 Horizontal Drilling
(drilling for drainage)
1999 Steerable RotaryDrilling
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What is Directional Drilling?
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Directional Drilling is the engineering effort
of deviating a well bore
along a planned course to
a subsurface target
whose location is a given
lateral distance and
direction from the vertical.
Definition
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Why is there a need for
Directional Drilling?
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Why Directional Drilling
Inaccessible Locations
Salt Dome Drilling Fault Controlling
Sidetracking
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Why Directional Drilling
Relief Well Drilling
Horizontal Drilling
Single Surface Location
Multi-Laterals
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Deflection Devices
Tools & Techniques to deflect the
course of the well in a controlled
manner, (overcoming natural
tendencies)
Kick-off, nudge (build angle from vertical to a desireddirection)
Trajectory correction (turn, build, drop to the desiredtrajectory)
Sidetrack (deflect the well from its original course)
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Deflection method 1
Jetting Used in soft formations
One large bit nozzle orientedto the desired direction
Near Bit Stabilizer and limberassembly
Wash a pocket in theformation
Spud and rotate, wash, untilangle is built
Continue building with rotaryBHA
Azimuth corrections more
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Deflection method 2
Open Hole Whip-stocking Used in medium to hard
formations Bit, NB Stab. pinned to whip and
conveyed to bottom Tool Face oriented
Whip is wedged on bottom andpin sheared
Undersized pilot hole is drilled
Only one joint drilled beforePOOH the BHA
Pilot hole opened up andprocess repeated
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Deflection method 3
PDM First commercial PDM
Hydraulic power to Mech. power
driving the Bit String kept stationary - only sliding Bent sub above motor provides side
force to the bit
Deflects the hole trajectory - kick-off
from vertical, sidetrack, correctionrun, etc.
Very efficient when compared to
contemporary deflection devices,
(jetting, whipstocks ..)
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Deflection method 4
RSS
Rotary steerable can work from
vertical
Drill off gravity toolface
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Drilling Ahead
D illi h d ft th Ki k
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Rotary Drilling Uses the horsepower from the rig directly down through the
drillstring
Deviation is controlled by the deflection of the drillcollars
Deflection of the drillcollars is controlled by stabilizers
Steerable motor drilling Uses hydraulic pressure and flow to give additional rotational speedat the drillbit
Setting a bend in the lower part of the motor dictates a DL
capability
Ideally used in 100% slide or 100% rotation
Rotary tendency is controlled by the stabilization
Rotary Steerables Uses the horsepower from the rig directly down through the
drillstring
Deviation is controlled by push or point the bit technology Amount of steering is controlled by the stabilization
Drilling ahead after the Kick-
Off
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Stabilization
Stabilized BHA can be designed to build, hold or drop
inclination Critical elements:
Stabilizer gauge
Stabilizer position
Drill collar OD/weight/moment of inertiaHole inclination
WOB, RPM, flow rates
Hole gauge
Bit Type
Prediction issues (formation effects, bit walk, hole washout)
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BHA's for building Inclination
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UG
BHA's for maintaining
Inclination
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Rarely used
BHA's for Dropping Inclination
a e s eera e
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a e s - eera eMotors
Bend closer to the bit reduces
bit offset for equivalentcurvature. < bit offset = < component stress
Rotation possible without concern
for component failure.
After kick-off, drill tangents,adjust trajectory without POOH.
Bit walk and build/drop
tendencies not always
predictable with rotary BHAs. Efficiency achieved with motor
bits, multi-lobe power sections
and wireless MWD.
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PowerPak Motors
80 models from 2 1/8 in. to 11 1/4 in. PowerPak XP & GT extended power sections
PowerPak XF & XC short radius drilling
Oil seal or mud lubricated bearings
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PDM - Basic Components Top Sub crosses over from
Stator to drillstring. (alsodump valve, flex joint..)
Power Section -
Rotor/Stator
Transmission shaft
transforms eccentric
rotation to concentric
rotation. Bearing assembly
Drive Sub
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Directional Drilling with PDMs
Hydraulic power to Mechanical for powering the Bit. Versatility - flexible components, sensors added, variety of
formations & conditions.
Short & Medium radius curves possible
Reduction in: BHA component weight.
String rotation.
Casing wear.
String vibration.
Issues: Hole tortuosity. Bit life, matching bits to motor/formation
Slide drilling
Stator strength (length & BHA response)
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Slide Drilling & Reactive Torque
Reactive torque increases with: WOB
Depth Motor output Torque (delta p.)
Bit aggressiveness
Decreases with: Bit balling
Formation characteristics Motor wear
Bit tooth wear
Tool Face Control issues: Weight transfer problems
Aggressive PDC bit MWD TF updates
Laminar formations
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Controlling Orientation
90.6
265.4
inclination
azimuth
LAST SURVEY
1.5 BH motorconfiguration
UP
RIGHT
DOWN
LEFT
Tool Face Display
++++++++
++
+++ 1.4 R
LAST TOOL FACE
degrees
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Slide - Rotate Sequence
8 ft 24ftTFA=10R
8 TFA=0
6 TFA=20L
18 TFA=5R
10 TFA=45R
28 TFA=140R
31
29
20
31
16
8
begin run
endrun
Slide Sections
Rotary Sections
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Slide - Rotate Well Profile
35
40
45
50
55
2500 2550 2600 2650 2700 2750 2800 2850 2900 2950 3000
MD (ft)
INCL
(deg)
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Managing Dogleg Larger motor bend gives larger dogleg through
slides will minimize steering
saves time
will increase tortuosity of the wellbore
downhole problems - tripping, logging, casing running increased torque - ability to drill to TD
impact bit and motor and bit performance and durability
Tortuosity is the summation of doglegs in thewellbore
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Calculating Dog-Leg
Dog-leg
calculation based
on 3 pt geometry
Formation effects
Hole gauge
effects
DogLeg Prediction ProgramVersion 5.02
Name of the simulation : dadsf
Motor : A675_S_14 Standard Near bit stabilizer
Legends : MODIFIED VALUES and STANDARD VALUES
Motor Lobes and Bit Bit Bit Sub Near Bit S tab Kick Pad Stator
OD Stages Diameter Length length OD Height length
6.75" 7:8 / 3.0 8.5" 12" 0" 7.5" 0.25" 125"
8.5" 12" 8.375" 0.25" 125"
Pony Collar Top Stab Distance to Effective
length OD Top Stab. K. Pad Dia.
0" 6.75" 24" 7.25"
8.375" 24"
Bit to center Bit Bend to Bit to Casing
dow n sta b. to be nd top sta b. top sta b. ID
37.48" 91.16" 184.85" 276.01"
Only for a casing
Bend DLS Radius Pred. Point Min. Pass- Speed Force on Force on
Angle (/100') Curv. (ft) of Contact Thru Dia. M ax . RP M b it (l bs) t op st ab . (lbs)
0.00 NEG NEG kickpad 8.50 200 0.00 0.00
0.39 0.7 8599 kickpad 8.50 200 0.00 0.00
0.78 4.0 1431 kickpad 8.50 120 0.00 0.00
1.15 7.2 792 kickpad 8.81 60 0.00 0.00
1.50 10.3 557 kickpad 9.18 60 0.00 0.00
1.83 13.1 437 kickpad 9.53 0 0.00 0.00
2.12 15.7 365 kickpad 9.84 0 0.00 0.00
2.38 17.9 320 kickpad 10.12 0 0.00 0.00
2.60 19.8 289 kickpad 10.35 0 0.00 0.00
2.77 21.3 269 kickpad 10.54 0 0.00 0.00
2.90 22.4 255 kickpad 10.67 0 0.00 0.00
2.97 23.1 248 kickpad 10.75 0 0.00 0.00
3.00 23.3 246 kickpad 10.78 0 0.00 0.00
START
http://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xlshttp://localhost/var/www/apps/conversion/DD%20Engineering/dogleg5_02.xls -
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Projecting Trajectory
Projecting ahead to the bit is essential
for calculating wellbore position within
reservoir
How much slide?
How much rotate?
What are the dog legs?calculate
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Inclination at Bit
Major influence on TVD control
Powerdrive X5
Xceed
Parameters Affecting Lost
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Parameters Affecting Lost
Footage in Recovering from
an Exit
Landing a Medium Radius
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Landing a Medium Radius
Horizontal Well
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TVD Control in a Horizontal Well
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Open Hole Sidetracking
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-4800 -3200 -1600 0 1600 3200
0
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9600
-4800 -3200 -1600 0 1600 3200
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>
PetrozuataZuata Field No 18 1
Plan View
No 18 1A No 18 1C
No 18 1BWorld RecordBit Run
9 5/8" casing
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End of Module
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