Coiled Tubing

Coiled Tubing Drilling

MK0122

Coiled Tubing Directional Drilling Capabilities • GOAL:

Achieve results similar to conventional drilling for:

– Drilling Lateral Sections – Drilling Build Sections – Changing Direction

Basic Coiled Tubing Drilling BHA CT Connector, Check Valves, Hydraulic Disconnect, Circulating Sub, Non-rotating Joint, Float Sub Directional/Gamma MWD

Coiled Tubing Orienter

Mud Motor

Equalizing Sub

Directional /Gamma Coiled Tubing MWD 306 -in (25 -ft 6 -in) 37.5 -in

8 -in 2.875-in OD

3.25 -in OD

FLOW

PULSER

TURBINE

GAMMA PROBE

DIRECTIONAL PROBE

CENTRALIZERS 5 -ft TO DIRECTIONAL SENSORS

14.5 -ft TO GAMMA SENSORS

Measurement While Drilling • Started with existing 3-1/2" Directional/Gamma • Sonde design allowed OD reductions • Shortened collars • Software modified for CT operation • Incorporating Short Radius technology

CTD MWD Specifications CT MWD OD (in.) 3.25 / 2.875 Length (ft.) 25.5 Dir. Measure Pt. from end of MWD 5 Gamma Measure Pt. from end of MWD 14.5 Top Box Connection 2-7/8 Stub Acme Mod Bottom Connection 2-3/8 CS Hydril Box Flow Rate Range (gpm) 80-160 Pressure Drop (psi) 120 Max. Temperature (deg. C / deg. F) 140 / 284 Max. Working Pressure (psi) 15,000 Max. Dogleg Severity (0 / 100 ft.) 35 Power / Telemetry Turbine / Positive Toolface Update Time Max./Avg. (sec) 9 / 23 Real-time Gamma Update Max./Avg. (sec) 14 / 35 Recorded Gamma Update Max./Min. (sec) 10 / 95 Full Survey Time (sec) 190 Short Survey Time (sec) 118 Running Short Survey Update Time (min) 5.4

Standard MWD 3.5 flex 36 13 22.5 2-3/8 IF (NC26) 2-3/8 IF Pin 80-200 120 140 / 284 15,000 30 Turbine / Positive 9 / 23 14 / 35 10 / 95 190 118 5.4

New Tools • Coiled Tubing Orienter – Required to orient bend – MWD must rotate in unison with bend – Operates on pressure drop • Equalizer Sub

Coiled Tubing Orienter Design • Driven by Pressure Drop below tool – No need for wireline (better hydraulics) – No need to cycle CT (less fatigue) • Indexes 20° every pump cycle • Piston + Helical Cam design with ratchet

Coiled Tubing Orienter

Internal Pressure

Annulus Pressure

Drive Piston

Pumps Off, Reset

Helical Return Cam Ratchet Spring Oil

Pumps On, Indexing

Port to Annulus

Balance Piston

Output Shaft

CTD Equalizer Sub

Orienter Specifications 3" OD Orienter

3-5/8" OD Orienter

7.5 ft

9.5 ft

Rotation/Cycle

20°

20°

Max Torque @ 600 psi ∆P

250 ft-lbs

400 ft-lbs

Max Torque @ 1000 psi ∆P

500 ft-lbs

800 ft-lbs

Max ∆P

1500 psi

1500 psi

Length

Directional Learning Curve • Drilling the Lateral – Must orient left/right - no rotation – “Meandering” increases drag – 1966 ft. lateral drilled – Only limited reach in 2 wells – Geologic factors

Well No. 9 Survey Plot Vertical Projection TVD (ft)

8600

8809.7 TVD at TD

11,628 -ft TD

8900 4000

4300

4600

4900

Vertical Section (ft) at N 2 deg 11 min W

5200

5500

Well No. 9 Survey Plot Horizontal Projection Latitude (ft) 4000

4600

4900

5200

5500

400

11,628 -ft TD

100

East

Departure (ft)

4300

North

700

Directional Learning Curve • Drilling the Build Section – 38°/100' build rate achieved w/1650' lateral – Goal: Intermediate/Short Radius (45° - 55°/100') – MWD: Flexible connectors, shorter probes • Orienting against the curve - 25°/100'

Thru-Tubing Sidetrack Cement Plug Kickoff 4-1/2" Tubing XN Nipple, milled to 3.8" ID 4-1/2" Tubing Tail @ 10,056 ft. KOP 10,140 ft. @ 33.5º INC 3-3/4" Open Hole 2-7/8" Liner

Laterals 1000 – 1966 ft.

7" / 9-5/8" Casing

Coiled Tubing Drilling Experience 40

B

Build Rate (º/100 ft.)

1650 30 515

B

675

579

198

B

20

B B

B

315

1966

B

1204

828

B

B

950

B B 983

1000

B

10

244 0 0

B

495 800 488 571 725 921

B B BB B

500

1000

1500

Horizontal Displacement (ft.)

2000

Lessons From Alaska IADC/SPE 35128 Excerpts • High Low-shear-rate viscosity improves cuttings transport – Solids kept below 1% – Backream: across doglegs and on short trips (every 50-100 ft.) – Drill rates in soft sands limited to 75 ft. / hr. to prevent buildup • Less aggressive PDC bits, non-mag motors • Depth control: use Gamma Ray to tie-in log to monitor • Economics: 40% savings in 1995 – Driving force: Thru-tubing applications with accessible targets

CTD Wells Through 1996 30

30

25

WELLS

20

15

10 5

5 3

1

1

1

O/S Holland

Mexico

UAE

0 Alaska

Long Beach

Other U.S.

CTD Statistics • 41 wells to date (12/96) • Over 36,000 ft. drilled / Over 25,000 ft. horizontal • Over 300 bit/mill runs • 1966 ft. – Longest horizontal section • 25 windows, 24 MR curves, 32 horizontals • 2 liner orientations – Longest 2100 ft. • 1 oriented acid job

Conclusions • Directional drilling capabilities have improved • New technology has been instrumental • Lateral Sections of 1966 ft. can be drilled • Build Sections of 38°/100 ft. can be drilled • Turns in 25°/100 ft. curve can be done • Global experience is expanding