Slimhole Coiled Tubing Drilling

8/17/2019 Slimhole Coiled Tubing Drilling

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Slim-Hole and Coiled-TubingTechnology

Dr. William J. McDonaldThomas E. Williams

PTTC Technology Seminar

Lafayette, LA December 5, 2000


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Drilling Engineering Association(DEA)

Sponsors Joint-Industry R&D Projects

28 Members (Operating Companies)

22 Associates (Service Co’s and Consultants)

Currently 113 projects

Typical project: 10-15 participants

Most successful DEA projects:

DEA-44 Horizontal Well Technology

DEA-67 Slim-Hole and Coiled-Tubing


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DEA-67Slim-Hole and Coiled Tubing Technology

Sponsors: Texaco & BP

Start Date: January 1, 1992

End Date: December 31, 2000

Participants: 65

Tasks: 22

Budget: $3 Million


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DEA-67 Tasks

1. Update Software2. New Software

3. User’s Group

4. New Technology

5. Drill-String Design

6. Motors and Bits

7. MWD and Geosteering

8. Well Control

9. UB Drilling/Completion

10. Logging Tools

11. Perforating Systems

12. Completion Techniques13. Stimulation Techniques

14. Production/Workovers

15. Through-Tubing

16. Field Tests

17. Case Histories

18. Well-Planning Manual

19. Composite Tubulars

20. Multibranch CT

21. Schools

22. Forums


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DEA-67 Deliverables

Major reports 6

Computer programs 9

Forums 6

Schools 8


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Advances inSlim-Hole Technology


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Summary

Slimholes:

-Reduce Well Costs 40 to 70%

-Reduce Environmental Costs & Concerns-Tools and Equipment Exist, and are

Available and Reliable

-Safe

-Do Not Usually Limit Production


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Overview

Historical Background

Types of Slim-Holes

Slim-hole Cost Savings

Evolution and Experience

Concerns and Conclusions

Outlook


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Publications on Slim Hole

0

10

20

30

40

50

60

3 9 4 2 4 5 4 8 5 1 5 4 5 7 6 0 6 3 6 6 6 9 7 2 7 5 7 8 8 1 8 4 8 7 9 0 9 3 9 6

YEAR

N

u m b e r o f P u b l i c a t i o n s


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Stekoll SlimholePumping System (1960)

Flow Line

Rubber Hose

1” Tee

Clamp

Polished Rod Liner

2 7/8” Casing

1” EUE Pumping String

Traveling Barrel Insert Pump

Slip-Type Hold-Downwith Rubber RemovedScreen

Blind Cage

Gas Vent

ConventionalStuffing Box


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Stekoll Field Well (1960)


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STEKOLL Field Experience (1960)

Over 1,300 Wells: Kansas, Texas, Canada

1,000 to 3,000 Foot Wells

1” EUE Tubing (Hollow Sucker Rod)

2-1/2” & 2-7/8” Inch Casing

70 BOPD

40 to 50% Reduction in Tubular Costs

17% Overall Cost Savings


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STEKOLL SlimholeOperations (2- 7/8”)

Drilling & Logging

Perforating & Squeeze Cementing Acidizing & Fracturing

Fishing & Washovers

Sand Bailing

Dual Completions


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Hollow Sucker Rod Advantage

“The hollow sucker rod combines the

function of the sucker rod and the

tubing, so it is no longer necessary to

pull both sucker rods and tubing

when working over wells.”

STEKOLL, 1960


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STEKOLL System Limitations (1960)

Limited Slimhole Logging Tools

Workover Concerns

Tubing Failures

Resistance to Slimholes

Resistance to New Technology


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Slim-Hole Systems

Rotary

Drilling

C o l l a r

Downhole

Motor

M u d M o

t o r

Continuous

Coring

C o r e B a r r e l


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Amoco SHADS Rig( Continuous Coring)

Wireline overshot forcore retrieval

Top drive (0-2250 rpm)

Sandline

Drawworks

Hydraulic drive

4-3/8” core bit (0-10,000 lb WOB)

WellboreSlim annulus

(


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Slim-Hole Motor Dr i l l ing

in WyomingAmoco (1995)


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Microdrill Slim-Hole Rig(Rotary Drilling)


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Slim-Hole Drilling Site(BP, 1994)

Site Reduced by 75%

Slim-Hole Site

Conventional Site

200 ft

390 ft

1 6 0 f t

3 3 0 f t


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Material Cost Savings(3” vs. 8”)

0

10

20

30

40

50

60

70

80

MUD CASING CEMENT

80%

70%

40%

% S a v i n g s


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MICRODRILL COSTS (1500-5000 ft DEPTH)


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Slim -Hole Dri ll ing and Complet ionCost Savings


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SLIM-HOLE RIG COSTS

(McLAUGHLIN, 1959)

HOLE SIZE

D A I L Y C O S T S ( $ )

800

625

525

335

9" 6 3/4" 5 5/8" 3 3/4" 0

200

400

600

800

1,000

4 MEN

4 MEN

3 MEN

5 MEN


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SLIM-HOLE CASING AND TUBING COSTS

(McLAUGHLIN, 1959) 7" CASING

2 7/8" TUBING

5 1/2" CASING 2 3/8" TUBING

4" CASING 1 1/2" TUBING

2 3/8" CASING NO TUBING

R E L

A T I V E C O S T


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40% Saving s Fo r 5000-ft WELLS (BONSALL, 1960)


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SLIM HOLE

( $ )

CONVENTIONAL

( $ )

% OF TOTAL

SAVINGS

ACID

150

600

3

LOGGING 850 850 --

PERFORATING

450

350

-1

FRACTURING

3300

4500

8

LOCATION EXPENSE

2500

2500

--

MUD 1000 1000 --

CORE ANALYSIS

200

200

--

TOTAL:

52,220

100

37,470

Savings For 5000-ft Wells (con t.)

2209314X DEA-67


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Cost Savings with Slim Holes

OPERATOR LOCATION SAVINGS YEAR

Hudson's Bay Canada 28% 1959

Western Mining Australia 75% 1984

Oryx Texas 50% 1991Elf/Microdrill Paris Basin 65% 1992

Maraven Venezuela 20% 1994

Chevron California 66% 1995

Wilcox Operators Texas 15% 1995GUPCO/Amoco Gulf of Suez 20% 1995

Shell Madagascar 40% 1996

ARCO Alaska 26% 1996

Remote Coring Operations


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SLIM-HOLE COSTS (WESTERN MINING, 1984)

4.0

2.0

0

6.0

W E L L C O S T (

$ M M )

LOGISTICS

REMOTE LOCAL

SLIM HOLE

CONVENTIONAL

2000m TD

DRY HOLE ONSHORE


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Conoco Indonesia Sl im-Hole Cos ts

(MACFADYEN et al., 1986)

1980-81 (CONV)

1985-86 (SH)

NUMBER OF WELLS

5

3

12

AVERAGE WELL COST 7,670,000 4,680,000 2,060,000

DRILLING

TOTAL FOOTAGE 18,962 11,740 29,179

AVERAGE DEPTH 3,792 3,913 2,432

DRILLING COST/WELL

2,770,000

960,000

760,000

LOGISTICS

NO. OF LIFTS 317 187 100

NO. OF DAYS 16 9 5

HELICOPTER

PUMA

PUMA

S-58T

1983 (SH)


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ORYX

HORIZONTAL SL IM-HOLE COSTS

(HALL AND RAMOS, 1992)


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DAYS DEPARTURE LATERAL COST TOTAL COST

18 1458 3.88 (CT) 0.63

38 2018 3.31 0.74

24

2002

1.84

0.41

21 2692 1.46 0.43

20 2242 1.83 0.45

18 1927 2.36 0.50

14 1600 1.75 0.31

22 1900 2.60 0.54

1991-92 ORYX SL IM-HOLE RE-ENTRIES

(HALL AND RAMOS, 1992)

0.50

1980

2.38

AVG 22

1991 CONVENTIONAL COST = 1.00


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ORYX'S CONCLUSION (1992)


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Domain Energy Slimholes (1995)

Cased Hole

5-1/2” Casing

4-3/4” Hole

2-7/8” Production Casing

7-7/8” Hole

TD 10926’

1518’

TD 10909’

Open Hole

7-5/8” Casing

4-3/4” Hole

2-7/8” Production Casing

9-7/8” Hole

1520’

10697’

InflatableCasing Packer

Cement


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Domain Energy Slim-Hole (1995)

Location:

Rig Modification:

Hole Diameter:

Casing Diameter:

Drill Pipe Diameter:Collar Diameter:

Motor Diameter:

Drilling Rate:

Problems:Successes:

Cost Savings:

Green River Basin, WYBowen S3.5 Power Swivel

4-3/4 inches

2-7/8 inches

2-7/8 inches3-1/2 inches - 3 stabilizers

3-3/8 and 3-3/4 inches

Up to 2x increase

4 Twist-offs (stabilizer torque)Cementing/Logging/Perforating

Breakeven (due to twist-offs)


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Domain Energy Slim-Hole Problems (1995)

Slim-Hole No. 1 Plugged bit nozzles - 1,006 ft

Motor twist-off (stabilizer torque) - 7,071 ft

Fishing - 3 trips

Slim-Hole No. 2 Hole deviation (no stabilizers)

Low ROP (reduced WOB due to hole deviation) Stuck pipe - 8,085 ft (stabilizer torque)

Fishing - back-off, spear, 4 trips (7 days)

Logging - problem running tool

Slim-Hole No. 3

Motor twist-off (stabilizer torque) - 1,004 ft Fishing - 3 trips (23 hours)

Motor twist-off (stabilizer torque) - 5,187 ft

Fishing - 1 trip (grapple)

Lost cone - 10,871 ft (drilled with rock bit)


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Unocal Thailand Slim-holes (1999)

Conventional

2-7/8” TBG

Slimhole Ultra Slim

13-3/8” @ 1000’

9-5/8” @ 4500’

7” @ 10000’

SSSV SSSV SSSV

9-5/8” @ 850’

7” @ 2500’

2-7/8” TBG @ 4500’

6-1/8” Hole

7-5/8” @ 850’

5-1/2” @ 2500’

2-7/8” TBG @ 4500’

4-3/4” Hole


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Unocal Thailand Slimholes (1999)

0.75

1.3

0

0.2

0.4

0.6

0.8

1

1.2

1.4

W e l l

C o s t ( $ m i l l i o

n s )

Slimhole Conventional

(4-3/4”) (8-1/2”)


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Unocal Gas Production Rates (1999)

0.00 500 1000 1500 2000 2500

C u m u l a t i v e G a s P r o d u c t i o

n ( M M S C F )

Time (days)

Slimhole Wells

Conventional Wells


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Unocal, 1997

“Slimhole development has completely

Transformed the future of Gulf of Thailand

Operations and has paved the way for

Operators to continue providing a long-

term economic supply of gas to the

Kingdom of Thailand”


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Pemex Slimholes (1998)

Conventional

13-3/8” Casing

12-1/4” Drill Bit

7” Casing

Packer

9-5/8” Casing

17-1/2 Drill Bit

2-7/8” Tubing

8-1/2” Drill Bit

3000 m

1650 m

150 m

Slimhole

9-5/8” Casing

8-1/2” Drill Bit

Cement

7” Casing

12-1/4 Drill Bit

3-1/2” Tubing

5-7/8” Drill Bit

3000 m

1650 m

150 m


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Texaco Dual Completion Slimhole

13-3/8” Casing

12-1/4” Hole

2-7/8” Tubing

9-5/8” Casing

17-1/2 Hole

2-7/8” Tubing

8-1/2” Hole

10,500’

8,000’

2,500’

Cement

12,500’


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Slim-hole Well Concerns

Casing Program

Drillstring Torsional Strength

Fishing & Milling

Increased ECD (lost circulation)Bit Design and Reliability

Downhole Motors(cost & reliability)

Cementing (primary & squeeze)Stimulation

Workovers


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Conclusions

Slimholes:

-Reduce Well Costs 40 to 70%

-Reduce Environmental Costs & Concerns

-Tools and Equipment Exist, and are

Available and Reliable

-Safe

-Do Not Usually Limit Production

Hi h P Sli M t


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High-Power Slim Motors

Bearing

PackUniversal Jt

Long Power Section

StandardPower

Sections


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Leniek Pumping System (1999)

Production Line

1-1/2” Hydraulic

Hose

Clamp

Hollow Polish Rod

3-1/2” Cemented Tubing

2” Coiled Tubing

Hollow Rod Pump

AnchorScreen

Gas Vent

Stuffing Box


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Leniek CT Pumping System

Conventional Surface Equipment1,000 to 5,000 Feet

2-7/8” or 3-1/2” Casing (CT or

Tubing)1-1/2” CT (Hollow Sucker Rod)

Hollow Polish Rod

Hollow Rod Pump

YPF Installation


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YPF Installation

Leniek System Advantages


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Leniek System Advantages

Reduce Well Construction Cost 50

PercentEliminates Tubing Thread Failures

Eliminates Tubing Anchors

Reduce Lifting CostsReduce Paraffin Problems

Reduce Casing Wear

Treat Wells Through CTEliminate Rod Failures

Allows Ultraslim Holes


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Advances inCoiled-Tubing Technology


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Overview

History & Evolution

Current Status

Conventional Operations

Coiled Tubing Drilling (CTD)

Outlook


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Evolution


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Evolution

1944 Allied Invasion Europe1962 Bowen CTU

1975 - 200 Units - 1-1/4”

1980 - Improved Pipe/Welding

1983 - Continuously Milled 3000’

1987 - Bias-Welded Strips1992 - 2-3/8” to 3-1/2” OD CT

1999 - 110 ksi CT

Today


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Today

750 Units Worldwide

50% in North America

Few Pipe Failures

Multiple Applications

CT Pipelines


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Common Applications

Clean outs (50%)

Stimulations

Profile Modifications

Perf/Log

Artificial Lift

Sand Control

Coiled-Tubing Applications


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Coiled-Tubing Applications

Clean-outDownhole Tools

Stimulation

Nitrogen Lift

Drilling

Logging/Perf

Jetting

Fishing

Cementing

Source: Quality Tubing


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Cost Savings with Coiled Tubing

OPERATOR JOB SAVINGS YEAR

ARCO Alaska Cement Squeeze 90% 1987

Fracmaster Pipeline Cleanout 90% 1988

BP (North Sea) Barium Scale 80% 1990Chevron Velocity String 59% 1992

Amoco (GOM) Zinc Sulphide 94% 1993

BP Alaska Spoolable GL 68% 1993

Mobil Fracturing 21% 1994Amoco TT Gravel Pack 80% 1996

Workovers

Completions


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Hybrid Coiled Tubing/


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Hybrid Coiled-Tubing/Snubbing Rig

(Hydrarig)

CT Injector

Injector Trolley

Jack Cylinder

Quad BOP

Substructure

Support Pole

Oman Large-OD CT Completions


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Oman Large OD CT Completions

ESP Well

SlipConnection

ESP cable

3-1/2” CT

Slip connector

Landing nipple

Protector

Motor

Centralizer

7” K55, LTC

Pump

2-7/8” CT

4-1/2”

Tie back

Slim ConcentricWater Injector

4-1/2” Tie back

2-7/8” EU nipple

5-1/2” x 2-7/8” production

packer

Gas Lift Well

7” shoe

3-1/2” nipple

7” packer

Slidingsleevecirculatingdevice

13-3/8”

casing

Gas liftmandrels

Velocity String

2-7/8” EU nipple

Productionpacker

Hyd. setretrievable

packer

Bottom holepress. gauge

Gas liftmandrel

Top CT plug

1-1/2” CT

3-1/2” tubing

Taylor and Conrad (1996)

ARCO Coiled-Tubing Liner


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ARCO Coiled Tubing Liner

Production tubing

Hydraulic set packer

Open-hole well(possibly drilled with

coiled tubing)

CT liner Pre-perforatedCT liner with

optional screen

Pay Zone

CT Steam-Injection System


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j y

Coiled Tubing

SteamGenerator

Injector

BOP

Wellhead

8

0 0 0 ’

CasingProduction

Tubing

Concentric CT

SlottedLiner Concentric CT

Cross Section

Pearlite

Oil Reservoir

OilOil

Steam

Steam

2-7/8” CT

1-3/4” CT

Coiled Tubing Drilling


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Coiled Tubing Drilling(CTD)

History of CDT

Current Status

Demographics of Current Activity

Advantages and Limitations

Where are we headed with CTD?

Coiled-Tubing Drilling System


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Coiled-Tubing Drilling System

Injector ReelPower Supply

Whipstock orCement Plug

2” CT with Wireline

Connector

Orienter

MudMotor

Bent Sub Bit

GuidanceSystem

Why CTD or Why Not ?


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Continuous CirculationPressure Control

Footprint, Environmental

LWD, Geosteering, Joystick OperationDeepenings, Side-Tracks

Through-Tubing Capable

Costs?

Availability

Acceptance

Brief CTD History


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Brief CTD History

1991 - Elf/Dowell & ORYX/Cudd1992 - Arco first window & MWD

1994 - First North Sea CTD wells

1994 - Maersk 3000’ Horizontal well

1995 - 200+ CTD Wells Worldwide

1999 - 1200± CTD Wells

Schlumberger Electrically-Controlled


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Schlumberger Electrically-ControlledCT Drilling System

2" CTDrilling

Head

Logging/Steering

Sub

ElectricOrienter Motor

7-Conductor

Wireline

Bit

Schlumberger “Viper” BHA

Transocean Hydraulically-Controlled


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Transocean Hydraulically ControlledCT Drilling System

1/4" SS Hydraulic Tubing

Connector

Logging/Steering SubHydraulicOrienter Motor

Monoconductor Wireline

Bit

2" CT

Check Valves/

Release Sub

Transocean Dual-Capillary BHA


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Arco CTD History


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y

1990-Initial interest for PRB ST1991-Initial ST effort unsuccessful

1992-94 Oklahoma Window Milling Tests

1992-Successful ST in West Texas

1993-Prudhoe program started

1994-95 THUMS Efforts,1997++ Algeria, Indonesia, CA, NM...

ARCO S (1999)


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ARCO Summary (1999)

120

11

1 1 3 10

20

40

60

80

100

120

Alaska California New Mexico Texas Indonesia Algeria


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Running 3 1/2” CTC after CTD


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g /


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Typical CTD Completion at PRB


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Surface Testing

17 PPG Fiber F/O PlugPilot HoleCasing Exit

“One Step” Mill


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1999-2000 CTD Developments


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Thru - 3-1/2” Tubing Operations Over 30 Slimhole Operations To-date

Fluid Loss/ECD Concerns

Lower DensityLower Polymer loading

Shale Stabilization Additives

Bi-center Bits

PRB CTD Average Footage


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817

1204

17941685

1950

0

200

400

600

800

1000

1200

1400

1600

1800

2000

A v e r a g e F o o t a g e

1995 1996 1997 1998 1999

Prudhoe Bay Summary


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100 wells 1993-99

Average Cost

1995 - $990M1996 - $1005M1997 - $1165M1998 - $1200M1999 - $1375M

•Harder, Longer Reach Targets• Avg. Production 1400 BOPD

•90% success

Grissom IslandTHUMS - Arco Project


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THUMS - Arco Project


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California CTD Project


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j

4/97- Drilled 7 shallow vertical wells

Fleet Cementers CTU - unique design

Used 2 7/8” OD CT, 4 3/4” PDMs

Hole size 6 to 6 1/2” holes, 1 to 9 1/2”

Depths 900-1000’ , Ran 3 1/2” casing

Total time 24 hours/well


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Indonesia


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Multiple well program in NW Java SeaOne ST/ window through 9-5/8” csg- 1997

870’ of 6-1/8” hole drilled w/ 2-3/8” CT

Used tinder barge rig as supportCompleted with cemented 3-1/2” liner

2nd well discontinued after 500’ - shale

3rd well April - June 1998- lost hole - shale


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Offshore Indonesia


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Current Status of CTD


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20 CTU’s capable of serious CTD

Less than 10 CTU’s actively drilling

AK, Oman, Canada, N. Sea, Venezuela

Currently active; Schl, Baker, BJFleet

MWD, electric/hydraulic BHA’s



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Continuous CirculationPressure Control

Footprint, Environmental

LWD, Geosteering, Joystick OperationDeepenings, Side-Tracks

Through-Tubing Capable

Costs? Availability

Acceptance

What is the Future ?


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Underbalanced operations All-electric CTD BHA

Composite CT

Pre-programmed, self guided BHA

Smaller BHAs

Through-tubing rotary drilling

Fiberspar Composite Coiled Tubing


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e spa Co pos e Co ed u g


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FS CT Field Validation Trails


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FS CT Field Validation Trails

HalliburtonEnergy Services

To date, 6 - CO2

injection wellclean-outs withacid stimulationfor Altura in W.TX and Phillips

in NM

FS LP First Commercial Application


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FS LP First Commercial Application

Altura, Levelland,TX

40,000’ waterflood installation

2” ID, 1500-psiWP FibersparLinePipe used

Pipe shipped in8,000 ftcontinuouslengths

Mobile Spooling Unit


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Mobile Spooling Unit

Few Fittings


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Few Fittings

Long runs wereeasilyaccomplished withfew or no fittings

to account forturns

Several long runswith multiple turns

were successfullycompleted in asingle pull


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Documents

Slimhole Coiled Tubing Drilling