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7/29/2019 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

1600

3200

4800

6400

8000

9600

-4800 -3200 -1600 0 1600 3200

0

1600

3200

4800

6400

8000

9600

>

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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