drillableservicetools - oilfield · pdf file3-4 drillableservicetools drillable service tools...

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Drillable Service ToolsThis section contains information about tool applications,

sizes available, running, setting, and operating drillable tools

and related accessories. Drillable Service Tools have many

functions including wellbore isolation, stimulation isolation,

remedial cementing, and plug and abandonment.

Halliburton is dedicated to providing top-quality equipment

and service. Halliburton maintains strict standards and well

documented processes and procedures to help ensure

excellence and dependability in our Drillable Service Tools

equipment. No matter what your downhole situation, you

can count on your Halliburton representative to help develop

a low-cost solution to address your situation.

Drillable Service Tools 3-1

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EZ Drill® Squeeze Packer

The EZ Drill® squeeze packers are poppet-valve cement

retainers for remedial cementing operations. Unlike some

squeeze packers, workstring manipulation does not open or

close the poppet valve. The poppet valve allows operators to

place cement below the packer and check backflow.

The EZ Drill squeeze packers are ideal for recementing and

high-volume squeeze cementing operations.

Features and Benefits

• Can be set mechanically or hydraulically on jointed pipe

or coiled tubing, electric wireline, or slickline using the

Halliburton DPU® downhole power unit

• Tool OD held to a minimum, allowing more clearance

between the tool and casing for faster run-in

• Effective setting and sealing in elevated temperatures

and pressures

• Squeeze pressure maintained on perforations in the zone

by a backpressure valve that holds pressure from below

and offers little resistance to fluid movement from above

Operation

When the packer is run to setting depth, the steel hose and

swivel are hooked to the top of the drillpipe, and circulation

begins. During circulation through the pipe or tubing, the

packer is worked up and down, which clears debris from the

packer and packer seat.

After circulation is stopped, the workstring is rotated the

specified number of clockwise turns. This rotation moves the

setting sleeve downward so that it unlatches the lock ring and

sets the top packer slips.

A series of applied pulls and hesitations are then used until

the tension sleeve parts. These pulls and hesitations allow the

packer rubbers to properly expand and contact the casing ID.

Pressuring up to 2,000 psi (13.79 MPa) below the packer

as it sets helps set the top packer slips. The pressure is

released before the tension sleeve parts so that the packer’s

internal seal is not damaged. After the tension sleeve

parts, the maximum permissible tubing weight is applied

on the packer, which helps set the slips and packer element

more tightly.

The setting tool is then pulled above the packer, and the

workstring is rotated so that the setting tool is placed in the

operating position. The poppet valve is opened by fluid

moving through the valve.

HA

L1

20

60

EZ Drill®Squeeze Packer

3-2 Drillable Service Tools

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EZ Drill® Squeeze Packers

Part NumberTool Size

in.

Casing Sizein.

Casing Weight

lb/ft

MaximumCasing IDin. (cm)

MinimumCasing IDin. (cm)

PackerMaximum OD

in. (cm)

PackerLengthin. (cm)

100004373802.303

2 7/8

2 1/2 line pipe2.44

(6.20)2.32

(5.89)2.18

(5.54)28.18

(71.58)2 7/8 6.40 - 7.903 1/2 16.70 - 17.05

100073040802.305

3 1/2

3 line pipe

3.24(8.23)

2.89(7.34)

2.69(6.83)

33.34(84.68)

3 1/2 9.20 - 10.034 16.50 - 19.00

4 1/2 26.50

100013754802.307

4

3 1/2 line pipe3.64

(9.25)3.32

(8.43)3.12

(7.92)33.34

(84.68)4 9.40 - 13.404 1/2 18.80 - 24.60

100009925802.3084 1/2 HW

4 1/2 13.50-15.10 3.92(9.96)

3.83(9.73)

3.58(9.09)

22.78(57.86)5 26.70

100010196802.309

4 1/2

4 line pipe

4.18(10.62)

3.92(9.96)

3.66(9.30)

22.78(57.86)

4 1/2 9.50 - 13.504 3/4 16.00

5 20.30 - 24.205 1/2 36.40

100013755802.311

5

5 11.50 - 18.004.56

(11.58)4.27

(10.85)3.97

(10.08)24.05

(61.09)5 1/2 26.00 - 32.306 5/8 70.00

100004375802.313

5 1/2

5 line pipe

5.04(12.80)

4.67(11.86)

4.37(11.10)

24.20(61.47)

5 1/2 13.00 - 23.005 3/4 22.50 - 25.20

7 64.10

100009407802.319

7

6 line pipe

6.46(16.41)

5.90(14.99)

5.50(13.97)

29.84(75.79)

6 5/8 17.00 - 24.007 20.00 - 38.00

7 5/8 45.30 - 55.307 3/4 53.52

These ratings are guidelines only. For more information, contact your local Halliburton representative.

EZ Drill® Squeeze Packer Operation

Nominal Casing Size

in.

Maximum Recommended Temperature

°F (°C)

Maximum Recommended Pressure Differential

psi (MPa)Maximum Recommended

Weight on Packer withLoad Transfer Device

lb (kg)*Externally Applied (Across Packer Rubbers)

Internally Applied (Packer Mandrel Burst)

3 1/24

425(218)

10,000 (68.95)

10,000 (68.95)

30,000(13 608)

4 1/25

5 1/26

425 (218)

10,000 (68.95)

10,000 (68.95)

80,000 (36 287)

6 5/87

425 (218)

10,000 (68.95)

10,000 (68.95)

100,000 (45 359)

Note: The maximum temperature and pressure capabilities are based on laboratory test results. Because of variations in well conditions, these values should not be considered as absolute when the tool is used in actual service.*Weight on the packer must never exceed these values. Weight on packer includes applied string weight and any hydraulic forces applied to the workstring. Impact loads can greatly reduce these weight ratings.These ratings are guidelines only. For more information, contact your local Halliburton representative.


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EZ Drill® Bridge Plug

EZ Drill® bridge plugs are built from cast iron, brass, and

rubber to provide unsurpassed drillability in general

oilfield service operations. Operators can use one of the

following types of equipment to set EZ Drill bridge plugs:

• Electric wireline setting tools

• Slickline setting tools

• Coiled tubing setting tools

• Mechanical setting tools


• Downhole pressure control and drillability

• Drill up with conventional tricone drill bits or

junk-style mills

• Drilling technique and bit choice will affect

drilling efficiency

• Top drilling

HA

L9

25

4

EZ Drill®Bridge Plug


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EZ Drill® Bridge Plugs


in.

Casing Sizein.

Casing Weight

lb/ft



PackerMaximum OD

in. (cm)


100004414803.639

4 1/2

4 line pipe

4.18 (10.62)

3.92(9.96)

3.66 (9.30)

25.13 (63.83)

4 1/2 9.50 - 13.504 3/4 16.00

5 20.30 - 24.205 1/2 36.40

100004416803.643

5 1/2

5 line pipe

5.04 (12.80)

4.67 (11.86)

4.37 (11.10)

25.37 (64.44)

5 1/2 13.00 - 23.005 3/4 22.50 - 25.20

7 64.10

100004417803.649

7

6 line pipe

6.46 (16.41)

5.90 (14.99)

5.50 (13.97)

31.57 (80.19)

6 5/8 17.00 - 24.007 20.00 - 38.00

7 5/8 45.30 - 55.307 3/4 53.52

Note: For sizes other than those listed above, please see EZ Drill® SV and SVB with optional bridging plug.These ratings are guidelines only. For more information, contact your local Halliburton representative.

EZ Drill® Bridge Plug Operation

NominalCasing Size

in.

Maximum RecommendedTemperature

°F (°C)

Maximum RecommendedPressure Differential

psi (MPa)

Applied Above Applied Below

4 1/2 425 (218)

10,000 (68.95)

7,000 (48.26)

5 1/2 425 (218)

10,000 (68.95)

7,000 (48.26)

7 425 (218)

10,000 (68.95)

8,000 (55.16)

Note: The maximum temperature and pressure capabilities are based on laboratory test results. Because of variations in well conditions, these values should not be considered as absolute when the tool is used in actual service.These ratings are guidelines only. For more information, contact your local Halliburton representative.


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EZ Drill® Frac Plug

EZ Drill® frac plugs are designed to provide wellbore zonal

isolation between multi-zone stimulation treatments. It is a

“caged ball” type frac plug and only provides isolation from

above the plug. The ball check valve in the top is captured

and allows pressure and flow from below to assist in wellbore

cleanup after stimulation. The EZ Drill frac plug is built from

cast iron, brass, and rubber to provide unsurpassed

performance in general oilfield service operations.

Operators can use one of the following types of equipment to

set the EZ Drill frac plugs:






• Design based on Halliburton's EZ Drill bridge plug for

proven performance

• Extended downhole service life over conventional

composite frac plugs

• Downhole pressure control and drillability

• Drill up with conventional tricone drill bits or

junk-style mills

• Drilling technique and bit choice will affect

drilling efficiency

• Top drilling

EZ Drill®Frac Plug

HA

L2

50

44


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EZ Drill® Frac Plugs


in.

CasingSizein.

CasingWeight

lb/ft



PackerMaximum OD

in. (cm)


1014962694 1/2 HW

4 1/2 15.1 - 15.5 3.91(9.93)

3.83(9.73)

3.58(9.09)

25.12(63.80)5 26.70

1014887544 1/2

4 Line pipe

4.18(10.62)

3.91(9.93)

3.66(9.30)

25.12(63.80)

4 1/2 9.5 - 13.5

4 3/4 16.00

5 20.30 - 24.20

5 1/2 36.40

1015770555 1/2

5 Line pipe

5.04(12.80)

4.67(11.86)

4.37(11.10)

25.37(64.44)

5 1/2 13.00 - 23.00

5 3/4 22.50 - 25.20

7 64.10

1016290967

6 Line pipe

6.46(16.41)

5.90(14.99)

5.50(13.97)

31.57(80.19)

6 5/8 17.00 - 24.00

7 20.00 - 38.00

7 5/8 45.30 - 55.30

7 3/4 53.52

1018496377 5/8

7 17.007.13

(18.11)6.50

(16.51)6.12

(15.54)31.67

(80.44)7 5/8 20.00 - 42.80

7 3/4 45.30 - 46.10


EZ Drill® Frac Plug Operation

NominalCasing Size

in.

MaximumRecommended Temperature

°F (°C)

MaximumRecommended Pressure

psi (MPa)

MaximumRecommended Weight

lb (kg)

4 1/2 - 5 1/2 425(218)

10,000(68.95)

80,000(36.287)

7 - 7 5/8 425(218)

10,000(68.95)

100,000(45.359)

The maximum temperature and pressure capabilities are based on laboratory test results. Because of variations in well conditions, these values should not be considered as absolute when the tool is used in actual service.These ratings are guidelines only. For more information, contact your local Halliburton representative.


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EZ Drill® SV Squeeze Packer

The EZ Drill® SV (sliding valve) squeeze packer provides

effective setting and sealing even under high pressures and

temperatures. Although primarily used for squeeze

cementing, the EZ Drill SV squeeze packer can also be used

as a bridge plug or as a means of pressure testing a

workstring. Regardless of its use, this tool can be run in

quickly and drilled out easily.

The EZ Drill SV squeeze packer can achieve a positive set

and seal, regardless of pressure direction because the packer

elements, slips, and other components are specially designed

to set and seal at high pressures, yet offer little resistance

to drillout.

Because of the packers’ small diameters, they can be used in a

wider range of casing sizes and weights. The small-diameter

feature also permits more clearance with casing ID, which

lessens the danger of premature setting.

The EZ Drill SV squeeze packer has a sliding-sleeve valve

that allows the tool to function like a bridge plug until the

squeeze operation. The pressure-balanced, sliding-sleeve

valve maintains squeeze pressure on the perforations

when closed.

Operated by pipe reciprocation, the valve seals the packer

against fluid movement in either direction. Sliding the valve

down to open allows fluid movement through the tool. Side

ports in the tool allow unobstructed fluid flow.

Setting Procedures


set EZ Drill SV squeeze packer:



• DPU® downhole power unit


• Controls flow and pressure differential from

either direction

• Can be used to pressure test the workstring

• Converts to a top-drilling bridge plug

• Sets mechanically or on wireline

• Can be set in wider ranges of casing grades

• Can be run in the hole quickly

EZ Drill® SV Squeeze Packer

HA

L1

20

39


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OperationWhen the packer is run to setting depth, the steel hose and

swivel are hooked to the top of the drillpipe, and circulation

begins. During circulation through the pipe or tubing, the

packer is worked up and down, which clears debris from the


After circulation is stopped, the workstring is rotated the

specified number of clockwise turns. This rotation moves the

setting sleeve downward so that it unlatches the lock ring and

sets the top packer slips.

A series of applied pulls and hesitations are then used until

the tension sleeve parts. These pulls and hesitations allow the

packer rubbers to properly expand and contact the casing ID.

Pressuring up to 2,000 psi (13.79 MPa) below the packer as

it is being set helps set the top packer slips. The pressure is

released before the tension sleeve parts so that the packer’s

internal seal is not damaged. After the tension sleeve parts,

the maximum permissible tubing weight is applied on the

packer, which helps set the slips and packer element

more tightly.

The setting tool is then pulled above the packer, and the

workstring is rotated so that the setting tool is placed in the

operating position. The sliding valve can then be opened,

and fluids can be pumped through the packer.

EZ Drill® SV Squeeze Packers (16 through 20 in.)

Part Number Tool Size

in.

Casing Size in.

Casing Weight

lb/ft



Maximum OD

in. (cm)

Length in. (cm)

Optional Bridging PlugPart Number

100073426802.364

16

16 line pipe 15.25 (38.74)

14.61 (37.11)

13.96 (35.46)

41.66 (105.82)

100004399802.3542616 65.00 - 109.00

100073450802.36500

18 5/8

18 5/8 87.50 - 117.50 18.00 (45.72)

17.44 (44.30)

16.80 (42.67)

41.70 (105.92)

100004399802.3542620 208.00

100072879802.04660

2020 94.00 - 208.00 19.12

(48.56)17.94

(45.57)17.24

(43.79)45.62

(115.87)100004399802.35426


EZ Drill® SV Squeeze Packer Operation

Nominal Casing Size

in.


°F (°C)


psi (MPa)

Maximum RecommendedWeight on Packer

lb (kg)*

Externally Applied (Across Packer Rubbers)


With Load Transfer

Device

Without Load Transfer

Device

1618 5/8

20

200(93)

2,500 (17.24)

6,000 (41.37)

100,000 (45 359)

50,000 (22 680)

Note: The maximum temperature and pressure capabilities are based on laboratory test results. Because of variations in well conditions, these values should not be considered as absolute when the tool is used in actual service.*Weight on the packer must never exceed these values. Weight on packer includes applied string weight and any hydraulic forces applied to the work-string. Impact loads can greatly reduce these weight ratings.These ratings are guidelines only. For more information, contact your local Halliburton representative.


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EZ Drill® SVB Squeeze Packer

The EZ Drill® SVB (sliding valve

brass) squeeze packer has a brass

mandrel that is stronger and more

ductile than cast-iron mandrels. As a

result, the packer can absorb greater

tensile and impact loads as well as

greater internal pressures. The brass

mandrel is easily drilled.

The valve arrangement helps improve

performance in high-temperature and

high-pressure areas, especially when

the valve is cycled repeatedly. The

valve also performs well when cycled

under conditions in which fluid

cannot be held static, especially when

there is pressure or flow from below.


• Controls flow and pressure

differential in either direction

• Allows workstring pressure testing

• Runs in quickly

• Sets in a wide range of casing grades

• Contains rugged brass mandrel,

improved slips, and improved

sliding-valve seals

• Can be set on electric wireline,

slickline, coiled tubing, and

jointed pipe

• Can be set mechanically or

hydraulically

• Converts to a top-drilling

bridge plug

Operation

When the packer is run to setting

depth, the steel hose and swivel are

hooked to the top of the drillpipe

and circulation begins. During

circulation through the pipe or

tubing, the packer is worked up and

down, which clears debris from the


After circulation is stopped, the

workstring is rotated the specified

number of clockwise turns. This

rotation moves the setting sleeve

downward so that it unlatches the

lock ring and sets the top packer slips.

A series of applied pulls and

hesitations allow the packer elements

to expand properly and contact the

casing ID until tension sleeve parts.

Pressuring up to 2,000 psi (13.79 MPa)

below the packer as it is being set is an

option to help set the top packer slips.

The pressure is released before the

tension sleeve parts so that the

packer’s internal seal is not damaged.

After the tension sleeve parts, the

maximum permissible tubing weight

is applied on the packer, which helps

set the slips and packer element

more tightly.

The setting tool is then pulled above

the packer, and the workstring is

rotated so the setting tool is placed in

the operating position. The sliding

valve can then be opened, and fluids

can be pumped through the packer.

HA

L1

20

40

EZ Drill® SVBSqueeze Packer


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EZ Drill® SVB Squeeze PackersPart Number

Tool Sizein.

Casing Sizein.

Casing Weight

lb/ft

MaximumCasing ID in. (cm)

MinimumCasing ID in. (cm)

Maximum OD

in. (cm)

Length in. (cm)

Bridging Plug Part Number

1013409413 1/2

3 line pipe

3.24 (8.23)

2.89 (7.34)

2.69(6.83)

32.96(83.72)

100004409802.5082

3 1/2 9.20 - 10.30

4 16.50 - 19.00

4 1/2 26.50

1013411454

3 1/2 line pipe3.64

(9.25)3.32

(8.43)3.12

(7.82)32.96

(83.72)100004409802.50824 9.40 - 13.40

4 1/2 19.20 - 24.60100004366802.043804 1/2 HW

4 1/2 13.50-15.10 3.92(9.96)

3.83(9.73)

3.58(9.09)

25.13(63.83)

100004374802.309365 26.70

100004367802.04390

4 1/2

4 line pipe

4.18(10.62)

3.92(9.96)

3.66(9.30)

25.13(63.83)

100004374802.30936

4 1/2 9.50 - 13.50

4 3/4 16.00

5 20.30 - 24.20

5 1/2 36.40

100004368802.04410

5

5 11.50 - 18.004.56

(11.58)4.27

(10.85)3.97

(10.08)25.22

(64.06)100004374802.309365 1/2 26.00 - 32.30

6 5/8 70.00

100004369802.04430

5 1/2

5 line pipe

5.04(12.80)

4.67(11.86)

4.37(11.10)

25.37(64.44)

100004374802.30936

5 1/2 13.00 - 23.00

5 3/4 22.50 - 25.20

7 64.10

100004370802.04490

7

6 line pipe

6.46(16.41)

5.90(14.99)

5.50(13.97)

31.57(80.19)

100004379802.31936

6 5/8 17.00 - 24.00

7 20.00 - 38.00

7 5/8 45.30 - 55.30

7 3/4 53.52

100004371802.04510

7 5/8

7 17.007.13

(18.11)6.50

(16.51)6.12

(15.54)31.67

(80.44)100004379802.319367 5/8 20.00 - 42.80

7 3/4 45.30 - 46.10

100072859802.04530

8 5/8

8 line pipe

8.13(20.65)

7.45(18.92)

7.00(17.78)

31.78(80.72)

100004379802.31936

8 5/8 24.00 - 52.00

8 3/4 49.70

9 45.00 - 55.00

9 5/8 71.80 - 91.00

100004372802.04540

9 5/8

9 34.00 - 40.00

9.06(23.01)

8.16(20.73)

7.75(19.69)

36.36(92.35)

100004399802.35426

9 5/8 29.30 - 70.30

9 3/4 59.20

9 7/8 62.80

10 3/4 91.00100072871802.04570

10 3/4

10 line pipe 10.19(25.88)

9.50(24.13)

9.00(22.86)

36.64(93.07)

100004399802.3542610 3/4 32.75 - 65.70

10205320213 3/8

13 40.00 - 50.00

12.72(32.31)

12.28(31.19)

11.68(29.67)

36.36(92.35)

100004399802.35426

13 3/8 48.00 - 76.60

13 1/2 81.40

13 5/8 88.20

14 92.68 - 119.38

Note: Other tool sizes may be available. These ratings are guidelines only. For more information, contact your local Halliburton representative.


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EZ Drill® SVB Squeeze Packer Operation

Nominal Casing Size

in.


°F (°C)

Maximum Recommended Pressure Differential

psi (MPa)


lb (kg)*

Externally Applied(Across Packer Rubbers)


WithLoad Transfer

Device

Without Load Transfer

Device

3 1/24

425(218)

10,000 (68.95)

10,000 (68.95)

30,000(13 608)

10,000(4536)

4 1/25

5 1/26

425 (218)

10,000 (68.95)

10,000 (68.95)

80,000 (36 287)

20,000 (9072)

6 5/87

7 5/8

425 (218)

10,000 (68.95)

10,000 (68.95)

100,000 (45 359)

40,000 (18 144)

7 LW8 5/8

8 5/8 HW

350(177)

10,000 (68.95)

10,000 (68.95)

100,000 (45 359)

40,000 (18 144)

9 5/8 300(149)

7,500 (51.71)

10,000 (68.95)

100,000 (45 359)

50,000 (22 680)

10 3/4 HW10 3/4

11 3/4 HW11 3/4

300 (149)

7,500 (51.71)

10,000 (68.95)

100,000 (45 359)

50,000 (22 680)

13 3/8 HW13 3/8

250 (121)

5,000 (34.47)

10,000 (68.95)

100,000 (45 359)

50,000 (22 680)



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EZ Drill® Premium Squeeze Packer with MCC Buttons

The EZ Drill® premium squeeze

packers with metallic-ceramic-

composite (MCC) buttons are sliding-

valve packers primarily used for

squeeze cementing. These tools are

specifically designed to work in casing

grades of Q125 or higher. The tools are

constructed of frangible materials such

as cast iron, brass, aluminum, and

rubber, making this tool easily drilled.

The valve arrangement helps improve

performance in high-temperature and

high-pressure areas, especially when

the valve is cycled repeatedly. The valve

also performs well when it is cycled

under conditions in which fluid cannot

be held static, especially when there is

pressure or flow from below the tool.

Features and Benefits• Sets in casing grades greater than

Q125

• Controls flow and pressure

differential in either direction

• Allows workstring pressure testing

• Runs in quickly

• Can be set on electric line, slickline,

coiled tubing, and jointed pipe

• Can be set mechanically or

hydraulically

• Converts to a top-drilling

bridge plug

OperationWhen the packer is run to setting depth

using a mechanical setting tool, the

steel hose and swivel are hooked to the

top of the drillpipe and circulation

begins. During circulation through the

pipe or tubing, the packer is worked up

and down, which clears debris from the






downward so that it unlatches the lock

ring and sets the top packer slips.

A series of applied pulls and hesitations

allow the packer elements to expand

properly and contact the casing ID until

the tension sleeve parts.

Pressuring up to 2,000 psi (13.79 MPa)

below the packer as it is beginning to

set is an option to help set the top

packer slips.

The pressure must be released before

the tension sleeve parts so that the

packer's internal seal is not damaged.

After the tension sleeve parts, the

maximum permissible tubing weight is

applied on the packer, which helps set

the slips and packer elements more

tightly. The setting tool is then pulled

above the packer, and the workstring is

rotated so that the setting tool is placed

in the operating position. The sliding

valve can then be opened, and fluids

can be pumped through the packer.

EZ Drill® Premium Squeeze Packer with MCC Buttons

HA

L1

85

40


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EZ Drill® Premium Squeeze Packers with MCC Buttons

Part Number Tool Size

in.

Casing Sizein.

Casing Weight lb/ft

Maximum Casing IDin. (cm)

Minimum Casing IDin. (cm)

MaximumOD

in. (cm)

Length in. (cm)

Bridging PlugPart Number

1015251215

5 11.50 - 18.004.56

(11.58)4.27

(10.85)3.97

(10.08)25.22

(64.06)100004374802.309365 1/2 26.00 - 32.30

6 5/8 70.00

101450419802.04499

7

6 line pipe

6.46(16.41)

5.90(14.99)

5.49(13.94)

31.57(80.19)

100004379802.31936

6 5/8 17.00 - 24.00

7 20.00 - 38.00

7 5/8 45.30 - 55.30

7 3/4 53.52

101407072802.04533

9 5/8

9 34.00 - 40.00

9.06(23.01)

8.16(20.73)

7.75(19.69)

36.36(92.35)

10004399802.35426

9 5/8 29.30 - 70.30

9 3/4 59.20

9 7/8 62.80

10 3/4 91.00

101448389802.0446110 3/4 HW

10 30.25 - 41.50 9.50(24.13)

9.19(23.34)

8.69(22.07)

36.54(92.81)

10004399802.3542610 3/4 71.00 - 86.20

101362309802.04551

11 3/4

11 3/4 42.00 - 79.00 11.08(28.14)

10.42(26.47)

9.87(25.07)

36.64(93.07)

10004399802.3542611 7/8 71.80

101358075802.04588

13 3/8

13 40.00 - 50.00

12.72(32.31)

12.28(31.19)

11.68(29.67)

36.36(92.35)

10004399802.35426

13 3/8 48.00 - 76.60

13 1/2 81.40

13 5/8 88.20

14 92.68 - 119.38

101407126802.365

1616

line pipe 15.25(38.74)

14.61(37.11)

13.96(35.46)

41.66(105.82)

10004399802.3542665.00 - 109.00

Note: Other tool sizes may be available.These ratings are guidelines only. For more information, contact your local Halliburton representative.

EZ Drill® Premium Squeeze Packer with MCC Buttons Operation

NominalCasing Size

in.


°F (°C)


psi (MPa)


lb (kg)*

Externally Applied (Across Packer Rubbers)


WithLoad Transfer Device

WithoutLoad Transfer Device

5 425(218)

7,500(51.71)

10,000(68.95)

80,000(36 287)

20,000(9072)

7 425(218)

10,000(68.95)

10,000(68.95)

100,000(45 359)

40,000(18 144)

9 5/8 300(149)

7,500(51.71)

10,000(68.95)

100,000(45 359)

50,000(22 680)

10 3/4 HW11 3/4

300(149)

7,500(51.71)

10,000(68.95)

100,000(45 359)

50,000(22 680)

13 3/8 250(121)

5,000(34.47)

10,000(68.95)

100,000(45 359)

50,000(22 680)

16 200(93)

2,500(17.24)

6,000(41.37)

100,000(45 359)

50,000(22 680)



Drillable

ServiceT

ools

EZ Drill® SV Openhole Squeeze Packers

EZ Drill® SV (sliding valve) openhole

squeeze packers are sliding-valve

cement retainers for openhole remedial

cementing operations. The packers are

built from cast iron, brass, aluminum,

and rubber to provide unsurpassed

drillability. These packers can be set on

slickline, coiled tubing, or jointed pipe

with either a mechanical or hydraulic

setting tool.

EZ Drill SV openhole squeeze packers

have a stinger-operated sliding valve

that controls pressure from both

directions. Workstring manipulation

opens and closes the sliding valve.

When weight is placed on the set

packer, the sliding valve opens. When

pipe weight is lifted from the packer

and the stinger is removed from the

packer bore, the sliding valve closes.

This feature isolates the cement below

the packer from the pressure and fluid

above the packer.

The most outstanding design features

of EZ Drill SV openhole squeeze

packers are their downhole pressure

control and drillability.

Openhole squeeze packers allow for

remedial cementing operations in

openhole wells and provide downhole

pressure control both above and below

the packer.

EZ Drill SV openhole squeeze packers

drill up with conventional tricone drill

bits or junk-style mills.

Features

• Stinger-operated sliding valve

controls pressure from both

directions

• Isolates cement below packer from

pressure and fluid above packer

• Downhole pressure control and

drillability

• Remedial cementing operations

performed in openhole wells

• Downhole pressure control both

above and below the packer

• Drill up with conventional tricone

drill bits or junk-style millsH

AL

17

82

9

EZ Drill® SV Openhole Squeeze Packer

EZ Drill® SV Openhole Squeeze Packers

Part NumberSizein.

MaximumHole Sizein. (mm)

MinimumHole Sizein. (mm)

Maximum OD

in. (mm)

Lengthin. (mm)

Minimum IDin. (mm)

MaximumRecommended Temperature

°F (°C)


psi (MPa)Maximum

RecommendedWeight on

Packerlbm (kg)*

Externally Applied

(Across Packer Rubbers)

Differential Pressure

Below(Valve Closed)

100013777802.3703

5 1/2

5.04(128.0)

4.67(118.6)

4.37(111.0)

31.62(803.1)

0.87(22.1)

350 (177)

2,000 (13.80)

2,000 (13.80)

30,000 (13 608)

100013778802.3706

7

6.46(164.1)

5.90(149.9)

5.50(139.7)

35.93(912.6)

1.19(30.2)

350 (177)

2,000 (13.80)

2,000 (13.80)

40,000 (18 144)

100073481802.3708

8 5/8

8.13(206.5)

7.45(189.2)

7.00(177.8)

36.14(918.0)

1.19(30.2)

350 (177)

2,000 (13.80)

2,000 (13.80)

40,000(18 144)

Note: The maximum temperature and pressure capabilities are based on a good packer seat that is not porous or vugular. Because of variations in well conditions, these values should not be considered as absolute when the tool is used in actual service.*Weight on packer must never exceed these values. Weight on packer includes applied string weight and any hydraulic forces applied to the workstring. Impact loads can greatly reduce these weight ratings.


Drillable

ServiceT

ools

Casing Alignment Tool

Severe corrosive action, excess tensile loading, or joint

back-off during drilling operations may part casing strings.

Sometimes these parted sections become misaligned, thereby

making well operations very difficult.

In this case, the well operator must either abandon

further work below this point or realign and stabilize the

parted casing.

Casing Alignment

The Halliburton casing alignment tool has been used to

successfully realign and permanently stabilize many parted

casing strings. The casing alignment tool is made up by

connecting threads at the lower end of the EZ Drill®

(poppet valve) squeeze packer. The EZ Drill SVB squeeze

packer may be used in conjunction with a poppet-type valve

adapter kit. When lowered into the well, the tapered nose of

the alignment tool guides the main body into the shifted

lower casing (Figure 1).

Continued lowering forces the larger, close-fitting outer case

of the alignment tool into the lower casing string to align the

casing sections.

Casing Stabilization

The EZ Drill (or adapted EZ Drill SVB) squeeze packer is set

by tubing or drillpipe to pack off within the upper string. The

packer forms an upper seal for placement of permanent

stabilizing cement behind the realigned casing and holds the

alignment tool in place across the parted section of the

casing. Cement slurry is then pumped through the squeeze

packer and the alignment tool filling the casing and the

formation annular space, surrounding the casing alignment

tool (Figure 2). After the cement has set, the squeeze packer,

alignment tool, and cement are drilled out with a

conventional rock bit, leaving a uniform diameter passage

through the casing ID (Figure 3). The new cement barrier

also helps isolate the casing interior from formation fluid or

gas intrusion.

Figure 1Running

the Casing Alignment Tool

Figure 2Aligning and Squeezing the Parted Casing

Figure 3Drilling Out the Casing

Alignment Tool

HA

L1

55

80


Drillable

ServiceT

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Equipment

After the problem well is evaluated, the proper alignment

tool is built. Casing alignment tools are custom

manufactured for specific jobs because of the variety of

diameter/length combinations possible. Alignment tool ODs

vary according to individual casing weights to minimize

clearance between the alignment tool and the casing ID. This

helps establish minimum alignment variation between upper

and lower realigned casing sections. Alignment tool lengths

vary because casing separation lengths vary as do the lengths

of damaged casing. Experience proves that 10 ft of alignment

tool should extend into good pipe on both sides of the

damaged or parted casing.

As mentioned, the lower end of EZ Drill® (poppet valve)

squeeze packers have threads to attach the alignment tool.

EZ Drill squeeze packers are not made for casings 7 5/8 in. or

larger, so the EZ Drill SVB squeeze packer plus poppet valve

conversion kit is needed to attach the alignment tool. This

conversion kit also changes the packer from side discharge to

bottom discharge so cement slurry will flow through the

alignment tool and exit at the lower end.

The casing alignment tool is available in 4 1/2 to 20-in. sizes.

Casing Alignment Tool with EZ Drill® Squeeze Packer

Casing Alignment Tool

with EZ Drill® SVB and Poppet-Type Adapter Kit

Casing Alignment Tool Tapered Nose

HA

L1

60

04

HA

L1

60

02

HA

L1

60

03


Drillable

ServiceT

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DrillGun™ Assembly (EZSVB)

The DrillGun™ assembly is a drillable

perforating system that provides

reliable, quality performance while

lowering overall wellsite costs by:

• Eliminating the high costs

associated with wireline services.

• Eliminating the need to switch to a

mud system for workovers.

The DrillGun perforating system

combines rugged, reliable Halliburton

perforating components with the

versatility of drillable materials. The

DrillGun perforating system is a

drillable, disposable system that helps

save time and money.

Components of the drillable perforating

system are drillpipe conveyed to the zone

of interest; thereby eliminating

mobilization or demobilization charges

normally associated with wireline units.

And, since no mud system is needed,

clear fluids can remain in place for

workover operations. When the

EZ Drill® SVB packer is set, the firing

head is actuated by pressure applied

through the tubing. After perforating,

the gun can be drilled out with

conventional drilling methods.

The drillable perforating system is

ideal for:

• Single-trip perforating, packer

placement, and cementing

on tubing.

• Cementing and perforating in

underbalanced conditions.

• Plug-to-abandon operations.

• Workover cementing with

clear fluids.

• Plugback set on wireline.

• Limited entry drillstem testing.

Components of the drillable

perforating system include:

• Aluminum perforating gun.

• High-performance, perforating

charges.

• Halliburton’s industry-proven

EZ Drill SVB packer.

• Also available in select sizes with

Fas Drill® SVB and composite gun

systems. For more information,

contact your local Halliburton

representative. HA

L1

20

56

DrillGun™ Assembly (EZSVB)

DrillGun™ Assembly Perforating


in.

Thread Size and Type

Maximum ODin. (cm)

Maximum Operating Pressurepsi (MPa)

Minimum Operating Pressurepsi (MPa)

Temperature RatingF (C)

MaximumOverall Length

ft (m)

Weightlb (kg)

1012886934

2 7/8-in. EU 8 Rd(73.03 mm EU 8 Rd)

4.00(10.16)

14,500(99.98)

3,500(24.13)

350 (max.)(176.7)

3.98(1.213)

79(34.0)

1012886927

2 7/8-in. EU 8 Rd(73.03 mm EU 8 Rd)

7.00(17.78)

14,500(99.98)

3,500(24.13)

350 (176.7)*

4.10(1.251) N/A

*Dependent on explosives. For use in wells above 350°F, contact a Halliburton TCP Technology representativeThese ratings are guidelines only. For more information, contact your local Halliburton representative.


Drillable

ServiceT

ools

DrillGun™ Packers

Part Number and Tool Size

in.Description

ExtendedTension Sleeve

Part Number

Stinger and Coupling

Part Number

1013770745

Packer Assembly, Squeeze, EZ Drill® SVB with DrillGun™ Adapter 100073013 100013760

90321

1013770755 1/2

Packer Assembly, Squeeze, EZ Drill SVB with DrillGun Adapter 100073013 100013760

90321

1013770767


100073254

1013770777 5/8


100073254

1013770788 5/8


100073254

1013770799 5/8


100073347

10138469311 3/4


100073347

10137716711 3/4

Packer Assembly, Squeeze, EZ Drill SVB, Top Slips Wicker, Bottom Slips MCC

Buttons with DrillGun Adapter100073015 100013722

100073347

10137716813 3/8

DrillGun Packer Assembly, MCC Button Slips, EZ Drill SVB 100073015 100013722

100073347

1013796987 HW

Packer Assembly, Fas Drill®, SVB Valve with 2 7/8 8 Rd EU

DrillGun Adapter, 29 to 38 lbN/A N/A

1013796997 LW

Packer Assembly, Fas Drill, SVB Valve with 2 7/8 8 Rd EU DrillGun Adapter,

20 to 29 lbN/A N/A

1013797007 5/8 HW

Packer Assembly, Fas Drill, SVB Valve with 2 7/8 8 Rd EU DrillGun Adapter N/A N/A

1013797019 5/8 HW

Packer Assembly, Fas Drill, SVB Valve with 2 7/8 8 Rd EU DrillGun Adapter N/A N/A

Note: For 16-in. application, use EZ Drill® SV Packer (100073426) with modified lower slip support (100073022).These ratings are guidelines only. For more information, contact your local Halliburton representative.


Drillable

ServiceT

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Drilling Instructions for EZ Drill® Tools

Suggested Drilling Technique for DrillableSqueeze Packers and Bridge Plugs

The best technique for drilling squeeze packers and bridge

plugs will vary with available equipment, but in general, the

following is suggested as a guide when drilling with rotary

equipment:

A junk basket should be placed above the bit when normal

circulation is employed.

Variations in rotary speed and bit weight should be employed

to help break up the metal parts and to reestablish bit

penetration should it cease while drilling. Penetration

stoppage because of “bit tracking” may require picking the bit

up above the drilling surface. Rapid bit contact and weight

application while continuing rotation will aid in breaking up

the established bit pattern and help to reestablish bit

penetration.

Note: Newer generation “cyber” rigs may require jars run in the

drilling bottomhole assembly be activated to impact the EZ

Drill SV tools and help establish penetration.

Additional information on drilling and milling of packers

can be found in the Drillable Tools Manual.

Suggested Milling Technique for DrillableSqueeze Packers and Bridge Plugs

This information is provided as a guide to be used if the

customer has no choice and must rely on milling to remove a

drillable packer. It is suggested that removal be accomplished

by drilling with a rock bit if possible.

• Mill tool: Junk type

• Bit type: Short- or medium-toothed hard-formation bit

(IADC Codes 2-1, 2-2, 2-3, 2-4, and 3-1)

• Rotary speed: 75 to 120 rpm

• Weight on bit: Apply 5,000 to 7,000 lb (2268 to 3175 kg)

until the top end of the packer mandrel is drilled,

(4 to 5 in. or 102 to 127 mm) and weight can be applied

across the full bit diameter, then increase to 2,000 to

3,000 lb (907 to 1361 kg) per inch of bit diameter to drill

out the remainder of the packer. (With 4 3/4-in. bit, use

9,500 to 14,000 lb or 4309 to 6350 kg).

• Drill collars: As required for weight and bit stabilization.

When reverse circulation is to be employed, casing scrapers

should have fluid passages as large as that through the bit so

cuttings will not tend to bridge at that point.

Some manufacturers produce a short version especially for

packer drilling.

• Rotation: 60 to 150 rpm

• Weight on mill: 5,000 to 8,000 lb (2268 to 3629 kg)

Additional Tips

1. Be sure to eliminate repeated particle milling by

removing cuttings from the milling area. Mill

manufacturers recommend mud viscosity of 60 CPS

and a minimum annular velocity of 120 ft/min

(36.58 m/min) to assure cutting removal.

2. Never start a mill on the target packer. Begin rotation a

foot or so above the target and slowly lower the mill

onto the target.

3. Never apply weight in excess of the recommended

amount. Excess weight could cause tearing out large

chunks of the target packer. A bailer trip might then be

necessary to remove these chunks, which can roll

around under the mill, before penetration can be re-

established.

4. Maintain a constant milling rate by continually

slacking off weight. Never allow the mill to drill off.


Drillable

ServiceT

ools

Fas Drill® Squeeze Packer

The Fas Drill® squeeze packer has a one-way poppet-valve

cement retainer that checks backflow and pressure from

below the packer after remedial cementing operations.

Designed for use at temperatures ranging from 50 to 250°F

(10 to 121°C), the packer has minimal ferrous metal content,

which allows for easy drillout. The poppet does not restrict

fluid movement through the packer from above.


• Each tool consists of composites and a packer set with

only minimal ferrous metal content.

• The packer can be drilled out with conventional tricone,

PDC, or junk-mill bits.

• The packer can function as cement retainers in squeeze

cementing operations on land-based or offshore rigs, in

vertical or deviated wells.

• The composite packer design reduces drillout time,

resulting in shorter rig times and less likelihood of

casing damage.

Operation

During operation, the packer operating mandrel (stinger) is

inserted into the packer bore, where it seals the workstring

and distributes weight to the slips and packer rubbers. The

maximum allowable pipe weight is then set on the packer for

a tighter fit. During operation, hydraulic forces can add or

subtract weight on the packer. Before using the packer,

operators should complete hydraulic calculations to prevent

overloading or pumpout.

Setting Procedures

Operators can use one of the following types of equipment

to set Fas Drill packers:





HA

L1

20

50

Fas Drill® Squeeze Packer


Drillable

ServiceT

ools

Fas Drill® Squeeze Packers


in.

PackerType

Casing Sizein.

Casing Weight

lb/ft

Maximum Casing ID in. (cm)


Maximum OD

in. (cm)

Lengthin. (cm)


°F (°C)

Maximum Recommended

Pressure psi (MPa)

Maximum Weight lb (kg)

100073667802.92875

2 7/8

PoppetSqueeze 2 7/8 6.40 - 7.90 2.44

(6.20)2.32

(5.89)2.18

(5.54)19.15

(48.64)50 - 250

(10 - 121)5,000

(34.47)16,000 (7258)

100004410802.93500

3 1/2

PoppetSqueeze 3 1/2 9.20 - 12.70 2.99

(7.59)2.75

(6.99)2.56

(6.50)22.74

(57.76)50 - 250

(10 - 121)5,000

(34.47)16,000 (7258)

100013789802.94500

4 1/2

PoppetSqueeze 4 1/2 9.50 - 13.50 4.09

(10.39)3.92

(9.96)3.66

(9.30)29.02

(73.71)50 - 250

(10 - 121)5,000

(34.47)60,000

(27 216)

100073689802.95000

5

PoppetSqueeze 5 11.50 - 18.00 4.56

(11.58)4.27

(10.85)3.97

(10.08)29.33

(74.50)50 - 250

(10 - 121)5,000

(34.47)60,000

(27 216)

100013793802.95500

5 1/2

PoppetSqueeze 5 1/2 15.50 - 23.00 4.95

(12.57)4.67

(11.86)4.37

(11.10)27.86

(70.76)50 - 250

(10 - 121)5,000

(34.47)60,000

(27 216)

100073701802.97000

7 HW

PoppetSqueeze 7 29.00 - 38.00 6.18

(15.70)5.92

(15.04)5.50

(13.97)35.96

(91.34)50 - 250

(10 - 121)5,000

(34.47)80,000

(36 288)

100073709802.97010

7

PoppetSqueeze 7 20.00 - 29.00 6.46

(16.41)6.18

(15.70)5.80

(14.73)35.96

(91.34)50 - 250

(10 - 121)5,000

(34.47)80,000

(36 288)

1019937359 5/8

PoppetSqueeze 9 5/8 29.30 - 70.30 9.06

(23.01)8.16

(20.73)7.75

(19.69)50.98

(129.49)50 - 250

(10 - 121)5,000

(34.47)100,000(45 358)



Drillable

ServiceT

ools

Fas Drill® SVB Squeeze Packer

The Fas Drill® SVB (sliding valve

brass) packer has a stinger-operated

sliding valve that holds pressure from

both directions. The sliding valve is

opened and closed with workstring

manipulation. When weight is placed

on the set packer, the sliding valve

opens. When pipe weight is lifted

from the packer and the stinger is

removed from the packer bore, the

sliding valve closes, which isolates

cement below the packer from the

pressure and fluid above the packer.

The Fas Drill SVB squeeze packer is

designed for use at temperatures

ranging from 50 to 250°F (10 to

121°C), and differential pressures up

to 5,000 psi (34.47 MPa). The packer

has minimal ferrous metal content,

which allows for easy drillout.


• Consists of composites and a packer

set with only minimal ferrous

metal content

• Can be drilled out with

conventional tricone, PDC, or

junk-mill bits

• Functions as cement retainer in

squeeze cementing operations

on land-based or offshore rigs,

in vertical, deviated, or

horizontal wells

• Design reduces drillout time,

resulting in shorter rig times and

less likelihood of casing damage

• Packer stinger design allows for the

seal to be carried on the stinger and

not internal to the packer, thus

improving its drillability

Operation





downward so that it unlatches the lock

ring and sets the top packer slips.

A series of applied pulls and hesitations

allow the packer elements to expand

properly and contact the casing ID until

the shear screws shear.

During operation, the packer

operating mandrel (stinger) is inserted

into the packer bore, where it seals the

workstring and distributes weight to

the slips and packer rubbers. The

maximum allowable pipe weight is

then set on the packer for a tighter fit.

During operation, hydraulic forces

can add or subtract weight on the

packer. Before using the packer,

operators should complete hydraulic

calculations to prevent overloading or

pump-out.

Setting Procedures

Operators can use one of the following

types of equipment to set Fas Drill

SVB squeeze packers:



• Coiled tubing hydraulic setting tools


HA

L1

20

51

Fas Drill® SVB Squeeze Packer


Drillable

ServiceT

ools

Fas Drill® SVB Squeeze Packers

Part Number and Tool Size

in.

Casing Size in.

CasingWeight

lb/ft


Minimum Casing ID in. (cm)

Maximum Tool OD in. (cm)

Tool Lengthin. (cm)


°F (°C)

Maximum Recommended

Pressure psi (MPa)

Maximum Weight lb (kg)

101282953802.94600

4 1/24 1/2 9.50 - 13.50 4.09

(10.39)3.92

(9.96)3.66

(9.30)37.58

(95.45)50 - 250

(10 - 121)5,000

(34.47)60,000

(27 216)

1019991145 1/2 5 1/2 15.50 - 23.00 4.95

(12.57)4.67

(11.86)4.37

(11.10)37.58

(95.45)50 - 250

(10 - 121)5,000

(34.47)60,000

(27 216)101246229802.97130

7 HW7 29.00 - 38.00 6.18

(15.70)5.92

(15.04)5.50

(13.97)42.54

(108.05)50 - 250

(10 - 121)5,000

(34.47)80,000

(36 288)

101246156802.97140

77 20.00 - 29.00 6.46

(16.41)6.18

(15.70)5.80

(14.73)42.54

(108.05)50 - 250

(10 - 121)5,000

(34.47)80,000

(36 288)

101206084802.97650

7 5/87 5/8 20.00 - 42.80 7.12

(18.08)6.50

(16.51)6.12

(15.54)42.54

(108.05)50 - 250

(10 - 121)5,000

(34.47)80,000

(36 288)

1019937379 5/8 9 5/8 29.30 - 70.30 9.06

(23.01)8.16

(20.73)7.75

(19.69) 52.70

(133.86)50 - 250

(10 - 121)5,000

(34.47)100,000 (45 358)

101275189802.91075

10 3/410 3/4 45.50 - 65.70 9.95

(25.27)9.50

(24.13)9.00

(22.86)52.58

(133.55)50 - 250

(10 - 121)5,000

(34.47)100,000 (45 358)

101304812802.9110010 3/4 HW

10 3/4 71.10 - 86.20 9.50(24.13)

9.19(23.34)

8.69(22.07)

52.58(133.55)

50 - 250(10 - 121)

5,000 (34.47)

100,000 (45 358)

101252474802.91175

11 3/411 3/4 42.00 - 79.00 11.08

(28.14)10.42

(26.47)9.87

(25.07)52.58

(133.55)50 - 250

(10 - 121)5,000

(34.47)100,000 (45 358)

101252358802.91350

13 3/813 3/8 48.00 - 76.60 12.71

(32.28)12.28

(31.19)11.68

(29.67)52.58

(133.55)50 - 250

(10 - 121)5,000

(34.47)100,000 (45 358)

10175630716 16 97.00 - 109.60 14.85

(37.72)14.68

(37.29)13.96

(35.46)62.50

(158.75)50 - 150(10 - 66)

2,000(13.79)

100,000(45 358)

Note: Packer type is brass sliding valve.These ratings are guidelines only. For more information, contact your local Halliburton representative.


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Fas Drill® Bridge Plug

The Fas Drill® bridge plug is used

similarly to a conventional drillable

bridge plug.

Fas Drill bridge plugs are available in a

variety of models that are categorized

based on temperature rating. The

following series of tools are available:

• 250 Series

• 300 Series

• 350 Series

• 400 Series

Setting equipment and operation are

similar for all series of Fas Drill bridge

plugs. The different series offer

varying operational pressure

differentials ranging from 5,000 psi

(34.47 MPa) up to 15,000 psi

(103.42 MPa). The material

composition, slip arrangement

(composite slips with white ceramic

inserts, composite slips with MCC

inserts, or cast-iron slips with

wickers), and the extrusion limiter

package determine the differential

pressure ratings at the corresponding

temperatures.



set, giving it minimal ferrous metal

content

• Isolates a lower zone during squeeze

cementing operations on land-

based or offshore rigs, in vertical or

deviated wells

• Functions as a bridge plug in multi-

zone stimulation treatments

• Helps save rig time and reduce

casing damage caused by long

drillout processes

• Drills out with conventional tricone,

PDC*, or with junk-mill bits

Operation

Fas Drill bridge plugs can be set on

tubing, on drillpipe, or with

conventional tools, such as electric

wireline. An adapter kit is required for

setting tools.

Setting Procedures


types of equipment to set Fas Drill

bridge plugs:





*Does not apply to cast-iron slip tools

HA

L1

20

41

Fas Drill®Bridge Plug


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Fas Drill® Bridge Plugs

Tool Sizein.

Bridge Plug

Series

Slip Insert Type

Casing Sizein.

Casing Weight

lb/ft



Maximum Tool ODin. (cm)

Lengthin. (cm)

Rated Differential Pressurepsi (MPa)

Part Number

2 7/8 350 MCC 2 7/8 6.40 - 8.70 2.44(6.20)

2.26(5.74)

2.12(5.38)

18.10(45.97)

8,000(55.16) 101329594

3 1/2 HW 350 MCC 3 1/2 12.7 2.75(6.99)

2.75(6.99)

2.56(6.50)

23.39(59.41)

10,000(68.95) 100004422

4 1/2 HW 350 Cast Iron 4 1/2 15.10 - 18.80 3.83(9.73)

3.64(9.25)

3.44(8.74)

28.91(73.43)

10,000(68.95) 101819685

4 1/2 HW 300 MCC 4 1/2 15.10 - 18.80 3.83(9.73)

3.64(9.25)

3.44(8.74)

29.91 (75.97)

10,000(68.95) 101819660

4 1/2 250 MCC 4 1/2 11.60 - 15.10 4.00(10.16)

3.83(9.73)

3.60(9.14)

28.89(73.38)

8,000(55.16) 101544618

4 1/2 300 Cast Iron 4 1/2 11.60 - 15.10 4.00(10.16)

3.83(9.73)

3.60(9.14)

29.99(76.17)

12,000(82.74) min.

See Operating Envelope

101851873

4 1/2 350 Cast Iron 4 1/2 11.60 - 15.10 4.00(10.16)

3.83(9.73)

3.60(9.14)

31.25(79.38)

10,000(68.95) 101853018

4 1/2 300 MCC 4 1/2 9.50 - 13.50 4.09(10.39)

3.92(9.96)

3.66(9.30)

29.70(75.44)

10,000(68.95) 101687898

4 1/2 300 Cast Iron 4 1/2 9.50 - 13.50 4.09(10.39)

3.92(9.96)

3.66(9.30)

30.00(76.20)

12,000(82.74) min.


101851874

4 1/2 350 Cast Iron 4 1/2 9.50 - 13.50 4.09(10.39)

3.92(9.96)

3.66(9.30)

31.20(79.25)

10,000(68.95) 101953454

5 1/2 250 White Ceramic 5 1/2 15.50 - 23.00 4.95

(12.57)4.67

(11.86)4.37

(11.10)31.04

(78.84)

5,000(34.47) min.


101789343

5 1/2 250 MCC 5 1/2 15.50 - 23.00 4.95(12.57)

4.67(11.86)

4.37(11.10)

31.03(78.82)

8,000(55.16) 101504269

5 1/2 300 MCC 5 1/2 15.50 - 23.00 4.95(12.57)

4.67(11.86)

4.37(11.10)

34.00(86.36)

10,000(68.95) min.


101554890

5 1/2 300 Cast Iron 5 1/2 15.50 - 23.00 4.95(12.57)

4.67(11.86)

4.37(11.10)

33.76(85.75)

13,000(89.63) min.


101539225

5 1/2 350 Cast Iron 5 1/2 15.50 - 23.00 4.95(12.57)

4.67(11.86)

4.37(11.10)

31.90(81.03)

10,000(68.95) 101820648

7 250 MCC 7 23.00 - 29.00 6.37(16.18)

6.18(15.70)

5.80(14.73)

35.57(90.35)

10,000(68.95) 101867119

7 350 MCC 7 20.00 - 29.00 6.46(16.41)

6.18(15.70)

5.80(14.73)

35.58(90.37)

8,000(55.16) 100073972

9 5/8 250 MCC 9 5/8 29.30 - 70.30 9.06(23.01)

8.16(20.73)

7.75(19.69)

46.60(118.36)

5,000(34.47) 101994560

Note: Other tool sizes may be available.These ratings are guidelines only. For more information, contact your local Halliburton representative.


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Fas Drill® Frac Plug

The Fas Drill® frac plug is used

similarly to a Fas Drill® bridge plug.

Fas Drill frac plugs are available in a

variety of models that are categorized

based on temperature rating. The

following series of tools are available:

• 250 Series

• 300 Series

• 350 Series

• 400 Series

Setting equipment and operation are

similar for all series of Fas Drill frac

plugs. The different series offer

varying operational pressure

differentials ranging from 5,000 psi

(34.47 MPa) up to 15,000 psi

(103.42 MPa). The material

composition, slip arrangement

(composite slips with white ceramic

inserts, composite slips with MCC

inserts, or cast-iron slips with

wickers), and extrusion limiter

package determine the differential

pressure ratings at the corresponding

temperatures.



set, giving it minimal metal content

• Provides zonal isolation during

multi-zone stimulation treatments

• Holds differential pressure from

above

• Allows flowback from below plug

• Helps save rig time and reduce


drillout processes

• Drills out with conventional tricone,

PDC*, or junk-mill bits

• Lower pin design prevents plug-off

• Ball can be run in place or dropped

from surface

Operation

The Fas Drill frac plug is designed to

be set on Advanced® slickline using the

DPU® downhole power unit or electric

wireline. An adapter kit is required for

setting tools.

Setting Procedures


types of equipment to set Fas Drill frac

plugs:




*Does not apply to cast-iron slip tools

HA

L1

20

42

Fas Drill®Frac Plug


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Fas Drill® Frac Plugs

Tool Sizein.

Frac Plug Series

Load Bearing Slip Insert Type

(Bottom Slips)

Casing Sizein.

Casing Weight

lb/ft




Lengthin. (cm)


Part Number

4 1/2 HW 300 MCC 4 1/2 15.10 - 19.20 3.83

(9.73)3.64

(9.25)3.44

(8.74)26.76

(67.97)12,000(82.74) 101924679

4 1/2 HW

300Caged Ball MCC 4 1/2 15.10 - 19.20 3.83

(9.73)3.64

(9.25)3.44

(8.74)28.09

(71.35)12,000(82.74) 102080921

4 1/2 HW 325 Cast Iron 4 1/2 15.10 - 19.20 3.83

(9.73)3.64

(9.25)3.44

(8.74)26.46

(67.21)10,000(68.95) 101924180

4 1/2 325 MCC 4 1/2 13.50 - 15.10 3.92 (9.96)

3.83(9.73)

3.54 (8.99)

25.16 (63.91)

10,000(68.95) 102004486

4 1/2 350 Cast Iron 4 1/2 13.50 - 15.10 3.92 (9.96)

3.83(9.73)

3.54 (8.99)

25.16 (63.91)

10,000(68.95) 102089986

4 1/2 300 Cast Iron 4 1/2 11.60 - 15.10 4.00(10.16)

3.83(9.73)

3.60(9.14)

28.73(72.90)

12,000(82.74) min.

See Operating Envelope101851890

4 1/2 300Caged Ball Cast Iron 4 1/2 11.60 - 15.10 4.00

(10.16)3.83

(9.73)3.60

(9.14)30.40

(77.22)

12,000(82.74) min.


4 1/2 350 Cast Iron 4 1/2 11.60 - 15.10 4.00(10.16)

3.83(9.73)

3.60(9.14)

30.84(78.33)

10,000(68.95) 101852664

4 1/2 275 White Ceramic 4 1/2 11.60 - 13.50 4.00

(10.16)3.92

(9.96)3.66

(9.30)24.27

(61.65)8,000

(55.16) 102054482

4 1/2 400 Cast Iron 4 1/2 11.60 - 13.50 4.00(10.16)

3.92(9.96)

3.66(9.30)

31.48(79.96)

12,000(82.74) 102085195

4 1/2 300 White Ceramic 4 1/2 9.50 - 13.50 4.09

(10.39)3.92

(9.96)3.66

(9.30)28.60

(72.64)8,000

(55.16) 101876059

4 1/2 300Caged Ball

White Ceramic 4 1/2 9.50 - 13.50 4.09

(10.39)3.92

(9.96)3.66

(9.30)28.60

(72.64)8,000

(55.16) 101697372

4 1/2 300 MCC 4 1/2 9.50 - 13.50 4.09(10.39)

3.92(9.96)

3.66(9.30)

28.59(72.62)

10,000(68.95) 101697394


(10.39)3.92

(9.96)3.66

(9.30)30.51

(77.50)10,000(68.95) 101935933

5HW 250 White

Ceramic 5 18.00 - 21.40 4.27(10.85)

4.12(10.48)

3.85(9.78)

24.86(63.14)

8,000(55.16) 101994007

5HW 325 Cast Iron 5 18.00 - 21.40 4.27

(10.85)4.12

(10.48)3.85

(9.78)25.01

(63.53)10,000(68.95) 101994453

5HW 400 Cast Iron 5 18.00 - 21.40 4.27

(10.85)4.12

(10.48)3.85

(9.78)25.01

(63.53)10,000(68.95) 101995195

5 350 Cast Iron 5 11.50 - 18.00 4.56(11.58)

4.27(10.85)

3.97(10.08)

31.69(80.49)

10,000(68.95) 101871601

5 1/2 HW 300 MCC 5 1/2 20.00 - 29.70 4.78

(12.14)4.38

(11.13)4.15

(10.54)31.56

(80.16)10,000(68.95) 101848553

5 1/2 250 White Ceramic 5 1/2 15.50 - 23.00 4.95

(12.57)4.67

(11.86)4.37

(11.10)30.32

(77.01)

5,000(34.47) min.


5 1/2 250Caged Ball

White Ceramic 5 1/2 15.50 - 23.00 4.95

(12.57)4.67

(11.86)4.37

(11.10)31.96

(81.18)

5,000(34.47) min.


5 1/2 300 MCC 5 1/2 15.50 - 23.00 4.95(12.57)

4.67(11.86)

4.37(11.10)

31.71(80.54)

10,000(68.95) min.


5 1/2 300Caged Ball MCC 5 1/2 15.50 - 23.00 4.95

(12.57)4.67

(11.86)4.37

(11.10) 33.16(84.23)

10,000(68.95) min.



(12.57)4.67

(11.86)4.37

(11.10)30.61

(77.75)

13,000(89.63) min.


5 1/2 350 Cast Iron* 5 1/2 15.50 - 23.00 4.95(12.57)

4.67(11.86)

4.37(11.10)

31.75(80.65)

10,000(68.95) 101824824

*Top slip set type is same as load bearing slip type.All top slip sets are composite with white ceramic inserts unless otherwise noted.All tools in this table have a 1.00-in. ID.Most tools in this table have both pumpdown groove in muleshoe and pinned slips.Note: Other tool sizes may be available.These ratings are guidelines only. For more information, contact your local Halliburton representative.


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Fas Drill® Fusion Plugs

Fas Drill® Fusion bridge and frac plugs

are part of the Halliburton advanced

composite line of drillable equipment.

These tools offer industry-exceptional

drillout performance while maintaining

differential pressure ratings of

10,000 psi at 325°F. The tools are

specifically designed to provide zonal

isolation of the horizontal wellbore

between multi-zone stimulation

treatments.

To enhance reliability in high debris or

horizontal applications, the Fas Drill

Fusion tools are equipped with solid

slip rings, a single element package, and

a one-piece extrusion limiter (retaining

bands not required) that are press-fit

into each single-piece element package

end. This allows for run-in speeds in

excess of 500 ft/min in vertical sections

and 250 ft/min in horizontal sections,

all while being able to pump at rates in

excess of 14 bbl/min passed the tools.

Fas Drill Fusion plugs are available in:

• Bridge plugs – Offer isolation from

above the isolation point or below.

All Halliburton bridge plugs are

top drilling.

• Frac plugs – Designed to only isolate

from above the plug. The ball check

valve in the top allows pressure and

flow from below to assist in wellbore

cleanup after stimulation. The ball

can be run in place or dropped from

surface after the plug is set.

• Caged ball frac plugs – Designed to

only isolate from above the plug. The

ball check valve in the top is captured

and allows pressure and flow from

below to assist in wellbore cleanup

after stimulation. It is specifically

designed for deviated wellbores

where it may be difficult to obtain a

seal with a free-floating ball.


• Premier plug for horizontal

applications

• Bridge plug holds pressure from

both above and below

• Frac plug holds pressure from above

but allows flowback from below

• Can be used in vertical or deviated

wellbores

• Run-in speeds in horizontal

sections in excess of 250 ft/min and

speeds in vertical sections in excess

of 500 ft/min

• Pump rates passed the tool in excess

of 14 bbl/min (without

pumpdown ring)

• Caged ball frac plug can be

converted to bridge plug

• No metal shear screws required

to set

• Drills out with conventional sealed

tricone bits, PDC bits, or mills with

jointed pipe or coiled tubing

• Locking thread mechanism for

drillout

• Helps save rig time and reduces


drillout process

Fas Drill®Fusion Plugs

HA

L3

25

73


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Operation

Fas Drill® Fusion plugs can be run on:


• Advanced® slickline service using the DPU® setting tool

• Coiled tubing or jointed pipe via hydraulic setting tools

Simply attach the specifically designed Halliburton adapter

kit to your preferred setting tool and thread the Fas Drill

Fusion plug in place. The tool can then be run in the well

and set.

Fas Drill® Fusion Bridge and Frac Plugs

Tool Sizein.

Frac Plug Series

Slip Insert Type

Casing Sizein.

Casing Weight

lb/ft




Lengthin. (cm)


Part Number

4 1/2 325 MCC 4 1/2 11.60 - 13.50 4.00(10.16)

3.92(9.96)

3.66(9.30)

31.32(79.55)

10,000(68.95) 101925199

4 1/2 325 Caged Ball MCC 4 1/2 11.60 - 13.50 4.00

(10.16)3.92

(9.96)3.66

(9.30)32.32

(82.09)10,000(68.95) 101925202

Note: Other tool sizes may be available.Bridge plugs have same pressure differential rating from above as the frac plug. Pressure differential rating from below is reduced to 6,000 psi.These ratings are guidelines only. For more information, contact your local Halliburton representative.


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Halliburton 250-Series Frac Plugs

Halliburton offers a selection of composite frac plugs that can

be run in wells at temperatures up to 250°F. The products

offered come from the Halliburton line of Fas Drill®

composite tools and Obsidian® composite tools. These plugs

offer exceptional drillout performance while maintaining

differential pressure ratings of up to 10,000 psi, depending on

wellbore temperature. The 250-series of tools are specifically

designed to provide zonal isolation of the horizontal wellbore

between multi-zone stimulation treatments.

To enhance reliability in high debris or horizontal

applications, the 250-series of tools are equipped with pinned

slips, allowing the plugs to have run-in speeds in excess of

500 ft/min in vertical sections and in excess of 250 ft/min in

horizontal sections, all while being able to pump at rates up

to 12 bbl/min.


• Composite slips with ceramic inserts

• Pump rates passed the tool in excess of 12 bbl/min

(without pumpdown ring)

• Premier plugs for horizontal applications

• Frac plug holds pressure from above but allows flowback

from below

• Can be used in vertical or deviated wellbores

• Run-in speeds in horizontal sections in excess of

250 ft/min and speeds in vertical sections in excess of

500 ft/min

• Drills out with conventional sealed tricone bits, PDC

bits, or mills with jointed pipe or coiled tubing

• Helps save rig time and reduce casing damage caused by

long drillout process

Operation

The 250-series composite plugs can be run on:


• Advanced® slickline service using the DPU® setting tool


Fas Drill® 250Frac Plug

HA

L3

29

18

Obsidian®Frac Plug

HA

L2

42

32


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Fas Drill® 250 Plugs

Tool Sizein.

Frac Plug Series

Slip Insert Type

Casing Sizein.

Casing Weight

lb/ft




Lengthin. (cm)


Part Number

4 1/2 Fas Drill® 250 White Ceramic 4 1/2 11.60 - 13.50 4.00

(10.16)3.92

(9.96)3.66

(9.30)22.06

(56.03)8,000

(55.16) min.* 101948570

4 1/2 Fas Drill 250Caged Ball

White Ceramic 4 1/2 11.60 - 13.50 4.00

(10.16)3.92

(9.96)3.66

(9.30)23.46

(59.56)8,000

(55.16) min.* 101973533

5 1/2 Fas Drill 250 White Ceramic 5 1/2 17.00 - 23.00 4.892

(12.73)4.67

(11.86)4.37

(11.10)24.28

(61.67)8,000

(55.16) 101976019

5 1/2 Fas Drill 250Caged Ball

White Ceramic 5 1/2 17.00 - 23.00 4.892

(12.73)4.67

(11.86)4.37

(11.10)25.67

(65.20)8,000

(55.16) 101974547

*See Operating Envelope


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Obsidian® 250 Frac Plugs

Part Number Tool Rating* Casing Size in.

Casing Weight

lb/ft


Minimum Casing ID

in. (cm)


Lengthin. (cm)

Pumpdown Groove

101753030 10K 250°F 4 1/2 11.6 - 13.5 4.00 (10.16)

3.92(9.96)

3.66(9.30)

28.92(73.45) Yes

101859398 10K 250°F 4 1/2 11.6 - 13.5 4.00 (10.16)

3.92(9.96)

3.66(9.30)

28.87(73.33) No

101848503 See Operating Envelope 5 1/2 17 - 23 4.892 (12.43)

4.67(11.86)

4.37(11.10)

30.79(78.21) Yes

101948788Caged Ball See Operating Envelope 5 1/2 17 - 23 4.892

(12.43) 4.67

(11.86) 4.37

(11.10) 30.79

(78.21) Yes

*See operating envelope for pressure ratings at lower temperatures


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250-Series Fas Drill® Frac Plugs with Foam

Halliburton offers a 250-series composite Fas Drill® frac plug

that allows the plug to be pumped down casing strings where

the liners are placed in the horizontal section of the wellbore.

The foam plug allows the plug to be pumped in the large

casing above the liner, reducing the fluid amount needed to

get the plugs to depth. These plugs offer exceptional drillout

performance while maintaining differential pressure ratings

of up to 10,000 psi, depending on wellbore temperature. The

250-series of tools are specifically designed to provide zonal

isolation of the horizontal wellbore between multi-zone

stimulation treatments.

A Gun Deployment System (GDS) is also available to allow

perforating guns to be pumped down through the larger

casing and horizontal liner hanger systems without the need

to set and utilize a drillable tool. This system uses the foam

plug system with Halliburton's composite material body.


• Composite slips with ceramic inserts

• Pump rates passed the tool in excess of 12 bbl/min

(without pumpdown ring)

• Premier plugs for horizontal applications

• Frac plug holds pressure from above but allows flowback

from below

• Can be used in vertical or deviated wellbores

• Run-in speeds in horizontal sections in excess of

250 ft/min and speeds in vertical sections in excess of

500 ft/min

• Drills out with conventional sealed tricone bits, PDC

bits, or mills with jointed pipe or coiled tubing


long drillout process

GunDeployment

System Assembly

HA

L3

73

44

250-Series Fas Drill Frac Plug

with Foam

HA

L3

73

53


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Operation

The 250-series composite plugs can be run on:


• Advanced® slickline service using the DPU® downhole

power unit setting tool


Fas Drill® 250 Plugs with Foam

Tool Sizein.

Frac Plug Series

Slip Insert Type

Casing Sizein.

Foam ODin. (cm)

Casing Weight

lb/ft




Lengthin. (cm)


Part Number

4 1/2 Fas Drill® 250 White Ceramic 4 1/2 6.25

(15.88)11.60 - 13.50

4.00(10.16)

3.92(9.96)

3.66(9.30)

37.61(95.53)

8,000(55.16) min.* 102010267

5 1/2 Fas Drill 250 White Ceramic 5 1/2 6.25

(15.88)17.00 - 23.00

4.892(12.73)

4.67(11.86)

4.37(11.10)

38.33(97.36)

8,000(55.16) 102071473

*See Operating Envelope.

Gun Deployment System with Foam

CasingSize in.

Foam OD in. (cm)

Maximum Tool OD in. (cm)

Length in. (cm)

Part Number

4 1/2 and 5 1/2

6.25(15.88)

3.66(9.30)

23.55(59.82) 102068778


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Obsidian® Bridge Plug

The Obsidian® bridge plug extends the Halliburton line of

composite products with features similar to the Fas Drill®

product line, including comparable setting equipment, but

with the added benefit of enhanced drillability. The 4 1/2-in.

Obsidian bridge plug has an operational limit of 250°F

(121°C) and 8,000 psi (55.16 MPa) differential pressure,

while the 5 1/2-in. Obsidian bridge plug is rated per the

operating envelope.


• Designed for isolating perforated intervals or portions of

a wellbore, the Obsidian bridge plug uses a unique

material in its construction and its ease of drilling makes

it ideal for horizontal applications.

• To enhance reliability in high debris or horizontal

applications, these bridge plugs are equipped with

stronger slip bands and are attached to the mandrel with

shearable composite pins. This allows run-in speeds in

horizontal sections in excess of 250 ft/min and speeds in

vertical sections in excess of 400 ft/min.

• Consists of composites and a packer set with no metal

content.

• Isolates a lower zone during squeeze cementing

operations on land-based or offshore rigs, in vertical or

deviated wells.

• Functions as a bridge plug in multi-zone stimulation

treatments.


long drillout processes.

• Drills out with conventional tricone, PDC, or with junk-

mill bits.

Setting Procedures

Operators can use any of the following methods to set

Obsidian bridge plugs:

• Electric wireline setting tool

• Slickline setting tool

• Hydraulic setting toolObsidian®Bridge Plug

HA

L2

42

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Obsidian® Bridge Plugs

Part Number

Tool Rating*

Casing Sizein.

Casing Weight

lb/ft


Minimum Casing ID

in. (cm)


Lengthin. (cm)

Pumpdown Groove

101753025 See Operating Envelope 4 1/2 11.6 - 13.5 4.00

(10.16)3.92

(9.96)3.66

(9.30)28.92

(73.45) Yes

101859399 See Operating Envelope 4 1/2 11.6 - 13.5 4.00

(10.16)3.92

(9.96)3.66

(9.30)28.92

(73.45) No

101848502 See Operating Envelope 5 1/2 17 - 23 4.892

(12.43) 4.67

(11.86) 4.37

(11.10) 30.36

(77.11) Yes

*See operating envelope for pressure ratings at lower temperatures.


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Composite Plugs with Pumpdown Feature

As the industry has shifted to more deviated and horizontal

applications, it has become a standard practice to pump

composite tools down to depth. In most cases, the

bottomhole assemblies (BHA) include some type of depth

correlation device, wireline gun systems, wireline setting

tools, and the composite plug. In some instances, getting this

large BHA to depth was difficult due to limited hydraulic

horsepower at surface to achieve a high enough rate to pump

these tools down. To help facilitate getting the tools to depth,

Halliburton developed Fas Drill® plugs and Obsidian® plugs

with pumpdown feature. This feature allows the same BHAs

to be pumped to depth with significantly reduced pump rates

over tools that do not have this feature—in most cases a

reduction of up to 50%. This feature includes a separately

installed rubber ring that reduces the gap between the overall

tool OD and the ID of the casing. The Halliburton

pumpdown ring’s unique design allows it to fall back on itself

to reduce the ring OD should a reduced ID be encountered,

allowing the tool to pass through. This feature does not affect

the overall tool performance or types of setting equipment

that can be used.

Setting Procedures


set the composite plugs with pumpdown feature:



• Hydraulic setting tools


• Available in select sizes for both frac plugs and

bridge plugs

• Facilitates pumping the bottomhole assembly to depth at

reduced pump rates

• Reduces the total volume of fluid required to pump the

tools down

• Can be run through Halliburton's low profile stage frac

wellhead isolation tool without having to remove the tool

from the wellhead

• Can be drilled up with conventional tricone drill bits or

junk-style millsFas Drill® Frac Plug

with Pumpdown Feature

HA

L2

50

40

HA

L2

50

45


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Pumpdown Rings

PartNumber

Tool/Casing Size in.

Casing Weight lb/ft

Casing ID in. (cm)

OD Installed in. (cm)

101559835 4 1/2 9.5 4.09(10.39)

3.89(9.88)

101528110 4 1/2 11.6 4.00(10.16)

3.80(9.65)

101559836 4 1/2 13.5 3.92(9.96)

3.72(9.45)

101703532 4 1/2 HW 15.1 3.83(9.72)

3.62(9.19)

101559837 4 1/2 15.1 3.83(9.72)

3.62(9.19)

101768815 5 11.5 4.56(11.58)

4.37(11.10)

101768886 5 13 4.49(11.41)

4.30(10.91)

101768887 5 15 4.41(11.20)

4.21(10.69)

101768888 5 18 4.28(10.86)

4.08(10.35)

101531148 5 1/2 15.5 4.95(12.57)

4.76(12.09)

101493800 5 1/2 17 4.89(12.43)

4.70(11.94)

101531149 5 1/2 20 4.78(12.14)

4.59(11.66)

101531150 5 1/2 23 4.67(11.86)

4.48(11.38)

101815300 5 1/2 20 - 23 Only for use with 4.15-in. OD tools

4.37(11.01)


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Drilling Instructions for Fas Drill® Tools

Removal Techniques for Fas Drill Drillable Tools

The Fas Drill® line has been designed to provide the best

drillability of any cement retainer and plugs in the energy

business today. All materials used in the construction of

these packers are selected for their blend of performance and

drillability. Even with this design consideration, there are

best practices for drilling the Fas Drill tools.

Note: Whenever possible, spot cement on top of the squeeze

packer after remedial cementing. This helps reduce the

possibility of packer part rotation.

The best drilling/milling technique will vary with the

equipment that will be used to drill or mill the packer or

plug. There follows four techniques, drilling while circulating

down the workstring, drilling while reverse-circulating,

milling the packer with conventional methods, and milling /

drilling with coiled tubing.

Note: If at any time progress through the packer/plug stops,

slow the rotary speed, set more weight, set less weight, slow

circulation rate, or do combinations of the preceding. Changes

in drilling style can help to break up pieces that are not

breaking with the following drilling practice.

Milling With Coiled Tubing

Milling Fas Drill tools with coiled tubing is a process that has

a great deal of variables. The following recommendations are

guidelines that have been developed from field data but do

not fully represent all the means for drilling up Fas Drill tools

with coiled tubing. Modifications to the following methods

may be needed to optimize individual milling processes.

Milling the Packer/Plug

Rig up milling assembly on coiled tubing. Mill and motor

selection should be based on the following:

• Five-bladed mill only: Medium to heavy “cutrite” 1/8 to

1/4 in. size, with a 30° taper from the outside inward

toward the middle

• Motor speed: 200 to 1,400 rpm

• Drilling weight: 500 to 3,000 lb (225 to 1350 kg)

• Use three-bladed mill for 2 7/8-in. packers and plugs

Mill – Five Blade – Fas Drill® Removal (802.99999)


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Excessive pump rates may generate hydraulic forces, which

tend to lift the mill off the target (commonly referred to as

“hydraulic lock”). This will significantly increase milling

times. An indication of excessive pump rate would be the

inability to stall the motor with increased weight on the mill.

• Pump slowly through the assembly to check the rotation

of the motor.

• Run motor/mill assembly to bottom of the hole and tag

the packer/plug.

• Pick up at least 3 ft (1 m) and begin pumping. Pump rate

should be determined by the downhole assembly and

coiled tubing.

• Slack off assembly until desired weight is setting on the

packer/plug.

• Continue slacking off weight as packer/plug material

is removed.

Suggestions and Recommendations for CoiledTubing Drilling/Milling

Experience has shown the best bit for removing Fas Drill®

tools is a short or medium tooth hard formation bit (IADC

codes 2-1, 2-2, 2-3, 2-4, and 3-1). Optimum bit size is

92 to 95% of casing drift diameter. Longer drilling times

should be expected when using other bit types. Motor speeds

from 50 to 400 rpm are recommended.

Variations from the recommended practices may be

necessary to optimize the milling/drilling operations. The

following suggestions may help with developing an

optimized technique.

• Larger-diameter coiled tubing will generate less friction

loss, allowing higher pump rates. It will also reduce the

annular flow area, which will increase the annular

velocity. The torsional yield of the coiled tubing should

be at least twice the maximum output torque of the

motor. This is especially true when running larger

motors with higher torque ratings.

• Motor selection may be the most important factor

because motors operate within a specific range of flow

rates and temperatures. Excessive flow rates damage the

stator, while insufficient flow rates cause the motor to

operate inefficiently or not at all. Do not exceed the

maximum allowable flow rate through or weight on

motor. Pump rates should be sufficient to maintain fluid

velocities capable of carrying the cuttings. In situations

where insufficient circulation can be maintained due to

high fluid hydrostatics, a suspending aid (nitrogen)

should be utilized. Additional milling times may be

experienced when using a gas-assisted system as the

efficiency of the downhole motor will be diminished. It is

important to maintain sufficient fluid velocities at the

target and up the annulus to ensure that cuttings are

carried away properly.

A number of different factors can significantly affect the

ability to maintain these proper fluid velocities. Coiled

tubing size, casing size, motor and mill / bit ODs, etc. will all

play a part in achieving sufficient fluid velocities.

Casing size will affect the annular flow area and either

increase or decrease the annular velocity. We cannot control

this parameter so we strive to control the others.

When feasible, the pump rate should be reduced during a

stall prior to picking up the bottomhole assembly. This

reduces damage to the stator when fluid surges through the

power section, extending the motor’s operating life.

Co-mingled nitrogen can be used to mill / drill composite

packer and plugs. Use enough nitrogen to maintain returns.

Nitrogen will increase the motor stall times due to gas

compression, slowing down the milling operation.

Mill ODs that are too large can prevent proper fluid

circulation. It can prevent larger particles from passing by the

mill and up into the annulus. Slightly undersized mills

perform better due to improved fluid movement around the

mill during the milling operation. This improved fluid flow

allows for better removal of the cuttings.

Experience has shown that a proper mill size is 92 to 95% of

the casing drift diameter.

Example:

4-1/2”, 11.6 #/ft - drift diameter - 3.875”

.92 x 3.875 = 3.548”

.95 x 3.875 = 3.681”

Suggested mill size - 3.625”

Flat mills, while they have larger cutting surfaces, do not

work as good as bladed mills. The optimum milling

technique is one that tears, not cuts.


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Five-bladed mills work better than four-bladed mills.

Four-bladed mills are too aggressive and tend to stall the

motor excessively.

High-pressure wells can inhibit the ability to generate

enough fluid velocity at the mill to carry away cuttings and

debris. High annular pressure can limit the flow rate available

to the motor, decreasing its efficiency. Surface equipment

may not allow the release of high flow rates at high pressures

or operators may prefer not to release pressure at high rates.

High wellhead pressure can cause the surface pump pressure

to exceed the maximum allowable pressure on the coiled

tubing. High-pressure coiled tubing units will be required for

this application.

In deviated well conditions, it may be more difficult to obtain

sufficient fluid velocities than in vertical well conditions. The

eccentric condition will cause reduced flow rates around the

coiled tubing. The drill cuttings, fill, or debris can drop out

and cause sticking of the coiled tubing and/or bottomhole

assembly. Weight-on-bit in a deviated well is also very

important. Motor assemblies vary in dimension and may

drag significantly in deviated sections of the well. The ability

to stack weight on the plug should be modeled beforehand.

Fas Drill® tools are constructed of materials that circulate out

easily due to their lightweight and low-density properties.

The HPHT (high-pressure high-temperature) Fas Drill tools

are constructed with very similar materials as the Fas Drill

tools with a few noted exceptions. The HPHT Fas Drill

bridge plugs have metallic-ceramic-composite (MCC) button

inserts in the slip mechanisms. These buttons are designed to

breakup during drilling or milling, allowing them to be

circulated out of the wellbore. Some HPHT assemblies have

aluminum slips that are easily removed during drilling or

milling.

When milling/drilling predominately composite sections of

packers and plugs, use lightweights (approximately 500 lb

[225 kg]) to avoid motor stalling.

When milling/drilling predominately rubber portions of

packers and plugs, apply weight up to the maximum

allowable weight on the motor. Vary the weight throughout

the rubber milling operations even though progress is slow.

When milling/drilling through bridge plugs that have

differential pressure trapped below the plugs, proceed slowly

through the top 6 in. of the plug. Periodically lift the

bottomhole assembly off the bridge plug as progress is made

through these first 6 in. to ensure pressure venting. This

allows pressure to vent through the ID of the mandrel and

relieves the upward force on the top slips. This procedure

prevents the plug from moving uphole during the milling/

drilling process. The bottomhole assembly should be picked

up while venting to reduce the risk of sticking.

Drilling With Normal Circulation

The best bit for drilling up Fas Drill tools is a short or

medium tooth hard formation bit (IADC codes 2-1, 2-2, 2-3,

2-4, and 3-1). Proper bit size is 92 to 95% of casing drift

diameter. The packers/plugs can be removed with other bit

types but drilling times may be longer. Rotary speeds from 50

to 125 rpm are recommended. Drill collars for weight and

stability are recommended. A junk basket is recommended to

catch larger cuttings that could possibly fall back on the

packer/plug and impede drilling.

To drill packer/plug:

• Tag packer/plug with bit and begin circulation to wash

any loose debris. Circulate at 1/2 to 3 bbl/min. Higher

flow rates can greatly reduce penetration rate by

reducing bit contact.

• Pick up at least 6 in. (16 cm) and begin rotation.

• Set back on the packer/plug while rotating and slack off

2,000 to 3,000 lb per inch of bit diameter (350 to 510 kg

per centimeter of bit diameter). Less weight can be used

for drilling but drilling times may increase.

• Continue slacking off weight as packer material

is removed.


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Drilling With Reverse Circulation

The best bit for drilling up Fas Drill® tools is a short or

medium tooth hard formation bit (IADC codes 2-1, 2-2, 2-3,

2-4, and 3-1). Proper bit size is 92 to 95% of casing drift

diameter. The packers/plugs can be removed with other bit

types but drilling times may be longer. Rotary speeds from 50

to 125 rpm are recommended. Drill collars for weight and

stability are recommended.

To drill packer/plug:

• Tag packer/plug with bit and begin circulation to wash

any loose debris. Circulate at 1/2 to 3 bbl/min.


• Set back on the packer/plug while rotating and slack off

2,000 to 3,000 lb per inch of bit diameter (350 to 510 kg

per centimeter of bit diameter). Less weight can be used

for drilling but drilling times may increase.


is removed.

• After drilling the first 6 to 8 in. (15 to 20 cm), monitor

the cuttings to see if returns are carrying rubber. Monitor

the pressure gauge on the reverse pump to watch for bit

plugging by the rubber. If problems are encountered

drilling the rubber, pick up the workstring 2 ft (.6 m) and

circulate for 1 to 2 minutes. Slow rotations to 10 to 20

rpm, and set weight back on the packer. Continue this

practice every 10 minutes until packer rubbers are fully

drilled (12 to 14 in. [30 to 36 cm]).

• Resume original drilling procedure after drilling

packer rubbers.

Milling With Conventional Equipment

The best mill for milling up Fas Drill tools is a junk-type mill

that tapers inward. The tools can be removed with other mill

types but the possibility of casing damage is greater. Rotary

speeds from 50 to 150 rpm are recommended. Drill collars

for weight and stability are recommended.

To mill packer/plug:

• Tag packer/plug with mill and begin circulation to wash

any loose debris. Circulate at 1/2 to 3 bbl/min.


• Set back on the packer/plug while rotating, and slack off

5,000 to 8,000 lb (225 to 3600 kg). Less weight can be

used for drilling but drilling times may increase.


is removed.


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Mechanical Setting Tool

The Halliburton mechanical setting tool sets and operates all

drillable tools. This setting tool is run on tubing or drillpipe

and is operated by workstring rotation and reciprocation.

The load transfer feature of the tool limits the amount of

string weight that can be applied to the sliding valve. This

feature helps ensure that the packer mandrel is placed in

compression rather than in tension, making the tool more

resistant to breakage.


• Acts as a load transfer device

• Provides positive indication when packer is set

• Allows tubing or drillpipe to be rotated as the tool comes

out of the hole

Operation

The drag blocks/springs contact the well casing to restrict

the rotation of the outer components while the right-hand

rotation of the workstring causes the outer components to

move down and begin the setting motion.

The right-hand rotation unlatches the packer lock ring and

sets the top slips. An upward pull on the workstring

completely sets the packer and releases it from the

setting tool.

Additional right-hand rotation moves the setting tool’s

outer components farther downward to unlock the upper

mandrel from the drag blocks, which moves the setting

tool’s outer components upward. This movement allows the

lower mandrel to extend down far enough to operate the

squeeze packer sliding valve. The disengagement also

causes the setting tool to become freewheeling, so the

workstring can be rotated out of the hole without causing

excessive wear on the setting tool drag blocks/springs.

The setting tool will not cycle again until it has been

redressed with the setting sleeve properly locked in place,

and the keys have been returned to their grooves.


with Load Transfer Device (LTD) Kit


with Fas Drill® SVB Setting Kit

Mechanical Setting Tool –

Drag-Spring Type

HA

L1

20

43

HA

L1

20

58

HA

L1

20

57


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Mechanical Setting Tool—Drag-Spring Type

Tool Sizein. (cm)

Maximum Tool ODDrag-Spring Type

in. (cm)

Overall LengthDrag-Spring Type

in. (cm)

MinimumTool IDin. (cm)

TensileStrength*

lb (kg)

2 7/8(7.30)

2.20(5.59)

42.17(107.11)

0.59(1.50)

36,000(16 329)

3 1/2(8.89)

2.69(6.83)

51.22(130.10)

0.56(1.42)

62,500(28 350)

4 1/2 - 5(11.43 - 12.70)

3.55(9.02)

67.57(171.63)

0.87(2.21)

130,000(58 967)

5 1/2 - 6 5/8(13.97 - 16.83)

4.35(11.05)

37.18(94.44)

1.00(2.54)

130,000(58 967)

7 - 8 5/8 (16.83 - 21.91)

5.53(14.05)

34.17(86.79)

1.13(2.87)

139,000(63 049)

9 5/8 - 13 3/8 (24.45 - 33.97)

7.00(17.78)

38.40(97.54)

1.62(4.12)

316,000(143 337)

16 - 20(40.64 - 50.80)

13.12(33.32)

59.22(150.42)

1.62(4.12)

316,000(143 337)

Note: These are the most common sizes. Other sizes may be available.*The tensile strength value is calculated with new tool conditions. Stress area calculations are used to calculate tensile strength.These ratings are guidelines only. For more information, consult your local Halliburton representative.

Mechanical Setting Tool—Drag-Block Type

Tool Sizein. (cm)

Maximum Tool OD Drag-Block Type

in. (cm)

Minimum Tool IDin. (cm)

Overall LengthDrag-Block Type

in. (cm)

TensileStrength*

lb (kg)

4 1/2 - 6 5/8(11.43 - 16.83)

3.56(9.04)

0.87(2.21)

86.46(219.61)

130,000(58 967.6)

7 - 8 5/8(17.78 - 21.91)

5.65(14.35)

1.13(2.87)

71.30(181.10)

139,000(63 049.34)

9 5/8 - 13 3/8(24.45 - 33.97)

7.00(17.78)

1.62(4.12)

38.40(97.54)

316,000(143 337.6)

Note: These are the most common sizes. Other sizes may be available.*The tensile strength value is calculated with new tool conditions. Stress area calculations are used to calculate tensile strength.These ratings are guidelines only. For more information, consult your local Halliburton representative.


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BP Hydraulic Setting Tool

BP hydraulic setting tools set Halliburton drillable packers

and plugs with workstring pressure. They have no

mechanism for operating tools once they are set. Because

BP hydraulic setting tools use no plugs or balls for

operation, they are ideal for work in horizontal wells.

Design Features

BP hydraulic setting tools can be run on drillpipe, tubing,

or coiled tubing. Two versions of the BP hydraulic setting

tool are available: fill and non-fill.

• Fill-type BP hydraulic setting tools have a hydrostatically

operated fill valve that allows the workstring to fill

during the trip into the hole. This fill valve has shear pins

that are preset at the surface to a predetermined

hydrostatic pressure. Once the fill valve reaches the

preset hydrostatic pressure, the pins shear and the fill

valve closes and locks. The fill valve cannot be opened

after it closes.

• Non-fill BP hydraulic setting tools have no means for

filling the workstring on the trip in, so an auxiliary fill

valve (RTTS® bypass, etc.) or filling from the surface is

necessary. The differential pressure between the wellbore

fluid and dry workstring does not adversely load the

setting mechanism on the trip in.

In both versions, the setting piston is activated by a

predetermined internal pressure applied to the workstring.

This pressure shears the pins holding the setting piston,

moving it down against the plug and setting the top slips.

Additional pressure fully sets the plug or packer and parts

the tension sleeve/pins.

After the plug or packer sets, the workstring is raised 4 to

5 ft (1.22 to 1.52 m). Continued internal pressure to the

workstring causes the setting piston to move down, which

opens the tool to establish circulation. Cement can then be

spotted on top of the plug.

BP Hydraulic Setting Tool(Non-Fill)

HA

L1

20

45

BP Hydraulic Setting Tool(Fill)

HA

L1

20

46


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BP Hydraulic Setting Tool

Tool Sizein. Tool Type Maximum Number

of Pins

4 1/2 - 6 5/8Non-fill

36Fill

6 5/8 - 8 5/8Non-fill

72Fill

9 5/8 - 20Non-fill

72Fill



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HCT Setting Tool

Hydraulic setting tools are used for applications where

pulling forces are needed to set packers or plugs downhole.

For example, these tools can be used to set cast-iron bridge

plugs, Fas Drill® plugs and packers, permanent packers, or

squeeze cement retainers. These setting tools can also be

used for any application where a conventional wireline

setting tool would be used. Since no explosives are necessary,

special training is not required to operate these tools.

Horizontal wells and wells without a rig that already have a

coiled tubing unit (CTU) in place are the most common

applications for hydraulic setting tools.

These setting tools are hydraulically activated when a ball is

dropped into the tool and tubing pressure is applied. They

also have a circulation port that can be uncovered after the

plug is set. This feature allows cement to be pumped down on

top of the plug, which saves another trip in the hole.

The 1.81-in. OD hydraulic setting tool can be run with only

three pulling cylinder assemblies, but the maximum

pulling force is reduced. The total working area will be

2.896 in.², which yields an output force of 13,900 lb

(6305 kg). The 1.81-in. OD assembly has the same profile

as the 1 11/16-in. GO setting tool.

The 3.64-in. OD assembly has the same profile as the

Baker No. 10 setting tool.

The 3.81-in. OD assembly will have the same profile as the

Baker No. 20 setting tool.


• The bottom connections emulate common wireline

setting tools.

• Circulation ports are available to use for spotting cement.

• Setting tools can be run on regular or coiled tubing.

• Hydraulic setting tools require no explosives.

• Tools continue to build pressure in the workstring above

the ball so that the ball-drop sleeve shears open,

establishing circulation through the assembly.

3.81-in. HCT Setting Tool

HA

L1

20

54


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Coiled Tubing Hydraulic Setting Tools

Tool OD in. (cm)

Tool Length in. (cm)

Stroke in. (cm)

Working Areain.² (cm²)

Maximum Forcelb (kg)

Service Rating

Top Connection

Box

Bottom Connection

(Setting Tool)

Maximum Pressure

psi (MPa)e

Tensile Ratinglb (kg)e

1.81(4.60)

93.66a

(237.90)10.0

(25.40)4.062

(26.21)19,497b

(8774)Standard 1.315-in. OD

2.25-lb OECO A 1 11/16-in. GO 10,000(68.95)

17,500(7875)

2.75(6.99)

60.99(154.91)

7.00(17.78)

7.394(47.70)

40,186(18 228) Standard 2 3/8-in.

PAC Box Baker No. 10 13,000(89.60)

51,000(23 133)

3.64(9.25)

33.80(85.85)

6.68 (16.97)

9.91(63.94)

40,135c

(18 061)Standard 2 3/8-in. EU

8 Rd Box Baker No. 10 11,000(75.84)

78,000(35 100)

3.81(9.68)

41.98(106.63)

12.0(30.48)

10.82(69.81)

55,000d

(24 948)Standard 2 7/8-in. EU

8 Rd Baker No. 20 8,400(57.92)

73,000(32 850)

aThis is the maximum length of the tool with four cylinders.bThis calculation is based on a shear pin rating of 4,800 psi.cThis calculation is based on a shear pin rating of 4,050 psi.dThis calculation is based on a shear pin rating of 4,500 psi.eThis is the pressure/tensile rating after the tool is fully stroked.These ratings are guidelines only. For more information, contact your local Halliburton representative.


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Fas-N-EZ™ Hydraulic Setting Tool

The Fas-N-EZ™ hydraulic setting tool has been designed

for setting and squeezing with EZ Drill® SV and SVB and

Fas Drill® SVB squeeze packers during a single trip in the

well. The hydraulic setting tool is operated by tubing

pressure only to set and shear off the packer. The

Fas-N-EZ hydraulic setting tool has a 5-in. OD and a

1.93-in. ID.

The hydraulic setting tool is designed to be run in

conjunction with a 5-in. PR FAS-FIL™ valve to allow the

workstring to fill during the trip in the hole. The fill valve

has shear pins that are preset at the surface to a

predetermined hydrostatic pressure. Once the FAS-FIL

valve reaches the preset hydrostatic pressure, the pins shear

and the fill valve closes and locks. The fill valve cannot be

opened after it closes.

Features

• Designed to set 6 5/8-in. through 20-in. EZ Drill SV and

SVB and 7-in. through 13 3/8-in. Fas Drill SVB squeeze

packers. One tool accommodates all sizes while utilizing

different setting kits for each type and size of packer.

• Workstring manipulation up and down is all that is

required to open and close the valve on the squeeze packer.

• Emergency ball drop seat.

• Centralization available with use of drag springs on the

setting sleeve OD.

• Can be run on jointed pipe or coiled tubing.

• Requires no plugs or balls for operation making it ideal for

work in horizontal wells.

• Designed to operate on workstring pressure only.

• Maximum differential burst pressure rating 12,050 psi.

• Maximum differential collapse pressure rating 11,430 psi.

• Maximum tensile rating, 110,730 lb.

• Maximum temperature rating 400°F.

Fas-N-EZ™ Hydraulic Setting Tool

HA

L1

59

17


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Operational Procedure

To set the EZ Drill® SV and SVB or Fas Drill® SVB squeeze

packer with the Fas-N-EZ™ hydraulic setting tool, the

following procedures are recommended. The FAS-FIL™

valve can be run directly above the setting tool to allow the

tubing or drillpipe to fill while tripping in the hole.

1. Pin the FAS-FIL valve with the correct number of pins

to allow the workstring to fill and close at the

appropriate depth.

2. Make up the FAS-FIL valve to the Fas-N-EZ hydraulic

setting tool on a single joint of pipe.

3. Sting into the packer and make up the coupling to the

tension sleeve in the EZ Drill packer or screw the shear

pins through the coupling ring into the Fas Drill

packer.

4. The setting procedure is activated by a pre-determined

internal pressure applied to the workstring.

5. Additional pressure fully sets the packer and parts the

tension sleeve or pins.

6. Cement squeeze or other applications can now be

performed through the packer.

Setting Kit Sizes

Setting Kit Sizes Tool Types

6 5/8-in. - 8 5/8-in. EZ Drill® SVB

9 5/8 in. - 13 3/8 in. EZ Drill SVB

16 in. - 20 in. EZ Drill SV

7 in. - 7 5/8-in. Fas Drill® SVB

9 5/8-in. - 13 3/8-in. Fas Drill SVB

Fas-N-EZ™HydraulicSetting Tool

Setting Kit

Stinger

HA

L1

59

50


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drillableservicetools - oilfield · pdf file3-4 drillableservicetools drillable service tools...

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