Fishing Tool Manual

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Fishing Tool

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Economics ... 1

Cardinal Rules of Pipe Recovery ... 2

Stuck Pipe – Three Questions ... 3

Manual Stretch calculation ... 5

Field Use Formulas ... 8

Free Point Indicator ... 9

PipeRecovery Log ... 12

Ten Sticking Conditions... 13-21 Back-off w/ Stringshot ... 22-24 Chemical Cutter ... 25-30 Jet Cutter ... 31-35 Bowen Internal Mechanical Cutter ... 36, 106 Owens Split Shot ... 37

Severing Tool ... 38-39 Bottom Hole Junk Shot... 40

Fishing Services

Cardinal Rules of Fishing ... 41

Screw-in Sub……… 42

Fishing High Angle Wells ... 42

Overshot – Series 150... 43-55 Overshot- Series 10 & 20 ... 56-60 Overshot – Series 70... 61-63 Overshot – Series 160... 64

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JARS

Bowen Lubricated Bumper Jar ...72-73 Bowen Non- Lubricated Bumper Jar………...…….74-75

Hydraulic Fishing Jar Release Mechanism……….………...76

Bowen Super Fishing Jar ... 77

Johnston Fishing Jar ... 78

Logan Fishing Jar……….79

Logan Energizer Jar……….79

Bowen Jar Intensifier ... 80-81 Johnston N2 Booster Jar ... 82

Johnston Hydraulic Bumper Jar……….82

Bowen Surface Bumper Jar ... 83-86 Cased Hole Fishing : Recommended Overshot/Wash Pipe/Cutter ... 87

Open Hole Fishing : Recommended Drill Pipe& Drill Collars ... 88-89 Drill Collars – Weight s and I.D ... 90

How many drill collars or HWDP ? ... 91

How long to jar? ... 93

Four Elements of Effective Jarring……….94

Mud Properties for Fishing ... 95

Types of Rotary Shoes ... 96

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Bowen External Cutter ... 101-102 Bowen Hydraulic External Cutter ... 103-104

Houston Engineers External Cutter ... 105

Internal Cutter – Bowen... 106-107 Circulation – can the well be circulated ? ………...109

Packer Milling ... 110-111 What’s new in milling technology? ... 112-114 Casing Failures.……….116-120 Tools for Fishing Junk ... 121-138 Fishing Wireline – Not Parted ( Cut & Strip) ... 140-141 Fishing Parted Wireline ... 143

Telephone List of Fishing & Rental Store Locations ... 144

Alphabetical Listing of Tools Baskets ... Magnets ... 127

ITCO ( Core-Type) Junk Basket ... 131 Overshots Reverse Circulation Junk Basket ... 135 Series 150 ... 44

Rev. Circ.- Full Flow junk Basket ... 137 Series 10 & 20 ... 56

Cutters ... Series 70 ... 61

Bowen Hydraulic External ... 103 Series 160 ... 64

Bowen Mechanical External ... 101 Spears Houston Engineer’s... 105 Bowen Itco Type ... 65

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Jars ... Wireline Fishing

Bowen Lubricated Bumper Jar ... 72 Parted ... 143

Bowen Non- Lubricated Bumper Jar ... 74 Cut & Strip ... 140

Bowen Super Fishing Jar ... 77

Johnston Fishing Jar ... 78

Logan Fishing Jar ... 79

Logan Energizer Jar... 79

Bowen Intensifier Jar ... 80

Johnston N2 Jar Booster ... 82

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Economics – When to quit fishing?



D = ( V + Cs ) ÷ ( Fd + Rd )



D = Maximum days to fish



V = Value of fish



Cs = Cost of sidetrack



Fd = Fishing daily cost



Rd = Rig daily cost

Cost of sidetrack = $ 500,000.00

Value of fish = $ 500,000.00

Fishing daily cost = $ 20,000.00

Rig daily cost = $ 120,000.00

( 500,000 + 500,000)

÷

( 20,000 + 150,000)

(1,000,000)

÷

( 170,000) = 5.9 Days to fish

What this simple formula does is set the rule of time. It does not

address the probability of success or the risk associated with

failure. It is critical to address the probability of success and the

cost of failure in the decision process before starting a fishing job.

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You are stuck! What is next?

There are three questions that I always ask regarding stuck pipe. These

questions are specifically suited to address open hole sticking conditions

but can also used very effectively in cased hole applications. These

questions are as follows:

Stuck Pipe Question # 1

Was the pipe moving when it became stuck?

YES or NO

YES – What direction was the pipe moving?

UP –

Keyseat Sticking, Under Gauge Hole, Differential Sticking

DOWN -

Under Gauge Hole, Differential Sticking

Rotating – ( There is no change in hydraulic properties.) Differential

Sticking

NO -

( There is no change in hydraulic properties.) Differential Sticking

NO –

( with a change in hydraulic properties, reduced flow, higher

pressures or both) Sloughing Hole

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Stuck Pipe Question # 2

Are the hydraulic properties the same or different than

before the pipe became stuck?

YES or NO

Yes –

Differential Sticking, Keyseat Sticking, Mechanical Sticking

No –

Well Bore Geometry – Sloughing Hole, Under Gauge Hole

Stuck Pipe Question # 3

Have you done a manual stretch calculation to estimate

where you are stuck?

Whenever pipe becomes stuck, always calculate the estimated depth at

which the pipe is stuck by measuring the stretch in the stuck pipe at a

given pull over string weight. My favorite formula is as follows:

(2208.5) x (nom. wt. of tube in pounds per foot) = the over pull

necessary to induce 3 ½” of stretch per 1,000’ of free pipe.

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Manual Stretch Calculation

Formula to Calculate Stuck Point

(2208.5) x (Nominal Weight of Tube (lbs/ft)) = the over pull over

string weight necessary to induce 3 ½” of stretch per 1,000 feet of

free pipe.

The stretch calculation listed above comes from the McCullough

Tool Company and is over fifty years old. It includes the tool joint

area. If you have coil tubing, wire line, or flush joint pipe, use 3” of

stretch per 1,000’ of free pipe and it will work very well.

Buoyancy - Do you include or exclude the effect of buoyancy in

the manual stretch calculation?

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Pipe Recovery

Free Point Indicator



_{All free point indicators read stretch, compression, and right hand}

torque.



The new generation of free point indicators also read left hand

torque.



Free point indicators read the actual movement of the pipe body

between the anchors on the Free Point Tool – 30/1,000” Stretch

and 15/1,000” Torque would be an average reading.



Max rating on some but not all free point indicators is up to 475

degrees F and 21,000 PSI pressure.



The patent for the first free point tool was issued February 11,

1941.

Cardinal Rules of Pipe Recovery



Cardinal Rule Number One : Free Point - Pipe is free or stuck.

Always leave free pipe above the stuck point if you intend to fish

this well. One or two joints above the stuck point is recommended.

Always check torque and stretch.

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Free Point Tool - Anchors

A free point tool reads on the average of 30/1000” movement in stretch reading

and 15/1000” movement in torque reading.

Magnet Bow Spring Centralizers Motorized Anchor

Four Types of Anchors are available.

• _{Bow Spring Anchor (Carbide Buttons)}

• Permanent Magnets

• _{Electromagnet}

• Motorized Anchor

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Free Point Tool with Bow Spring Anchor.

20

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Pipe Recovery Log ( also called a Stuck Pipe Log)

_{A pipe recovery log or stuck pipe log is actually a single receiver cement bond log.}

_{A pipe recovery log can be extremely valuable in planning the fishing job because it}

gives us information about the well situation below the stuck point.

_{A pipe recovery log is best suited for open hole use but can be used in cased hole.}

_{Pipe recovery logs do not work well in horizontal wells in the lateral.}

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Ten Sticking Conditions

Approximately sixty years ago the McCullough Tool Company identified the ten sticking conditions that are involved whenever pipe or tools become stuck in a well bore either cased hole or open hole. Whenever pipe or tools become stuck it is critical to identify the problem by addressing what is the sticking condition or conditions that have caused you to become stuck. The ten sticking conditions are listed below.



Differential Sticking



Key Seat Sticking



Blow Out Sticking



Sloughing Hole Sticking



Lost Circulation Sticking



Cemented Sticking



Mechanical Sticking



Under Gauge Hole



Mud Stuck



Sand Sticking

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Differential Sticking

is a major problem in drilling operations worldwide.

Differential Sticking

The most common cause of differential sticking is thick filter cake across a permeable zone.

Preventive Action

Reduce wall contact with B.H.A. using spiral drill collars, H.W.D.P., and stabilizers.

Maintain minimum mud weight.

Daily short wiper trips when hole drag is observed.

Keep drill string moving. Consider rotating drill string while standing back pipe or picking up a stand or single when making a connection.

Spotting Agents

Local knowledge is critical as to what spotting agents work in a geographic area, and what is the average time that a spotting agent needs in order to free the stuck pipe.

If you choose to spot oil, diesel, or Black Magic®, pump enough to cover the B.H.A. and be able to pump ½ barrel every hour while waiting for the pipe to come free.

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Differential Sticking The example shown below calculates to have a sticking

force of 1.2 million pounds.

Differential Sticking - Jarring Recommendation

If drilling jars are in the hole and are working, apply torque and jar down if the bit is not on bottom. If the bit is on bottom jar up. Do not jar down with the bit on bottom.

Jarring option by itself is rarely successful because the hydraulic force sticking the pipe is so strong. Spotting a pipe releasing agent usually works even if jars are also needed to free the pipe.

Inputs:

Drill Collar Diameter

(inches) 6

Stuck Length (inches) 240 Imbedment (inches) 0.125 Hole Size (inches) 7.875 Calculations:

Hole Radius = (b) 3.9375

Drill Collar Radius = (a) 3

Imbedment 0.125

Center Offset = (c) 1.0625

Total Drill Collar Surface

Area: 4524 sq. inches

Contact Area: 817 sq. inches Differential Pressure Inputs:

Mud Weight: 9.3 lb/gal Formation Pressure: 3500 psi Depth: 10300 ft Differential Pressure Calculations:

Hydrostatic Pressure: 4976 psi Note: A negative number denotes

Differential Pressure: 1476 psi higher formation pressure than hydrostatic pressure

Differential Sticking Force Calculations:

Sticking Force: 1,205,795 lbs force into the wall of the wellbore a Angle "A" c b Angle "C" Angle "B" Instructions:

Input well information into YELLOW cells. The RED

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Key Seat Sticking –

A key seat occurs when drill pipe in tension wears a slot (key seat) in the wall of a hole during drilling operations. This happens when a well deviates from true vertical, controlled or not controlled.

Preventive Action

When it becomes evident that a key seat is forming, wipe it out with a key seat wiper or string reamer before it sticks your drill string.

Indication of Key Seat Sticking

Pipe was moving up when it became stuck.

Pipe is usually at an O.D. enlargement or stiffness change in the drill string.

Circulation is not affected in any way.

Pipe may be able to be rotated but not reciprocated.

Recommended Procedure

Surface Jars – DO NOT hit down with surface jars at a setting higher than the weight of the available free pipe or the rebound will stick the pipe tighter.

Back-off – Leave a minimum of two joints of free pipe above the stuck point to insure that the top of the fish will be above the top of the key seat.

Jarring Option – Screw-in with jarring assembly with enough drill collars to effectively jar down.

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Blowout Sticking

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Sloughing Hole Sticking or Lost Circulation Sticking

Sloughing Hole Sticking

– Usually occurs immediately below a cavity. The most common cause is poor filter cake across an unstable zone. A warning sign is hole fill during connections or trips. Indication of sloughing hole is pipe is stuck and hole is packed-off. Circulation is greatly reduced or impossible.

Recommended Procedure – If circulation (although at a reduced rate) is possible, jarring is an option that has merit. If the hole is packed-off, the success rate of jarring is almost nil. Wash-over is the option that will work. Dimensions of B.H.A. and well bore and mud properties will dictate the risk factor of this option.

Lost Circulation Sticking –

Can occur after losing circulation.

Recommended Procedure – If circulation (although at a reduced rate) is possible, jarring is an option that has merit. If the hole is packed-off, the success rate of jarring is almost nil. Wash-over is the option that will work. Dimensions of B.H.A. and well bore and mud properties will dictate the risk factor of this option.

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Cemented Sticking

When pipe is cemented in place, jarring is not an option except on a very short section of pipe.

Recommended Procedure Open Hole-

Cemented in pipe can usually be washed-over if economics will allow it.

Cased Hole –

Wash-over will be a problem in cased hole unless the pipe being washed-over is centralized in the hole (and it almost never is). During wash-over, when the pipe being washed-over is not centralized, a pinch point will be reached where either the wash pipe will simply not make any more progress at all, the wash pipe will become stuck, or the well side-tracked. Selecting a very aggressive mill and milling up pipe may be the best option. If a pilot mill is selected, the pilot must be small enough O.D. to allow the blades to sweep the hole from side to side where the pipe being milled is not centralized.

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Undergauge Hole Sticking

Identity if the undergauge hole is above or below the bit. If a bit

was stuck in undergauge hole while tripping in the hole, jarring up is usually successful. If the undergauge hole occurs above the B.H.A. due to a plastic shale or salt section and circulation (although at a reduced rate) is possible, jarring is an option that has merit. If the hole is packed-off, the success rate of jarring is almost nil.

Wash-over is the option that will work. Dimensions of B.H.A. and well bore and mud properties will dictate the risk factor of this option.

Mechanical Sticking

Mechanical sticking occurs due to junk or a foreign object in the

hole. Circulation is usually nor affected.

Recommended Procedure

Free point and part pipe at appropriate place. Run attachment tool with jarring assembly that will enable you to effectively jar both up and down.

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Sand Stuck Mud Stuck

Sand Sticking or Mud Sticking

The greatest risk is that during pipe recovery while reciprocating the pipe, a pocket will be formed in the sand or mud that will cause the free point tool to show free pipe, but the pipe cannot be pulled. Take the free point reading at a higher pull value than when the pipe was being reciprocated if think Sand Sticking or Mud Sticking is probable.

Recommended Procedure – If circulation (although at a reduced rate) is possible, jarring is an option that has merit. If the hole is packed-off, the success rate of jarring is almost nil.

Wash-over is the option that will work. Dimensions of B.H.A. and well bore and mud properties will dictate the risk factor of this option.

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Pipe Recovery How to part pipe

Preferred method in alphabetical order if fishing is an option.

. Back-off ( with string shot explosive)

. Chemical Cut

. Jet Cut

. Mechanical Cut ( Internal)

. Split Shot®

If side-track is the option, a Severing Tool can be run.

Back-off ( with string shot explosive)

Prior to putting in left hand torque, the pipe to be backed-off should be tightened by putting

in right hand torque by turning the pipe to the right. Do not exceed make-up torque. When you put in the right hand torque, count the rounds, stopping when make-up torque is reached. Reciprocate the pipe which will work the torque down hole to the stuck point. Release the torque slowly counting the rounds that you get back. When you get the same number of rounds back that you put in, the pipe is properly tightened and is ready to put in the left hand torque The rule-of-thumb for how many rounds to the left is as follows;

Drill Pipe - ½ - ¾ Rounds to left per 1,000’ of free pipe Tubing - 1 Round to left per 1,000’ of free pipe

Fire the shot with the string shot rod across the connection to be broken. Checking the break

After the initial break is made to the left, pull the collar locator up hole two connections plus ten feet and stop . Make a note of what depth the second connection is. Finish unscrewing the pipe and pick up the backed-off pipe five feet. The connection below the collar locator should have moved up the hole five feet. Check this with the collar locator. Do not go lower than the break with the wire line tools . Trip out with wire line tools. Trip out of hole with backed-off pipe.

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Prima-Cord

( String Shot) has only one manufacturer – Ensign- Bickford.

Four Types of Prima-Cord

PETN - 225 degrees F for one hour RDX - 350 degrees F for one hour HMX - 400 degrees F for

PYX - 525 degrees F for one hour

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String Shot Back-Off

Advantages of a back-off

. A back-off leaves a connection to screw back together not depending on a rubber pack-off if circulation through the fish is critical as it always is in open hole fishing.

. Can be run through smaller I.D.’s than cutters.

. High mud weights do not adversely effect a string shot back-off.

. Temperature – Prima-Cord is available to handle well bore temperatures up to 525 degrees F for one hour.

. String shot can be run in combination with a free point indicator if the well conditions warrant it.

Five requirements for a successful back-off (

Value Order Listed)

. The connection to be backed-off must be free. . The shot must be fired across the connection.

. The connection being shot must be at neutral weight.

. The correct amount of left hand torque must be applied.

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Chemical Cutter

The chemical cutter is designed to cut a specific weight of tubing without

damaging an adjacent pipe string.

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Chemical Cutter

Advantages of a chemical cutter

.

O.D. and I.D. of fish are unchanged and are suitable to be fished with an overshot or a spear.

. Chemical cutter will NOT damage an adjacent string.

Disadvantages of a chemical cutter

. Heavy mud (above 15 ppg) can be a problem.

. Hold down buttons can punch through corroded tubing.

. Well temperature limitation – 300 degrees F for one hour.

. Wall Thickness – Poor track record in attempting to cut greater than 0.45” wall.

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Sample of typical chemical cut Chemical Cutter

. Cut accomplished with controlled high-pressure dispersion of Bromide Triflouride. . No debris.

. No damage to adjacent pipe.

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Jet Cutter

Advantage of jet cutter

. Short assembly – will go places a chemical cutter will not pass.

. No hold down buttons. Scale or coatings on the I.D. of the pipe to be cut have little effect on the jet cutter.

. Greater size range than the chemical cutter.

Available sizes to cut from 1” CT – 13 3/8” Casing

.

Disadvantage of jet cutter

.

Can damage adjacent string unless cut is made in centralized area.

. Flares the O.D. of the fish requiring it to be dressed off if an overshot is to be run.

Examples of Jet Cutters Cut-Away

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Jet Cutter

Sample Cuts

Super Cutter Segmented Cutter

Note the flaring of the pipe and possible damage to adjacent strings.

Jet Cutter - What’s new? Titan Spectra Cutter

This is a jet cutter that leaves a minimal flare. Testing has shown that it does not damage adjacent strings.

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Titan Spectra ‘Low-Flare’ Jet Cutter

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Mechanical Cutter - Internal

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Owens Oil Tool - Split Shot®

. The Owens Split Shot is a magnetically decentralized explosive that makes ma 12”, 18”, or 24” long split in a linear configuration. When this is across a tubing or casing

collar the pipe above can be pulled if it is free.

. Available Sizes

. .875” to split 1.315” to 2 3/8” Tubing . 1.00” to split 1.315” to 2 3/8” Tubing

. 1.375” to split 2 3/8” to 5” Tubing and Casing . 2.00” to split 2 7/8” to 7” Tubing and Casing . 2.00” to split 3 ½” to 16” Tubing and Casing

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Owens Split Shot®

. A linear shaped charge of relatively small diameter.

. Designed to split a collar or connection with no distortion of the pipe.

Advantages of Owens Split Shot

®

. Can be run in very thick mud.

. Can be run through major I.D. restrictions such as spears without re-heading the wire line.

Disadvantages of Owens Split Shot

®

. If pipe is integral joint not coupled, multiple trips will probably be needed to complete the cut if the Owens Split Shot® is run.

. The split coupling could come out with the upper section of pipe retrieved or stay on the bottom section of pipe left in the hole or fall off on top of the fish while tripping out.

Severing Tool

. The severing tool usually eliminates all fishing options. It should be use when side

track or P&A is the next option.

. Open Hole Use Only

. When attempting to sever pipe not drill collars, fire the severing tool in the tool joint or coupling. When a severing tool is fired in the tube of pipe it usually will balloon and rail spilt the tube but not part the pipe. The severing tool needs the mass of

a drill collar or tool joint in order to work properly.

Picture of a Severing Tool

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Severing Tool

.

Available Sizes - Caution – Open Hole Use Only!

. ¾” to sever Coil Tubing

. 1 3/8” to sever up to 6” O.D. Drill Collar

. 1 ¾” to sever up to 9” O.D. Drill Collar . 2” to sever up to 11” O.D. Drill Collar . 2 5/8” to sever up to 11” O.D. Drill Collar . Sample Cuts

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Bottom Hole Junk Shot



This is actually a large perforating charge pointed downward rather

than to the side.



The nose cone on the charge must actually touch the junk at the bottom

of the hole.



Even though this is a directional charge pointed downward there are

tremendous forces generated to the side. Because of this NEVER RUN

A BOTTOM HOLE JUNK SHOT IN CASED

HOLE.

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Fishing Services

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Standard Fishing Tool String - Jarring B.H.A.

. Attachment Options . Screw-In Sub

. Overshot (outside catch) Series 150, 10, 20, 70 and 160 . Spear (inside catch)

. Screw-In Sub

. The most important purpose of a screw-in sub is provide a connection to back-off,

a safe distance from the jars if the jarring operation did not free the fish.

. In a high angle well, should the screw-in sub be skirted or should it be a slick assembly?

Note the difference in the bore hole (cross-hatched area) in the examples below.

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Fishing High Angle Wells

Hard Formations

70

Fishing High Angle Wells

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.

Screwing into a previously backed-off connection

. Run a slick screw-in assembly the same O.D. as the fish top.

. A skirted screw-in assembly makes the screw-in assembly track at a different level in the high angle hole.

Overshots

–

_{Series 150 Overshot}

–

Series 10 Overshot

–

Series 20 Overshot

–

Series 70 Overshot

–

Series 160 Overshot

Series 150 Overshot with Spiral Grapple

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NOV Bowen Series 150 Overshot

Specifications:Bowen-Series-150-Overshot

Calculated Strengths: All strengths listed are calculated theoretical yield points and are accurate within 20 %.It should be noted ,

however, that all strengths assume a, steady pull and full grapple engagement of a round fish. Anything less than full engagement or

straight pulling will reduce the strength substantially. This includes tong marks or other damage to the bowl surface.

* Type Explanation: FS Full Strength-Engineered to withstand all pulling, torsional, and jarring strain. XFS Extra Full Strength-

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NOV Bowen Series 150 Overshot

Engineered for extreme abuse. SFS Semi Full Strength-Engineered for special hole conditions commensurate with maximum strength. SH Slim Hole- Engineered to withstand heavy pulling loads only. XSH Extra Slim Hole – Engineered for pick up jobs only.

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NOV Bowen Series 150 Overshot

Engineered for extreme abuse. SFS Semi Full Strength-Engineered for special hole conditions commensurate with maximum strength. SH Slim Hole- Engineered to withstand heavy pulling loads only. XSH Extra Slim Hole – Engineered for pick up jobs only.

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NOV Bowen Series 150 Overshot

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NOV Bowen Series 150 Overshot

Engineered for extreme abuse. SFS Semi Full Strength-Engineered for special hole conditions commensurate with maximum strength. SH Slim Hole- Engineered to withstand heavy pulling loads only. XSH Extra Slim Hole – Engineered for pick up jobs only

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NOV Bowen Series 150 Overshot

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NOV Bowen Series 150 Overshot

Engineered for extreme abuse. SFS Semi Full Strength-Engineered for special hole conditions commensurate with maximum strength. SH Slim Hole- Engineered to withstand heavy pulling loads only. XSH Extra Slim Hole – Engineered for pick up jobs only

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Catch Range of Series 150 Overshot



Overshot – Series 150 Not Published



If the fish OD is at the maximum catch of the overshot, there is NO

OVERAGE.

• Spiral Grapple Catch Range

»

1/64” – 1/32” Over

»

1/16” – 1/8” Under

• Basket Grapple Catch Range

»

1/16” – 1/8” Over

»

1/16” – 1/8” Under

Overshot Series 150 – Accessories – Top Sub

The top sub for an overshot is nothing but a crossover sub for the thread form of the bowl

and the thread form of whatever it is attached to. An important thing to remember is that if

the top sub for the overshot has a tool joint connection there will be a reduced I.D.

through that connection as there will be in the jars and the drill collars if they are run.

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Series 150 Overshot – Accessories – Upper Extension

. The I.D. of an upper extension is always less that the maximum catch of the overshot.

. The thread form on the upper end of the overshot bowl is load and torque bearing.

. The thread form on the lower end of the overshot bowl is a fine thread and is not designed to be load or torque bearing.

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Overshot Series 150 – Basket grapple with built-in STOP

If the fish top has an O.D. change from larger on top and

smaller below and is short enough to pass above the grapple inside

the overshot, a STOP must be run or the overshot will not release

.

A grapple with a built in STOP reduces the overshot strength by an

average of 35% because it reduces grapple contact area on the fish.

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Overshot Series 150 – Accessories - Floating Stop Ring

( Does not reduce overshot strength )

A steel ring with the proper I.D. can be put in place of the Type A Packer with

either a basket or spiral grapple and it does not reduce the strength of the bowl as

the grapple with stop built in does.

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Overshot Series 150 – Accessories - Guides

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Overshot Series 10 & 20 Sucker Rod Overshots

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Overshot Series 10 & 20 Sucker Rod Overshots

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Overshot Series 10 - Strength Table

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Overshot Series 10 - Strength Table

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Overshot Series 20 - Strength Table

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Overshot - Series 70 Short Catch

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Overshot - Series 70 Short Catch

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Overshot - Series 70 Short Catch – Strength Table

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run the Side Door Overshot. Listed below are the situations that I recommend NOT to run the Side Door Overshot.

. any radio-active logging tool . any directional drilled hole . any line stuck situation . depths below 3,000’

. wire line with a large O.D. Quick Connect

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Standard Fishing Tool String – Attachment – Spear

NOV Bowen - ITCO Type Spear

This will catch the I.D. of the fish. It either has a solid mandrel

or a very small I.D. through the spear. Very little work can be done through the I.D. of a spear.

The catch range of each grapple is published by NOV Bowen.

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ITCO Type Spear – Catch Range & Strengths

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ITCO Type Spear - Catch Range & Strengths

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ITCO Type Spear - Catch Range & Strengths

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ITCO Type Spear - Catch Range & Strengths

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NOV Bowen Full Circle Spear

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NOV Bowen Full Circle Spear

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NOV Bowen – Lubricated Bumper Jar

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NOV Bowen – Non-Lubricated Bumper Jar

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NOV Bowen – Non-Lubricated Bumper Jar

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Hydraulic Fishing Jars

Bowen developed the first hydraulic fishing jar in 1950. It was the Bowen Type Z . Below is a drawing of the Bowen style timing device which is used in the dual action

hydraulic fishing jar. When the jar releases, the hammer hits the anvil and a stress wave heads to the surface traveling at the speed of sound. All of the energy released by the jar is produced by the pipe above the jar.

Jar is in cocked position. Jar has released.

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NOV Bowen – Hydraulic Fishing Jar – Super Jar®

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Key Energy Hydraulic Fishing Jars - Johnston®

Johnson Fishing Jars

TR, DC and FB Jar Specifications and Strength Data OD (in.) ID (in.) STD. Conn. STD. Conn. Maximum Rec. Jarring Pull Maximum Jarring Pull at Yield (lb.) Maximum Pull (lbs.) Maximum Torque (ft-lb.) 1-13/16 3/8 1-13/16 Wilson 20,000 30,000 100,000 2-1/4 1/2 1-1/4 REG 33,500 50,000 135,000 3-1/16 1 2-3/8 REG 40,000 45,000 160,000 3-1/16 1- 1/2 2-3/8 EUE 30,000 40,000 108,000 3-1/8 1-1/2 2-7/8 PAC 36,000 48,000 184,000 3-5/8 1-15/16 2-3/8 EUE 33,000 52,000 232,000 4-1/2 2-3/8 2-7/8 EUE 54,000 83,800 318,000 3-3/4 1/1/2 2-3/8 IF 55,000 78,000 186,000 4-1/8 1-1/2 2-7/8 IF 70,000 107,000 331,000 4-1/8 1-1/2 2-7/8 IF 70,000 107,000 331,000 4-1/8 2 2-7/8 IF 45,500 70,000 320,000 4-3/4 1 7/8 3-1/2 FH 80,000 125,000 379,000 4-3/4 1-7/8 3-1/2 IF 80,000 125,000 379,000 4-3/4 2 3-1/2 IF 67,000 103,000 364,000 4-3/4 2-1/4 3-1/2 IF 95,000 110,000 340,000 5-3/4 2 4-1/2 FH 131,000 219,000 651,000 5-3/4 2 4-1/2 FH 131,000 219,000 651,000 6-1/4 2 4-1/2 IF 190,000 292,000 726,000 6-1/4 2 4-1/2 IF 190,000 292,000 726,000 6-3/4 2-1/2 5-1/2 4-1/2 REG - IF 190,000 292,000 975,000 89,500 6-3/4 2-1/2 5-1/2 4-1/2 REG - IF 190,000 292,000 975,000 89,500 7-3/4 3 6-5/8 REG 208,000 317,000 1,390,000 7-3/4 3 6-5/8 REG 208,000 317,000 1,390,000 1,200 2,200 7,600 2,700 4,000 8,350 17,750 12,580 15,900 15,900 14,000 29,200 29,200 20,000 12,000 34,200 34,200 57.300 57,300 136,000 136,000

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NOV Bowen Fishing Jars – Jar Intensifier®

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NOV Bowen Surface Bumper Jar®

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NOV Bowen Surface Bumper Jar®

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NOV Bowen Surface Bumper Jar®

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Weights of 30’ – 0” Drill Collars

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Drill Collars or H.W.D.P. ?

Whenever you run jars it is prudent to run weight material. The weight material can be

H.W.D.P. or drill collars. What the jar manufacturer is looking for is weight to include in the equation that calculates impact and impulse. If you run H.W.D.P. instead of drill collars it is a two for one exchange. In other words you would need to run twice as many joints of equivalent sized H.W.D.P. as you would run drill collars to approximate the same available weight.

How many drill collars?

Rule of Thumb for Selecting Number of Drill Collars to Run.

_{Match the O.D. of your drill collars and jars and that number will be the}

minimum number to run. The maximum will be the minimum multiplied by two.

 Example: 6 1/4” Jars and 6” DC

_{Min = 6 Max = 12}

_{H.W.D.P. is a two for one exchange}

_{Example: 3 ¾” Jars and 3 ½” DC}

_{Min = 4 Max = 8}

Another way of looking at the rule of thumb is one drill collar for each O.D. inch of the jars that are being run for the minimum. The maximum would be two drill collars per O.D. inch of the jars being run.

This Rule of Thumb should only be used when the jars are placed two joints or less from the stuck point. If you are outside of this two joint window you need to run a jar placement program in order to know how many drill collars to run.

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Fishing Jar Program – NOV Bowen

Jar Placement - Two joints or less from the stuck point if appropriate to well

bore conditions and casing seats. The rule of thumb for how far to back-off pipe

from a casing seat in open hole is a minimum of 100’.

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Jarring Operations

How long are you going to jar assuming there is no

movement either up or down ?



_{Chevron data based their jarring operations world wide. Their}

conclusion based on the data base was with no progress in moving

the fish up or down the maximum time to jar is 4 – 5 hours.



What I wish Chevron would have done would be to separate cased

from open hole and in my opinion maximum time to jar would be:



Cased Hole – (Mechanically stuck major portion of time.) Jarring

time - 2-3 Hours



Open Hole – ( Many different sticking mechanisms .) Jarring time

10 – 12 Hours



The key words in the data base from Chevron are ‘NO

MOVEMENT’. If you are moving the fish at all either up or down,

be patient, keep doing what is working and you can almost always

work the fish out of the hole.

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Four Elements of Effective Jarring

In any jarring operation make sure you have met each of the four elements listed

below or you are not efficiently jarring UP on the fish.

1. Restricted Pull

a. You must be stuck.

b. Restricted pull device ( Oil Jar )

2. Multiplier ( Drill Collars or H.W.D.P. )

If you do not run drill collars or H.W.D.P. ,the multiplier is less than one.

3. Transition Area

a. The change in mass from drill collars/HWDP to pipe is an acceptable transition

area. NOV Bowen calls this a reflective area.

b. A Jar Accelerator®/Booster®/Energizer®/Intensifier® is the most effective and

efficient transition or reflective area.

4. Stored Energy

a. Jarring work-string

b. Jar Booster® / Energizer® / Intensifier®

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Wash Over Shoe Design



A shoe must cut clearance in order keep from getting stuck and get the

mill cuttings to the surface.



CASED HOLE SHOE – SMOOTH O.D. TO PROTECT CASING I.D. –

Cuts clearance on the I.D. by turning down the O.D. of the fish.



_{OPEN HOLE SHOE – ROUGH O.D. ( Can be rough or smooth I.D. )}

Usually smooth I.D. to protect the dimensions of the fish being washed over.

Wash Pipe String Design

The most common wash pipe connection is Hydril WP® . It has two torque shoulders on the bottom of the pin and the top of the box. This connection averages about a 50% connection efficiency which means the connection is 50% as strong as the tube as far as pull force is concerned. Each size of WP connection has a published torsional yield for maximum torque. This wash pipe connection is flush joint. It has no reduction in I.D. or increase in O.D.

Another wash pipe connection that is in use today is the Hydril 511 Series® . It has a hook thread that makes it a superior connection when operating in a curve that applies side-load when the pipe is rotated. The down side of this connection is that there is a slight reduction through the I.D. of the pin.

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Wash Over Operation

How much wash pipe can you run?

. Cased Hole –

You will reach the economic limit of how much wash pipe

to run in most cases before you reach the practical limit.

. Open Hole –

You must come up with a plan that enables you to fish the well

in a time frame that is economic. If it is necessary to run more wash pipe than

seems prudent for you well configuration, then you may want to go to side-track

without ever starting the wash over operation.

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NOV Bowen - External Cutters

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NOV Bowen - Hydraulic External Cutter

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NOV Bowen - Hydraulic External Cutter

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HE - DH Cutter

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NOV Bowen Internal Cutter

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NOV Bowen Internal Cutter

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Can the well be circulated?

Option 1 : Slow the pump down to ½ BPM during the milling process.

Option 2: Dry Drill – Pump 3 barrels to start the milling, dry drill for 15

minutes, then pump another 3 barrels.

Option 3: Spot a pill, sand or calcium carbonate across the perfs before the

production tubing is cut.

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Packer Milling – Permanent Packers – Shoe Dimensions



_{Rule Number One: Shoe O.D. = Bit Size}



Rule Number Two: Shoe I.D. – Packer MUST be O.D. fishable with an

overshot after mill over is completed.



_{Rule Number Three: In high angle wells, shoe I.D. MUST be the same as}

packer mandrel O.D.

Packer Milling – Permanent Packers – Milling Shoe Design



_{Flat Bottom or Wavy Bottom ? Both will do the job.}

Packer Milling – Permanent Packers – Optimum R.P.M.



Optimum R.P.M. for shoe or mill : 1500 ÷ 3.1416 ÷ O.D. of shoe or mill in

inches



Example : 1500 ÷ 3.1416 ÷ 6 = 80 RPM



If you are running an inserted shoe or mill the recommended RPM would be

1.5 to 2 times as fast as the conventional crushed carbide milling tool.

Packer Milling – Permanent Packers – Weight on Shoe



Maximum Weight on shoe or mill :



_{Crushed Carbide = 250 pounds per square inch}



_{Carbide Inserts = 500 pounds per square inch}

On anything other than a whipstock operation, mill by torque if possible. If

whatever you are milling is spinning you apply weight to slow or stop the

movement of the fish. Additional weight is applied as necessary until milling

progress is made. The last resort is shutting the pump down and dry drilling in

order to stop the fish from spinning.

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Packer Milling – Permanent Packers – Retrievers

( Baker “ CJ ”®, Bowen Simplex®, H.E.-PRT® )

Bowen Simplex

‘JB’ Packer Retrieving Tool

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What’s new in milling technology?

Inserted Mill Crushed Carbide Mill

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What’s new in milling technology?

Mike Henson Bits – San Angelo, TX

www.mhbits.com

Bear Claw Cutting Structure Chomps cutting Structure

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What’s new in milling technology?

Mike Henson Bits – San Angelo, TX

www.mhbits.com

Hurricane Style bit with Chomps Cutting Structure

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Fishing for Coil Tubing

 Sucker Rod fishing tools were the only tools available until the last five years.

The conventional fishing tools such as Series 10 and Series 150 Overshots do not work very well with coil tubing because the coil tubing is oval not perfectly round.

_{Fishing tools engineered specifically to fish coil tubing are now available. A list of some}

of the attachment tools available are listed below;

 Hydraulic Overshots

_{Hydraulic Spears}

_{Continuous Overshots}

_{Continuous Sniper Overshots}

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Casing Failures



Whenever you have a casing failure it is critical to identify the cause of the failure.

_{Tools available to diagnose type of casing failure}

_{Impression Block – An impression block can be extremely helpful in}

diagnosing what type of casing failure has occurred in you well.

_{Video Camera – If well conditions will allow for a camera run it will also}

be extremely valuable in diagnosing the type of casing failure has occurred in you well.

_{Casing Inspection Log – There are a number of casing inspection logs}

available that will provide very definitive information as to the condition of the casing in your well.

_{Four Categories of Casing Failure}

 Earth Shift  Corrosion _Erosion _Hydraulic

_{Fishing Tools Available}

 Casing Swage Mandrel

 NOV Bowen Casing Roller

_{External Casing Patch}

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Casing Swage Mandrel

. Run on pipe with jars and drill collars.

.

Start with a swage mandrel 1/8” larger than the collapse and increase swage mandrel size in 1/8”-1/4” increments until the maximum size (drift ) is run. . Run the NOV Bowen Casing Roller to remove the memory from the steel.