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Page 1: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

Weatherford Fishing Best PracticesTraining

COURSE MANUAL

February, 2001

Revision NW

Page 2: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

Notices

All information contained in this publication is confidential and the proprietary property ofWeatherford, Inc. Any reproduction or use of these instructions, drawings, or photographswithout the express written permission of an officer of Weatherford, Inc. is forbidden.

© Copyright 2001 Weatherford, Inc.

All Rights Reserved.

Printed in the United States of America

The drawings in this manual were the most recent revisions and the best quality available at thetime this manual was printed. We recommend that you check your manual for individual drawingclarity and revision level. Should you have equipment with revisions later than the drawings in thismanual, or should you require higher quality drawings than the drawings in this manual, orderreplacements from the Engineering Print Room in Houston.

Page 3: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

Weatherford, Inc.

Technical Communications - Houston Weatherford Fishing Best Practices Training

11909 Spencer Road (FM529) Course Manual

Houston, Texas 77041-3011

READER'S COMMENTS

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Page 4: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

Revisions

Fishing Best Practices Training - NW 02/01 Revision Record

Revision Record

Weatherford Fishing Best Practices Training

Course Manual

Date Revision Description

10/2000 NW Initial release (NW).

Page 5: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

2001 Weatherford. All Rights Reserved

October 18, 2000 Page i-i

Fishing Best Practices Manual

Introduction

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

Page 6: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

Contents at a Glance

Introduction

Job Planning and Record Keeping

Fishing for Junk

Pipe Recovery Methods

Open Hole Fishing

MUD

Fishing in Cavities

Fishing for Parted Pipe

Jarring Operations

Fishing in Lateral Wells

Cased Hole Fishing

Casing Repair

Fishing for Wireline

Reversing Tool

Trip Saver Bushing

Multi-String Cutting

M.O.S.T. Tool

W.O.B.O. Tool

Drill Collar Spear

Underwater Casing Patch

Section 1

Section 2

Section 3

Section 4

Section 5

Section 6

Section 7

Section 8

Section 9

Section 10

Section 11

Section 12

Section 13

Section 14

Section 15

Section 16

Section 17

Section 18

Section 19

Page i-ii 2001 Weatherford. All Rights Reserved. October 18, 2000

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2001 Weatherford. All Rights Reserved.

October 18, 2000 Page i-iii

Table of ContentsIntroduction .........................................................................................................................i-i

Table of Contents ............................................................................................................... i-iii

List of Figures .....................................................................................................................i-x

List of Tables .................................................................................................................... i-xv

Introduction..................................................................................................................... i-xvii

Job Planning and Record Keeping ................................................................................1-1

Introduction........................................................................................................................1-3

Cardinal Rules of Fishing.................................................................................................1-5

Rule 1 – Obtain the Important Details or Ask the Important Questions ...........................1-5

Rule 2 – Know all the Do’s and Don’ts ........................................................................1-5

Rule 3 – Determine the Dimensions .............................................................................1-6

Rule 4 – Maintain An Accurate Top of Fish Location....................................................1-6

Arriving on Location .......................................................................................................1-7

In and Out Method..........................................................................................................1-8

Kelly Bushing (KB) Measurements..................................................................................1-9

Tally Book....................................................................................................................1-10

Tally Book Abbreviations ..............................................................................................1-11

Leaving the Job Site Upon Job Completion .....................................................................1-14

Review ........................................................................................................................1-14

Notes:..........................................................................................................................1-15

Fishing for Junk ................................................................................................................2-1

Introduction........................................................................................................................2-5

Junk or Debris Evaluation................................................................................................2-7

Fishing Magnets..............................................................................................................2-7

Procedure run Magnet.................................................................................................2-8

Globe Type Junk Baskets ..............................................................................................2-10

Example Procedure...................................................................................................2-10

Reverse Circulating Junk Basket....................................................................................2-13

Bowen Full Flow Reverse Circulating Basket .................................................................2-14

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2001 Weatherford. All Rights Reserved.

Page i-iv October 18, 2000

Example Procedure...................................................................................................2-14

Cone Dimensions ..........................................................................................................2-16

Junk Shot .....................................................................................................................2-17

Poor Boy Basket ..........................................................................................................2-17

Recommended Fishing Tool Usage ................................................................................2-18

Mills.............................................................................................................................2-19

Milling Rates in Surface Feet Per Minute (SFPM) ..........................................................2-20

Cone Buster Mills .........................................................................................................2-20

Cement Mills ................................................................................................................2-21

Notes:..............................................................................................................................2-23

Pipe Recovery Methods ..................................................................................................3-1

Introduction........................................................................................................................3-5

Formulas ........................................................................................................................3-6

Stretch Formula ..........................................................................................................3-6

Tapered String ............................................................................................................3-7

Blind Backoff ...............................................................................................................3-10

Free Point Indicator...................................................................................................3-10

Pipe Recovery Log ...................................................................................................3-11

String Shot Backoff.......................................................................................................3-12

Where to Backoff? ...................................................................................................3-12

Pup Joints.....................................................................................................................3-13

Chemical Cutter............................................................................................................3-13

Jet Cutters....................................................................................................................3-15

Super Jet Cutter............................................................................................................3-16

Shaped Charges............................................................................................................3-17

Severing Tool ...............................................................................................................3-18

Internal Mechanical Cutter ........................................................................................3-19

Operating Procedures For Internal Cutters ..............................................................3-20

Notes:..............................................................................................................................3-21

Open Hole Fishing............................................................................................................4-1

Introduction........................................................................................................................4-5

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2001 Weatherford. All Rights Reserved.

October 18, 2000 Page i-v

Stuck Pipe Conditions .......................................................................................................4-10

Running Wash-pipe .......................................................................................................4-10

Shoe Selection ..........................................................................................................4-14

Differential Sticking ......................................................................................................4-17

Differential Sticking Force .........................................................................................4-19

Sticking Prevention....................................................................................................4-21

Key Seat Sticking .........................................................................................................4-21

Key Seat Sticking .........................................................................................................4-22

Bowen Surface Jars..................................................................................................4-24

Sloughing Shale or Hole Cave – In.................................................................................4-25

Signs that the hole is still sloughing..............................................................................4-25

Solution.................................................................................................................4-26

Blowout Sticking.......................................................................................................4-26

Under Gauge Hole Sticking........................................................................................4-27

Lost Circulation Sticking............................................................................................4-27

Mechanical Sticking ..................................................................................................4-28

Other Fishing Options ................................................................................................4-28

Economics of Fishing ....................................................................................................4-31

Actual Job Example ...............................................................................................4-32

Before Leaving the Well Site .....................................................................................4-32

Notes:..............................................................................................................................4-33

Drilling Fluids ....................................................................................................................5-1

Introduction........................................................................................................................5-5

Common Formation Problems..........................................................................................5-8

Reactive Formations....................................................................................................5-8

Unconsolidated Formations ..........................................................................................5-9

Over-Pressured Shale Collapse..................................................................................5-10

Mud Properties.............................................................................................................5-10

Mud Weight..............................................................................................................5-11

Shale Control Inhibitors..............................................................................................5-11

Filtrate Reducers.......................................................................................................5-12

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2001 Weatherford. All Rights Reserved.

Page i-vi October 18, 2000

Annular Flow/Mud Viscosity......................................................................................5-13

Advantages of Laminar Flow.....................................................................................5-13

Cuttings Removal......................................................................................................5-14

Slip Velocity of Cuttings in Ft/Sec. .............................................................................5-14

Vertical and Highly Deviated Wells................................................................................5-14

Mud Pills ......................................................................................................................5-15

Circulating Time Prior to Tripping ..................................................................................5-15

Mud Cycling Time.....................................................................................................5-16

Volume of Mud in System.........................................................................................5-16

Capacity of Hole .......................................................................................................5-16

Miscellaneous Formulas.............................................................................................5-17

Rotation and Reciprocation............................................................................................5-17

Parameters...............................................................................................................5-18

Desired Annular Velocity Formula .............................................................................5-19

Annular Volume........................................................................................................5-19

Annular Velocity in Ft./Min........................................................................................5-20

Triplex......................................................................................................................5-20

Displacement............................................................................................................5-21

Filter Cake................................................................................................................5-21

Hydrostatic Pressure.................................................................................................5-21

Buoyancy Factor.......................................................................................................5-22

Mud For Fishing Operations...........................................................................................5-23

Notes:..............................................................................................................................5-24

Fishing in Cavities............................................................................................................6-1

Introduction........................................................................................................................6-3

Getting Washpipe Over a Fish .........................................................................................6-3

Feeler Pins ..............................................................................................................6-4

Trahan Bushing...........................................................................................................6-5

Other Methods To Use ...................................................................................................6-6

Mule Shoe ..................................................................................................................6-7

Wall Hook..................................................................................................................6-9

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2001 Weatherford. All Rights Reserved.

October 18, 2000 Page i-vii

Kick Sub ....................................................................................................................6-9

Knuckle Joint............................................................................................................6-10

Consequences...........................................................................................................6-12

First Bad decision: .................................................................................................6-12

Second Bad decision:.............................................................................................6-12

Third Bad decision:................................................................................................6-12

Fourth Bad decision: ..............................................................................................6-12

Conclusion ............................................................................................................6-12

Overruled by Company Man......................................................................................6-12

Notes:..............................................................................................................................6-13

Fishing for Parted Pipe ....................................................................................................7-1

Introduction........................................................................................................................7-5

Bottom Hole Assembly Options .......................................................................................7-7

Attachment Tool Rating System...................................................................................7-8

Screw In Sub..................................................................................................................7-9

Overshot ......................................................................................................................7-10

What Overshot do I Need?............................................................................................7-11

Series 150 Oververshot Tightening Torques ................................................................7-21

Mill Extensions..........................................................................................................7-22

Overshot in an Open Hole - Run Procedure....................................................................7-24

Releasing Overshots .....................................................................................................7-25

The Oversocket Fishing Tool.........................................................................................7-27

Clulow Socket Overshot................................................................................................7-29

Releasing Spears ..........................................................................................................7-29

Bowen Full Circle Releasing Spear.............................................................................7-31

Houston Engineers Releasing Spear ...........................................................................7-31

H.E. Releasing Spear Accessories..........................................................................7-32

Box Tap and Taper Tap................................................................................................7-40

Pin Taps and Hollow Pin Taps .......................................................................................7-42

Notes:..............................................................................................................................7-44

Jarring Operations............................................................................................................8-1

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2001 Weatherford. All Rights Reserved.

Page i-viii October 18, 2000

Introduction........................................................................................................................8-3

Bumper Jars (Mechanical and Lubricated) ...........................................................................8-3

Bumper Sub Operation....................................................................................................8-4

Hydraulic Up Stoke Jars .....................................................................................................8-4

Hydraulic Up Jar Operation.............................................................................................8-5

Mechanical Up Jar Operation..............................................................................................8-6

Accelerator Jars.................................................................................................................8-6

Hydro-Mechanical Dual Acting Jars ....................................................................................8-7

Additional Jarring Procedures..............................................................................................8-8

Jar Failure..........................................................................................................................8-9

Pump Open Force...........................................................................................................8-9

Notes:..............................................................................................................................8-10

Fishing in Lateral Wells....................................................................................................9-1

Introduction........................................................................................................................9-3

Jars................................................................................................................................9-3

Tips on Torque Setting ....................................................................................................9-4

Example Job............................................................................................................9-5

Notes:................................................................................................................................9-8

Cased Hole Fishing ........................................................................................................10-1

Introduction......................................................................................................................10-5

Mud Stuck Tubing ............................................................................................................10-7

Sand Sticking....................................................................................................................10-8

Mechanical Sticking - Stuck Packer...................................................................................10-9

Bowen External Cutter ................................................................................................... 10-12

Running-In Precautions ............................................................................................... 10-16

Bowen Hydraulic External Cutters............................................................................... 10-24

Bowen Internal Cutter .................................................................................................... 10-30

Bowen Collar Finder....................................................................................................... 10-34

Weatherford Pressure Cutter .......................................................................................... 10-34

Retrieving Spears and Mills ............................................................................................. 10-35

Weatherford J-B Bushing............................................................................................ 10-36

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2001 Weatherford. All Rights Reserved.

October 18, 2000 Page i-ix

Assembly ............................................................................................................... 10-36

Running Procedure.................................................................................................. 10-36

Releasing Instructions.............................................................................................. 10-37

Parameters and Observations .......................................................................................... 10-40

Milling Rates .............................................................................................................. 10-40

Rotary Shoes .......................................................................................................... 10-40

Packers...................................................................................................................... 10-42

Weatherford Washover Type Packer Milling Assembly .................................................... 10-46

Mechanical Sticking........................................................................................................ 10-53

Exercise..................................................................................................................... 10-57

Procedure One ....................................................................................................... 10-58

Procedure Two....................................................................................................... 10-59

Procedure Three..................................................................................................... 10-60

Procedure Four ....................................................................................................... 10-61

Procedure Five ....................................................................................................... 10-61

Notes:............................................................................................................................ 10-63

Casing Repair..................................................................................................................11-1

Introduction ..................................................................................................................11-3

Casing Failure...............................................................................................................11-4

Downhole Video...........................................................................................................11-4

Casing Swage...............................................................................................................11-6

Casing Roller................................................................................................................11-7

Mills.............................................................................................................................11-8

Lace Joint ....................................................................................................................11-8

Casing Repair Tool ..................................................................................................... 11-11

Upper String Replacement........................................................................................... 11-11

Internal Cutters........................................................................................................... 11-12

Weatherford Internal Casing Patch.............................................................................. 11-14

Notes:............................................................................................................................ 11-21

Fishing for Wireline ........................................................................................................12-1

Introduction ..................................................................................................................12-3

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2001 Weatherford. All Rights Reserved.

Page i-x October 18, 2000

Problems and Precautions .............................................................................................12-6

Run in Procedures ........................................................................................................12-7

Proof of Overshot Engagement......................................................................................12-7

Side Door Overshot Procedures................................................................................... 12-11

Fishing for Parted Wireline .......................................................................................... 12-12

Center Prong Rope Spear........................................................................................ 12-12

Double Prong Spear ................................................................................................ 12-13

Crankshaft Spear .................................................................................................... 12-13

Notes:............................................................................................................................ 12-22

List of FiguresFigure 1-1: Fishing Job Planning Flow Chart...............................................................................1-4

Figure 1-2: In and Out Method Example ....................................................................................1-8

Figure 1-3: Top of Fish Calculation Example ..............................................................................1-9

Figure 1-4: Weatherford Fishing & Cutting Service Report .......................................................1-13

Figure 2-1: Junk Fishing Job Flow Chart ....................................................................................2-6

Figure 2-2: Fishing Magnet with a Cripple Type Guide Attached .................................................2-8

Figure 2-3: Boot Basket............................................................................................................2-9

Figure 2-4: Globe and Boot Baskets ........................................................................................2-11

Figure 2-5: Standard Catcher Baskets .....................................................................................2-11

Figure 2-6: Bowen Itco Type Junk Basket...............................................................................2-13

Figure 2-7: Bowen Full Flow Reverse Circulation Junk Basket..................................................2-15

Figure 2-8: Rock Bit Cone Dimensions Example From Bowen Instruction Manual......................2-16

Figure 2-9: Finger Shoe, Poor Boy Basket, and Poor Boy Basket in Borehole ............................2-17

Figure 2-10: Cone-Buster Mills ...............................................................................................2-21

Figure 2-11: Cement Mills.......................................................................................................2-22

Figure 3-1: Pipe Separation Methods .........................................................................................3-5

Figure 3-2: Excel Spreadsheet for Free Point in Stuck Drill Pipe..................................................3-9

Figure 3-3: Pipe Sticking While Free Pointing...........................................................................3-11

Figure 3-4: Shot String Example ..............................................................................................3-12

Figure 3-5: Chemical Cutter and Severed Pipe .........................................................................3-14

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2001 Weatherford. All Rights Reserved.

October 18, 2000 Page i-xi

Figure 3-6: Examples of Chemically Cut Pipe...........................................................................3-14

Figure 3-7: Jet Cutter .............................................................................................................3-15

Figure 3-8: Results of Super Jet Cutting on Tubing ...................................................................3-16

Figure 3-9: Severing Tool and Pipe After Severing Tool Used on It ...........................................3-18

Figure 3-10: Mechanical Internal Cutter...................................................................................3-19

Figure 4-1: Determine the Operation at Time of Sticking.............................................................4-5

Figure 4-2: Rotating Operation Flow Chart.................................................................................4-6

Figure 4-3: Trip In Hole (TIH) Operation...................................................................................4-7

Figure 4-4: Tripping Out Of the Hole (or POOH) Operation .......................................................4-8

Figure 4-5: Static Flow Chart ....................................................................................................4-9

Figure 4-6: Washpipe Diameter Illustration ..............................................................................4-11

Figure 4-7: Kick Pad Welded on Shoe .....................................................................................4-13

Figure 4-8: Wash-over Assembly (with safety joint) .................................................................4-14

Figure 4-9: Example Rotary Shoe Designs From the Same Job..................................................4-15

Figure 4-10: Example of Differential Sticking ...........................................................................4-18

Figure 4-11: Differential Sticking Force Spread Sheet (Microsoft Excel).................................4-20

Figure 4-12: Single and Double Clutch Keyseat Wipers ............................................................4-23

Figure 4-13: Mechanical Sticking Examples .............................................................................4-28

Figure 5-1: Drilling Mud Report.................................................................................................5-7

Figure 5-2: Effect of Mud Weight on Drilling Rate ...................................................................5-12

Figure 5-3: Overburden Pressure ............................................................................................5-13

Figure 5-4: BHA Drag in Lateral Cuttings beds........................................................................5-15

Figure 6-1: Getting Over Fish with Wash Pipe............................................................................6-4

Figure 6-2: Getting Side Tracked...............................................................................................6-4

Figure 6-3: Trahan Bushing.......................................................................................................6-5

Figure 6-4: Shorten the Washpipe to Get Over the Fish...............................................................6-6

Figure 6-5: Cripple Shoe Engagement........................................................................................6-7

Figure 6-6: Re-Top Fish with Spear...........................................................................................6-7

Figure 6-7: Bent Joint and Mule Shoe ........................................................................................6-8

Figure 6-8: Kick Sub ................................................................................................................6-9

Figure 6-9: Re-Top Fish with Kick Sub......................................................................................6-9

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2001 Weatherford. All Rights Reserved.

Page i-xii October 18, 2000

Figure 6-10: Knuckle Joint ......................................................................................................6-11

Figure 7-1: Twisted Off Pipe ....................................................................................................7-5

Figure 7-2: Fishing for Parted Pipe Flow Diagram......................................................................7-6

Figure 7-3: BHA Options..........................................................................................................7-7

Figure 7-4: Overshot-150 Grapple and Basket assemblies .........................................................7-12

Figure 7-5: Overshot 150 shown with Spiral and Basket Grapple Assemblies .............................7-14

Figure 7-6: Catch Pin .............................................................................................................7-16

Figure 7-7: Grapple Wickers Biting the Fish.............................................................................7-17

Figure 7-8: Oversocket Fishing Sequence ................................................................................7-28

Figure 7-9: Spear with stop and Pack-off.................................................................................7-32

Figure 7-10: Releasing Spear Accessories ...............................................................................7-33

Figure 7-11: Releasing Spear Examples ...................................................................................7-34

Figure 7-12: Itco Type Bowen Releasing Spear and Catching Range Table – Sheet 1.................7-36

Figure 7-13: Itco Type Bowen Releasing Spear and Catching Range Table – Sheet 2.................7-37

Figure 7-14: Itco Type Bowen Releasing Spear and Catching Range Table – Sheet 3.................7-38

Figure 7-15: Itco Type Bowen Releasing Spear and Catching Range Table – Sheet 4.................7-39

Figure 7-16: Box and Taper Tap BHAs...................................................................................7-40

Figure 8-1: Hydraulic Jar Operation, 1 of 2 ................................................................................8-5

Figure 8-2: Hydraulic Jar Operation, 2 of 2 ................................................................................8-5

Figure 9-1: Avoid pulling pipe into the wall/ free point with torque................................................9-5

Figure 10-1: Cased Hole Fishing Decision Chart.......................................................................10-6

Figure 10-2: External Tubing Cutter....................................................................................... 10-11

Figure 10-3: Slip Assembly, exploded view............................................................................. 10-13

Figure 10-4: Cutter, exploded view........................................................................................ 10-15

Figure 10-5: Bowen External Cutter Assemblies .................................................................... 10-17

Figure 10-6: Bowen Mechanical Cutters Specifications and Replacement Parts (page-1) .......... 10-18

Figure 10-7: Bowen Mechanical Cutters Specifications and Replacement Parts (page-2) .......... 10-19

Figure 10-8: Bowen Mechanical Cutter Exploded View.......................................................... 10-22

Figure 10-9: Mechanical Cutter Slip Assembly, Exploded View............................................... 10-23

Figure 10-10: Bowen Hydraulic External Cutter Assembly...................................................... 10-25

Figure 10-11: Bowen External Hydraulic Cutter Parts ............................................................ 10-26

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2001 Weatherford. All Rights Reserved.

October 18, 2000 Page i-xiii

Figure 10-12: Maximum Length and Load of Tubing and Drill Pipe Picked Up with Knives, Pressureand GPM to Make Cut.................................................................................................... 10-27

Figure 10-13: Bown Hydraulic External Cutters ..................................................................... 10-28

Figure 10-14: Bowen Hydraulic Cutters Specifications and Replacement Parts ........................ 10-29

Figure 10-15: Running in and Cutting..................................................................................... 10-31

Figure 10-16: Bowen Internal Cutter ..................................................................................... 10-32

Figure 10-17: Bowen Internal Cutter Parts............................................................................. 10-33

Figure 10-18: Bowen Collar Finder........................................................................................ 10-34

Figure 10-19: Mill Out Extension, Seal Bore and No Extension................................................ 10-35

Figure 10-20: JB Bushing-1................................................................................................... 10-38

Figure 10-21: JB Bushing-2................................................................................................... 10-39

Figure 10-22: Example Packer Data Sheet............................................................................. 10-41

Figure 10-23: Rotary Shoe Examples..................................................................................... 10-42

Figure 10-24: Bowen Packer Retriever.................................................................................. 10-44

Figure 10-25: Packer Sequence............................................................................................. 10-45

Figure 10-26: Baker Service Tool Packer Examples ............................................................... 10-46

Figure 10-27: Weatherford Washover Type Packer Milling Assembly with J Latch Type Retriever..................................................................................................................................... 10-47

Figure 10-28: Weatherford Pilot Mill Type Packer Milling Assembly with Shear Ring Type Retriever..................................................................................................................................... 10-48

Figure 10-29: H.E. & Bowen Simplex PRT’s......................................................................... 10-51

Figure 10-30: Cutting the Packer........................................................................................... 10-52

Figure 10-31: Mule Shoe Joint with “No-Go” ......................................................................... 10-54

Figure 10-32: 2 3/8-in. OD Special Washdown Mill ................................................................ 10-54

Figure 10-33: 9 5/8-in. 47 pound casing.................................................................................. 10-55

Figure 10-34: Seven-inch 29 pound casing.............................................................................. 10-55

Figure 10-35: Seven inch 35 pound Casing ............................................................................. 10-56

Figure 10-36: Worst Case – All Three Major OD of the Strings Coming Together at the Same Time..................................................................................................................................... 10-56

Figure 10-37: Baker A-5 Dual Packer Retrieval Method One ................................................. 10-58

Figure 10-38: Baker A-5 Dual Packer Retrieval Method Two................................................. 10-59

Figure 10-39: Baker A-5 Dual Packer Retrieval Method Three............................................... 10-60

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2001 Weatherford. All Rights Reserved.

Page i-xiv October 18, 2000

Figure 10-40: Baker A-5 Dual Packer Retrieval Method Four and Five, Inside-Outside BackoffCollar............................................................................................................................. 10-62

Figure 10-41: Rope Spear ..................................................................................................... 10-62

Figure 11-1: Decision Chart ....................................................................................................11-3

Figure 11-2: Collapsed & Parted Casing ..................................................................................11-5

Figure 11-3: Swaging Tool......................................................................................................11-6

Figure 11-4: Casing Roller ......................................................................................................11-7

Figure 11-5: Lace Joint...........................................................................................................11-8

Figure 11-6: Casing Parted at 3,450-feet..................................................................................11-9

Figure 11-7: Enter & Dress Parted Casing............................................................................. 11-10

Figure 11-8: Casing Repair Tool Sequence............................................................................. 11-11

Figure 11-9: Mill Types......................................................................................................... 11-14

Figure 11-10: External Casing Patch-1................................................................................... 11-16

Figure 11-11: External Casing Patch-2................................................................................... 11-17

Figure 11-12: External Casing Patch, exploded view............................................................... 11-18

Figure 11-13: External Casing Patch Grapple and Exploded View ........................................... 11-19

Figure 11-14: Casing Scraper................................................................................................ 11-20

Figure 12-1: Wireline Open Hole .............................................................................................12-3

Figure 12-2: Wireline Cased Hole ............................................................................................12-4

Figure 12-3: Bowen Side Door Overshot ............................................................................... 12-10

Figure 12-4: Bulldog Screwgrab .......................................................................................... 12-14

Figure 12-5: Wireline Stripping Job Assembly No. 1 ............................................................... 12-15

Figure 12-6: Wireline Stripping Job Assembly No. 2 ............................................................... 12-16

Figure 12-7: Wireline Stripping Job Rope Socket .................................................................... 12-17

Figure 12-8: Wireline Stripping Job Spear Head Overshot ....................................................... 12-18

Figure 12-9: Wireline Stripping Job C-Plate and Spear Head Sub and Adapter ......................... 12-18

Figure 12-10: Wireline Stripping Job Clamp............................................................................ 12-19

Figure 12-11: Wireline Stripping Job Rope Socket Anchor....................................................... 12-19

Figure 12-12: Wireline Stripping Job Grapple Assembly .......................................................... 12-20

Figure 12-13: Wireline Stripping Job Spiral Grapple ................................................................. 12-20

Figure 12-14: Wireline Stripping Job Basket Grapple............................................................... 12-21

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2001 Weatherford. All Rights Reserved.

October 18, 2000 Page i-xv

List of TablesTable 1-1: Maximum OD of Tools to Run in Casing Excluding Overshots ....................................1-7

Table 1-2: Example of Daily Charges Included in the Tally Book...............................................1-11

Table 1-3: Mill Out Concave Data Example .............................................................................1-12

Table 2-1: Weatherford Type P Boot Basket...........................................................................2-10

Table 2-2: Weatherford Globe Type Junk Basket.....................................................................2-12

Table 2-3: Bowen Itco Globe Type Junk Basket.......................................................................2-12

Table 2-4: Bowen (W7R) Reverse Circulation Junk Basket Specifications .................................2-14

Table 2-5: Bowen Full Flow Reverse Circulating Basket Dimensions.........................................2-15

Table 2-6: Recommended Fishing Tool Usage..........................................................................2-18

Table 2-7: Fishing Tools (use with Table 2-6)...........................................................................2-18

Table 2-8: Standard SFPM.....................................................................................................2-20

Table 3-1: Advantages and Disadvantages of Chemical Cutters ................................................3-13

Table 3-2: How The Shaped Charge Works.............................................................................3-17

Table 4-1: Weatherford Rotary Shoes .....................................................................................4-16

Table 5-1: Shale Control Inhibitors...........................................................................................5-11

Table 5-2: Flow Rates in Extended Reach Wells ......................................................................5-14

Table 5-3: Volume of Pills ......................................................................................................5-15

Table 5-4: Circulation Relative to Bottom’s Up Time................................................................5-15

Table 5-5: Single Acting Triplex Pump Data ............................................................................5-20

Table 5-6: Buoyancy Factor....................................................................................................5-22

Table 7-1: Screw In Sub Rating ................................................................................................7-9

Table 7-2: Overshot Rating.....................................................................................................7-10

Table 7-3: Bowen Overshot Uses ...........................................................................................7-10

Table 7-4: Overshot Types .....................................................................................................7-11

Table 7-5: Series 150 Overshot - Tightening Torques................................................................7-21

Table 7-6: One Trip Operation Example (Dress and Engage Fish) .............................................7-23

Table 7-7: Overshot Fishing Tool - Available Sizes ...................................................................7-28

Table 7-8: Clulow Sockets ......................................................................................................7-29

Table 7-9: Releasing Spear Rating...........................................................................................7-30

Table 7-10: Full Circle Type Bowen Releasing Spears..............................................................7-34

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2001 Weatherford. All Rights Reserved.

Page i-xvi October 18, 2000

Table 7-11: Box Tap or Die Collar Rating................................................................................7-41

Table 7-12: Taper Tap Rating .................................................................................................7-41

Table 7-13: Drill Pipe Pin Tap Rating ......................................................................................7-42

Table 7-14: Releasing Spear Rating.........................................................................................7-43

Table 9-1: Hole Description ......................................................................................................9-5

Table 10-1: Outside Cutter Dimensions.................................................................................. 10-10

Table 12-1: Pressure Required to Rupture Disks in Pump Out Sub ............................................12-9

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2001 Weatherford. All Rights Reserved.

October 18, 2000 Page i-xvii

IntroductionFishing is the technology of removing any undesirable object from the wellbore. Thefish may include all or part of the drill string, smaller pieces of equipment such as bitcones, pieces of tools, or any material accidentally dropped into the wellbore. In casedholes, there are many problems which create fishing jobs including but not limited toretrieving packers, fishing for parted tubing, and repairing collapsed casing. Pipe issometimes dropped and wireline and wireline tools are either stuck or parted resultingin a fishing job.

There are many different types of fishing jobs, fishing methods, and many types andkinds of fishing tools. Which tool to use depends on the type of fish in the hole,whether the fish is stuck or free, and whether it is in casedhole or openhole . Thecondition of the top of the fish and the condition of the hole at the top of the fish areother considerations.

Each fishing job is unique, but there are some "Best Practices" commonly used inmost jobs. The course outlined in this manual is designed to provide Fishing ToolSupervisors with a thorough overview of Weatherford’s best fishing practices. Thecontent includes proven techniques for solving difficult problems. Topics coveredinclude: job planning and record keeping, fishing for junk, open and cased hole fishing,fishing for parted pipe, fishing in cavities, and fishing for laterals. It also includes piperecovery methods, wireline fishing and casing repair .

This course can also be useful for salespersons and support staff who requireknowledge of how fishing tools work.

The sections are divided as follows:

Section 1 Job Planning and Record Keeping, illustrates the importance of proper jobplanning and which records are required for the job to run smoothly evenwith personnel changes.

Section 2 Fishing for Junk, covers the recovery of various debris from the wellbore.

Section 3 Pipe Recovery Methods, covers best practices for recovering pipe fromthe wellbore, whether this pipe is damaged or not.

Section 4 Open Hole Fishing, describes fishing in open hole environments.

Section 5 Mud, provides a brief overview of drilling fluids and special considerationsused during fishing operations.

Section 6 Fishing in Cavities, describes best practices used when fishing in cavities.

Section 7 Fishing for Parted Pipe, describes methods for fishing for damaged pipe

Section 8 Jarring Operations, describes the use of jars and accelerators in fishingoperations in various environments.

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2001 Weatherford. All Rights Reserved.

Page i-xviii October 18, 2000

Section 9 Fishing in Laterals, describes fishing in lateral boreholes.

Section 10 Cased Hole Fishing, discusses fishing in cased hole environments.

Section 11 Casing Repair, describes the processes preferred for repairing damagedcasing.

Section 12 Fishing for Wireline, presents options for fishing for wireline componentslost in boreholes.

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2001 Weatherford. All Rights Reserved

February 28, 2001 Page 1-1

Fishing Best Practices Manual

Job Planning and Record Keeping

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

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2001 Weatherford. All Rights Reserved.

Page 1-2 February 28, 2001

Contents

Introduction........................................................................................................................1-3

Cardinal Rules of Fishing.................................................................................................1-5

Rule 1 – Obtain the Important Details or Ask the Important Questions ...........................1-5

Rule 2 – Know all the Do’s and Don’ts ........................................................................1-5

Rule 3 – Determine the Dimensions .............................................................................1-6

Rule 4 – Maintain An Accurate Top of Fish Location....................................................1-6

Arriving on Location .......................................................................................................1-7

In and Out Method..........................................................................................................1-8

Kelly Bushing (KB) Measurements..................................................................................1-9

Tally Book....................................................................................................................1-10

Tally Book Abbreviations ..............................................................................................1-11

Leaving the Job Site Upon Job Completion .....................................................................1-14

Review ........................................................................................................................1-14

Notes:..........................................................................................................................1-16

List of Figures

Figure 1-1: Fishing Job Planning Flow Chart...............................................................................1-4

Figure 1-2: In and Out Method Example ....................................................................................1-8

Figure 1-3: Top of Fish Calculation Example ..............................................................................1-9

Figure 1-4: Weatherford Fishing & Cutting Service Report .......................................................1-14

List of Tables

Table 1-1: Maximum OD of Tools to Run in Casing Excluding Overshots ....................................1-7

Table 1-2: Example of Daily Charges Included in the Tally Book...............................................1-11

Table 1-3: Mill Out Concave Data Example .............................................................................1-12

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 1-3

IntroductionSuccessful fishing jobs start with excellent job planning and meticulous recordkeeping. Record keeping is especially helpful when there is a shift change before thejob has been completed. One of the first steps in the job planning process is obtainingrecords from previous jobs. Records from previous jobs form a base of informationthat can be used as a resource when planning fishing jobs. Figure 1-1 illustrates thejob planning work flow. Record keeping also comes into play on current jobs.

Proper preparation ensures that most options of a fishing job are planned for and thatequipment, personnel, and other assets are available when needed.

When contacted regarding a possible fishing job, a base of information must beobtained from the well owner/operator to determine the feasibility of the job.

Research previous fishing jobs with similar characteristics. Obtain ALL details aboutthe well and job site.

Schedule both personnel and equipment assets for the job. Obtain commitments forany equipment or personnel that may be needed in addition to the assets initiallycommitted to the job.

Ensure that the well owner/operator understands and agrees on the course of actionplanned to complete the fishing job.

Consider previous jobs and possible complications of the job. Obtain standbycommitments for assets that might be required to successfully complete the job evenif the operation does not proceed as initially planned.

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2001 Weatherford. All Rights Reserved.

Page 1-4 February 28, 2001

Pre

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Figure 1-1: Fishing Job Planning Flow Chart

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 1-5

Cardinal Rules of FishingWhen a fishing tool supervisor is notified that he is to go on a job, his firstconsideration is to formulate a game plan to solve the customers problem. He shouldget agreement on the plan from the company man. An alternate plan should also beconsidered. By discussing the job with his fishing tool coordinator and the companyman, every one will be in the loop. A phone number of a contact person on the rigshould be secured in case of any delay or problem lining up the tools. Get gooddirections to the rig or boat dock and give the company man a reasonable ETA. Theywill have other things to do while waiting on fishing tools.

Regardless of the type of job, there are some basic rules of fishing which apply to alljobs.

Rule 1 – Obtain the Important Details or Ask the ImportantQuestions

Several important details should be obtained about the company, job location, wellparameters, work-string, fish and the operation at the time of the incident.

• What is the hole size, angle and depth?

• What is the size, weight and depth of all casings and liners?

• What are the connections on the work string and drill collars?

• Are there jars in the hole and are they working?

• Does the job require jars?

• Ask that a copy of the Bottom Hole Assembly (BHA) be faxed to you.

Rule 2 – Know all the Do’s and Don’ts• Don’t ever rotate the fish out of the hole

• Don’t assume that a fast trip time is always the best

• Don’t ever run anything into the hole that is not OD fishable.

This does not include overshots or washpipe. It refers to bit subs, drill collars,jars, the fishing neck on boot baskets, mud motors, stabilizers, spears or othertools.

• Do familiarize yourself with the fish. Make use of the composite catalog,technical manuals, and manufacturers drawings to learn critical points ofrecovering, burning over or milling up the fish.

• Do have an exact replica of the fish (same type packer, etc.) delivered to thelocation. It is far more valuable than drawings, specification sheets, or photos.

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2001 Weatherford. All Rights Reserved.

Page 1-6 February 28, 2001

Rule 3 – Determine the DimensionsIt is critically important to determine all possible dimensions of the fish. This can bedone by obtaining a complete well profile wherever possible. Client companyinformation and local geology should be known.

Following is information that should be included in the well profile:

• Dimensions in the well profile:

OD, ID, length of the fish

OD, ID, length of the fishing tool assembly

OD, ID, length of the work string

• Location of the top of the fish

• Tensile and torsional strengths of everything that is run into the hole. Pull strengthis 80% of the tensile strength. Strength of the fish must be either memorized ornoted in a readily accessible location. (You may need to pull this informationquickly and not have the time to figure or research maximum pull values.)

Rule 4 – Maintain An Accurate Top of Fish LocationOne of the most difficult jobs a fishing supervisor has is keeping accurate figures andalways knowing where the top of the fish is.

Important: The number one reason for being relieved from a job is not knowing where the top ofthe fish is. Once you verify the depth of the top of fish, NEVER deviate from thatbase number. If some fish is recovered or the fish falls, the depth obviously must beadjusted, the base number MUST NEVER change.

Verify the top of fish on the first trip out of the hole and continue to use this figure.Strap out of the hole on the very first trip. Verify the pipe count and ask the drillers tonotify you if they pick up or lay down any pipe.

Note: You must be alert and observe the operations. Don’t depend on the drillerto necessarily inform you if they pick up or lay down pipe. It is the fishingsupervisor’s job to ensure that an accurate count is maintained.

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 1-7

Table 1-1: Maximum OD of Tools to Run in Casing Excluding Overshots

Minimum Size Casing Maximum Tools to Run Wash Pipe to Cover

O.D. I.D. Wt. O.D. O.D. I.D. Wt.

4-1/2 3.754 16.60 2-3/4 3-1/2 2.955 9.20

4-1/2 3.920 13.50 3-1/16 3-3/4 3.250 9.50

5 4.276 18.00 3-1/4 4 3.428 11.60

5-1/2 4.670 23.00 3-1/2 4-3/8 3.749 13.58

5-1/2 4.778 20.00 3-5/8 4-1/2 3.826 16.60

6 5.240 23.00 4-1/8 5 4.276 18.00

6-5/8 5.791 28.00 4-5/8 5-1/2 4.892 17.00

7 6.004 35.00 4-3/4 5-3/4 4.990 22.50

7 6.276 26.00 5-1/8 6 5.325 20.00

7-5.8 6.625 39.00 5-3/8 6-3/8 5.625 24.00

8-5/8 7.511 49.00 6 7 6.276 26.00

8-5/8 7.825 36.00 6-3/8 7-3/8 6.625 29.00

8-5/8 8.017 28.00 6-5/8 7-5/8 6.875 29.70

9-5/8 8.535 53.50 6-7/8 8-1/8 7.185 39.50

9-5/8 8.835 40.00 7-3/8 8-3/8 7.625 35.00

10-3/4 9.760 55.50 7-7/8 9 8.150 40.00

10-3/4 9.950 45.50 8-3/8 9-5/8 8.681 47.00

13-3/8 all wts. 10-5/8 11=3/4 10.88 54.00

16 all wts. 12 13=38 12.415 68.00

Arriving on LocationUpon arriving on the rig, the supervisor should verify all the pertinent information withthe company man and/or tool pusher, check his equipment and verify all informationabout the job.

• Introduce yourself to the company man

• Verify all pertinent information concerning the fish, well, and local conditions withthe company man

• Check your tools ASAP

Grapples are generally manufactured in 1/16 or 1/8-inch increments. The fishingsupervisor should personally caliper all tools upon arrival on location. Precisionis critically important when calipering tools.

• Record the BHA and pipe in the hole with the driller

• Count all the pipe on the location and check this against the company man’srecords.

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2001 Weatherford. All Rights Reserved.

Page 1-8 February 28, 2001

• Clean out the V door and mark the first joint of pipe on the rack.

• Count and tie off all pipe in the derrick. The count on the surface subtracted fromthe total on location should equal what is in the hole.

In and Out MethodThe “In” and “Out” method is a good way of checking the string figures for possiblemistakes. The example shown in Figure 1-2 illustrates this method while going froman overshot run to a wash-pipe run. First we add up the new wash pipe BHA, thefishing string and length needed down on the kelly to reach the top of fish. Then wetotal the old overshot BHA and any other pipe left out to allow room for thewashpipe. We then subtract the new BHA from the old BHA and the difference willbe the amount down on the kelly required to reach the fish. To use this method, thetotal left out must be greater than the total picked up.

In and Out Method

Out In

DOK 23.65 Shoe 4.60

BHA 311.35 3 Jts. WP 95.96

1Std. DP 94.00 Sfty. Jt. 2.75

Total out 429.00 Jars 6.90

Total In (BHA) 411.66 X-over 1.45

Diff. &DOK 17.34 Tools 111.66

10 DC 300.00

BHA 411.66

19 Std. DP 1786.00

2197.66

DOK 17.34

TOF 2215.00

Figure 1-2: In and Out Method Example

The total out must always exceed total up to use the formula shown in Figure 1-2.

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 1-9

Top of fish example. The following is an example using the in and out method forcalculating the depth of the top of the fish.

• Twisted off while drilling @ 4,000-ft.

• Recovered 3,895.73-ft. including length Down On Kelly (DOK)

• Made Bit trip; tag fish with 37-ft. DOK

• Compute difference bit run and overshot run

• Subtract the (in) from the (out)

• Difference will be length DOK w/overshot run

The out length must be greater than in length to work.

Out = kelly + fish In = Fishing String

Bit sub & bit 4.45 Tools 24.48

Jars & subs 39.28 5 DC 155.83

4 DC 123.54 180.31

DOK 37.00

Total out 204.27

Total in 180.31

DOK 23.96

Figure 1-3: Top of Fish Calculation Example

Kelly Bushing (KB) MeasurementsThe standard oilfield measurement to any depth downhole is recorded from groundlevel, plus the distance to the kelly bushing (KB) on the rig that drilled the well.

This is called the original elevation and is recorded in the well file.

If a workover rig is later employed, the difference in this rigs elevation from theoriginal one must be accounted for.

The difference in elevation is added to or subtracted from the current pipe tally inorder to correlate with the original well elevation.

This can be of great importance in some cases.

• Example: Original elevation is 30-feet.

• Current elevation is 6-feet.

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2001 Weatherford. All Rights Reserved.

Page 1-10 February 28, 2001

• The difference of 24-feet must be added to the current pipe tally so that downholedepths will correlate.

Tally BookThe tally book should be kept in such a manner that a relief man could carry on thejob with information contained in the book. A complete description of the fish and allwell data should be recorded. The tally book should be clean, legible, accurate andcurrent. Use one line for each tool description with the OD, ID, length, fishing neckand serial number. It is important to document what tools were run for billingpurposes.

Include a record documenting what happened on each trip because this is useful forjob analysis after the job has been completed.

If a milling job is performed, all parameters must be recorded in a timely manner.These parameters include depth, RPM, Strokes Per Minute (SPM), Weight On Bit(WOB), torque, time and rate of penetration. This information is valuable for futurereference.

If washpipe is run, the size and footage must be recorded along with all auxiliaryequipment and the daily charges.

Anything that will be billed to the customer, including estimated repairs or soldgrapples, must be recorded on the resume and signed by the company man. A newpage should begin each midnight and only one trip should be recorded on each page.An example tally book and resume page follows.

It is important that the fishing supervisor call in a report to his fishing coordinator eachday.

Important: Usually the fishing tool coordinator will be talking to the operators representative intheir office on a daily basis, and the fishing tool coordinator needs to be keptinformed regarding the job’s progress.

The tally book must be:

• Accurate, legible and current

• Include the time, date, trip / job number

• Have a brief description for each trip

• Have a record of any accidents

• Maintained as if it is to be passed on to the relief man

• Be kept for future reference

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 1-11

Table 1-2: Example of Daily Charges Included in the Tally Book

Days Qty Tool Description & Report Serial # Est. Price

1 1 8 3/8 SOD x 7 ¼ SID Scallop R. Shoe 2965 $2010.00

1 14 Joints 8 1/8 OD wash pipe (434’) Pearland $985.00

1 1 4 ½ if x 8 1/8 wp pin canfield bushing 21047 $390.00

1 1 6 1/6 OD Bowen Fishing Jar x 4 ½ if 9202071 $1450.00

1 1 8 1/8 wash pipe slips 96777 $275.00

T.I.H. Tagged top of fish @ 6572. Got over TOF andslacked off to the cement @ 6656. Started milling over fish@ noon. Milled over fish 12 hours from 6656 to 6710. Millquite.

New Page for 03-16-99

Circulate hole clean and start POH @ 2:00am.

Sub Total

Previous

Total

$6402.00

$2895

9297

Tally Book AbbreviationsRPM rounds per minute TOF top of fish

SPM strokes per minute MD measured depth

WOB weight on bit TVD true vertical depth

BHA bottom hole assembly BF buoyancy factor

WOC wait on cement DP drillpipe

WOO wait on orders DC drill collar

WOW wait on weather Dh diameter of hole in inches

TIH trip in hole e stretch in inches

POH pull out hole P over pull in pounds

GPM gallons per minute ESP estimated stuck point

AV annular velocity MOP margin of over pull

ECD equivalent circulation density NP neutral point

FV funnel viscosity OPT optimum

C&C circulate and condition mud MW mud weight in ppg

HHP hydraulic horsepower Lbs pounds

LC loss circulation Len length in feet

LCM loss circulation material LOT leak off test

YP yield point BOP blow out preventor

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2001 Weatherford. All Rights Reserved.

Page 1-12 February 28, 2001

WL water loss SLM steel line measurement or strap in/out hole

The following table shows an example of window milling data that might be includedin the Tally book.

Table 1-3: Mill Out Concave Data Example

Depth RPM SPM WOB Torque Time Minutes Feet

3282-85 88-116 65 2 1,000 00:15-1:00 45 1

86 116 65 3 12-18 1:30 30 2

87 116 65 4 11-15 1:45 15 3

88 116 65 4 12-16 1:55 10 4

89 116 65 4.5 12-16 2:10 15 5

90 116 65 4.5 12-14 2:25 15 6

91 116 65 4.5 12-16 2:30 5 7

92 116 65 4.5 10-18 2:33 3 8

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 1-13

FISHING & CUTTING SERVICE REPORT

WO#

STORE

CUSTOMER: BY: SUPERVISOR:

DATE: STATE: COUNTY: FIELD: LEASE: WELL: SERVICE LOCATION

CHARGE TO:

ADDRESS:

ATTN:

TOTAL:

SUPERVISOR’S TIME DAYS FROM: THRU: @

CAR NO. SUPERVISOR’S AUTO MILEAGE WITH TRAILER MILES @

OPEN HOLE � CASED: � TYPE OF FISH: DEPTH O FJOB:

TYPE OF JOB: HOLE SIZE: OTHER SERVICES:

CUSTOMER SIGNATURE

PRINTED NAME

TITLE CUSTOMER COMMENT

| ENTER DATA

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2001 Weatherford. All Rights Reserved.

Page 1-14 February 28, 2001

Figure 1-4: Weatherford Fishing & Cutting Service Report

Leaving the Job Site Upon Job CompletionThe job is not complete until the paperwork is completed.

Account for all Weatherford tools.

Break down all tools whenever possible on the rig using the rig tongs when they comethrough the rotor. Vendors normally charge about $100.00 per joint to break downthe tools and most Weatherford stores do not have the facilities to perform thisoperation. Rig time on some offshore rigs is prohibitively expensive for this operation.When fishing on offshore rigs in the north sea especially, the customer should becharged for breaking down the tools at the shop facility, it is cheaper for thecustomer.

Ensure that all protectors are installed on the tools before transport back to theWeatherford store location. They arrived onsite with protectors in place.

Ensure that only Weatherford property is transported back to the Weatherfordstore location. It is difficult to arrange a return trip to bring equipment back to thewell site that is not the property of Weatherford.

ReviewSuccessful jobs require extensive research and paperwork before the job is acceptedor started.

Meticulous paperwork MUST be maintained throughout ALL phases of the job.

An example of the fish, if available, is an invaluable aid to the fisherman on the rigsite.

An accurate top of fish depth MUST be obtained, verified and maintained by thefisherman.

Accurate caliper measurements of the tools must be made onsite by the fishermanPersonally.

The fishing tool coordinator should be consulted when the company man does notagree with the Weatherford fishing supervisor’s suggested course of action.

The company man must sign the resume when Weatherford’s suggested course ofaction is refused.

Any and All charges must be included on the resume. Charges can be negotiated offthe bill but are extremely difficult to add to the bill.

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 1-15

The company man must sign the job resume when it is completed.

Don’t transport any equipment not belonging to Weatherford back to the Weatherfordstore.

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2001 Weatherford. All Rights Reserved.

Page 1-16 February 28, 2001

Notes:

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2001 Weatherford. All Rights Reserved

February 28, 2001 Page 2-1

Fishing Best Practices Manual

Fishing for Junk

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

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2001 Weatherford. All Rights Reserved.

Page 2-2 February 28, 2001

Contents

Introduction........................................................................................................................2-5

Junk or Debris Evaluation................................................................................................2-7

Fishing Magnets..............................................................................................................2-7

Procedure run Magnet.................................................................................................2-8

Globe Type Junk Baskets ..............................................................................................2-10

Example Procedure...................................................................................................2-10

Reverse Circulating Junk Basket....................................................................................2-13

Bowen Full Flow Reverse Circulating Basket .................................................................2-15

Example Procedure...................................................................................................2-15

Cone Dimensions ..........................................................................................................2-17

Junk Shot .....................................................................................................................2-18

Poor Boy Basket ..........................................................................................................2-18

Recommended Fishing Tool Usage ................................................................................2-19

Mills.............................................................................................................................2-20

Milling Rates in Surface Feet Per Minute (SFPM) ..........................................................2-21

Cone Buster Mills .........................................................................................................2-21

Cement Mills ................................................................................................................2-22

Notes:..............................................................................................................................2-24

List of Figures

Figure 2-1: Junk Fishing Job Flow Chart ....................................................................................2-6

Figure 2-2: Fishing Magnet with a Cripple Type Guide Attached .................................................2-8

Figure 2-3: Boot Basket............................................................................................................2-9

Figure 2-4: Globe and Boot Baskets ........................................................................................2-11

Figure 2-5: Standard Catcher Baskets .....................................................................................2-12

Figure 2-6: Bowen Itco Type Junk Basket...............................................................................2-14

Figure 2-7: Bowen Full Flow Reverse Circulation Junk Basket..................................................2-16

Figure 2-8: Rock Bit Cone Dimensions Example From Bowen Instruction Manual......................2-17

Figure 2-9: Finger Shoe, Poor Boy Basket, and Poor Boy Basket in Borehole ............................2-18

Page 41: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 2-3

Figure 2-10: Cone-Buster Mills ...............................................................................................2-22

Figure 2-11: Cement Mills.......................................................................................................2-23

List of Tables

Table 2-1: Weatherford Type P Boot Basket...........................................................................2-10

Table 2-2: Weatherford Globe Type Junk Basket.....................................................................2-12

Table 2-3: Bowen Itco Globe Type Junk Basket.......................................................................2-12

Table 2-4: Bowen (W7R) Reverse Circulation Junk Basket Specifications .................................2-14

Table 2-5: Bowen Full Flow Reverse Circulating Basket Dimensions.........................................2-16

Table 2-6: Recommended Fishing Tool Usage..........................................................................2-19

Table 2-7: Fishing Tools (use with Table 2-6)...........................................................................2-19

Table 2-8: Standard SFPM.....................................................................................................2-21

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2001 Weatherford. All Rights Reserved.

Page 2-4 February 28, 2001

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Page 43: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 2-5

IntroductionThis section discusses fishing for junk in the borehole. Several classes of junk andfishing equipment used to retrieve that junk are discussed in this section. Figure 2-1 isa flow diagram showing an overview of the decisions and processes generallyrequired to successfully fish for junk in a borehole.

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2001 Weatherford. All Rights Reserved.

Page 2-6 February 28, 2001

Jun

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Figure 2-1: Junk Fishing Job Flow Chart

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 2-7

Junk or Debris EvaluationAny debris or junk in the borehole must be evaluated before any successful fishingattempt can be made. Consider the following before proceeding with a fishing job.

• What is the junk size, weight, and condition?

• Is the junk magnetic?

• Pick it up or mill it up?

Remember, all jobs are unique in one way or another. It is possible that the job willrequire a combination of different tools and/or runs. Follow the decision chart (Figure2-1) for the right answers

Fishing MagnetsBowen fishing magnets are primarily used to pick up bit cones, but they can pick upall types of small objects with magnetic properties. Magnets should be run on pipeinstead of wireline because of the capability to circulate and rotate1. It is necessary towash the top of the fish sufficiently so that enough surface area will make contactwith the magnetic pole plate. Run a boot basket directly above the magnet to catchany loose bearings or small pieces of junk.

Note: Most, but not all tungsten carbide bit inserts are non-magnetic.

Fishing magnet runs on wireline are usually made inside the casing with clear fluid inthe hole.

Check to see if the magnet is charged properly by attaching a 20-lb. sledge hammerto the face of it. If the magnet will support the weight of a sledge hammer, it willlikely hold any small pieces of junk in the wellbore. The lifting capacity is a function ofsize, area, and charge.

The OD of the magnet should be 1/4- to 1/2-in. less than hole size.

1 There are adapters available to run magnets on a wireline.

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2001 Weatherford. All Rights Reserved.

Page 2-8 February 28, 2001

Figure 2-2: Fishing Magnet with a Cripple Type Guide Attached

Procedure run Magnet1. Trip in hole with the magnet and stop about 30-ft. from bottom.

2. Circulate and ream to the bottom a couple times to rake any loose junk off thewall and top of the fish.

3. Circulate at a good rate a couple inches off the fish to clean off any cuttings.

4. Rotate a couple rounds while slacking off to help roll the fish into the face of themagnet.

CAUTION: Be careful, the magnet is not a drilling tool.

A cut lip or crippled type guide is best suited to use with a magnet. The rotarymay slap as the guide rakes the cones into the face of the magnet and you will beable to slack off a couple inches.

5. Stop rotating and set 3,000 to 4,000 pounds of weight down on the junk, then shutthe pump off.

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 2-9

6. Pull out of the hole slowly without rotating. The guide should prevent the fish frombeing rubbed off while pulling out of the hole.

Run the magnet more than once if the volume of junk in the hole warrants.

A boot basket is loaded by pumping at ahigh flow rate while rapidly slacking offon the work string. After taggingbottom, shut the pumps off for a minutewhile raising the work string slowly. Asthe flow changes from turbulent tolaminar, the junk drops into the boot orcup. This procedure is repeated severaltimes to recover all the junk on thebottom.

Figure 2-3: Boot Basket

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2001 Weatherford. All Rights Reserved.

Page 2-10 February 28, 2001

Table 2-1: Weatherford Type P Boot Basket

Complete Recommended Maximum OverallAssembly Hole Sleeve LengthNumber Size

ConnectionOD

Borein.

471-000-4 4-1/8 x 4-1/2 2-3/8 Reg. 3-11/16 1 32

471-140 4-5/8 x 4-7/8 2-7/8 Reg. 4 1 32-1/2

471-140 5 x 5-3/4 2-7/8 Reg. 4-1/2 1 32-1/2

471-145 5-7/8 x 6-3/8 3-1/2 Reg. 5 1-1/2 3

471-145 6-1/2 x 7-3/8 3-1/2 Reg. 5-1/2 1-1/2 32

471-150 7-1/2 x 8-1/8 4-1/2 Reg. 6-5/8 2 34

471-150 8-5/8 x 9-5/8 4-1/2 Reg. 7 2 34

471-160 9-5/8 x 11-3/8 6-5/8 Reg. 8-1/2 3 36

471-160 11-1/2 x 13 6-1/2 Reg 9-5/8 3 36

Globe Type Junk BasketsThe Bowen Itco/Globe basket (Figure 2-4) consists of a top sub, barrel, and tungstencarbide milling shoe. Inside are two manganese bronze catchers (Figure 2-5) that arefree to rotate. The globe basket is recommended for use in soft to medium formations(drilling rate above 15-ft. per hour). The crown on the shoe should be about 1/8- to1/4-in. less than hole size. The ID should be dressed with tungsten carbide to about1/8-in. less than the ID of the catchers. A crippled type shoe is the preferred type.Specifications for the Weatherford and Bowen Itco Globe junk baskets are listed inTable 2-2 and Table 2-3.

Example Procedure1. Begin rotating and circulating about 30-ft. off bottom with medium pump rate and

RPM’s.

Important: It is extremely important to circulate the debris and fill away from the hard bottombefore starting to cut a core. The fill MUST be washed away if the junk is to besuccessfully fished.

2. Tag bottom and watch the torque gauge. The rotary should slap as the shoe getsover the cones, or junk, and then the torque should smooth out. You should knowthe measurements from the bottom of the shoe to the top catcher and to whereyou would “bump” up.

3. Proceed to cut the core until the shoe quits or you bump up.

4. Mill on the shoe with 3,000 to 4,000-lb. of weight.

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 2-11

CAUTION: Do not exceed 4,000-lb. or you will wear the shoe out prematurely.

If you cut a full core, you get an increase in pump pressure.

5. To break the core, stop the rotary, slow the pump down, and raise the pipe aninch or so.

6. Rotate a few rounds and pick up a couple more inches.

7. If there is no drag, pull out of the hole without rotating. If a good core isrecovered, containing no junk, normal drilling may be resumed.

T o n g s

T o n g s

T o n g s

Globe BasketFluid flow

Tongs

Tongs

Boot Basket

Figure 2-4: Globe and Boot Baskets

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2001 Weatherford. All Rights Reserved.

Page 2-12 February 28, 2001

Figure 2-5: Standard Catcher Baskets

Table 2-2: Weatherford Globe Type Junk Basket

Assembly Hole OD Carbide Crown Max. Dia. of Fish Unless

Number Size In. In. In. Specified

473-118 3-7/8 x 4-1/4 3-5/8 3-3/4 2-23/32 2-3/8Reg.

473-117 4-5/8 x 4-7/8 4-1/4 4-1/2 3 4-11.6#FJWP

473-123 4-7/8 x 5-1/4 4-1/2 4-3/4 3-3/8 4-1/2-16.6#FJWP

473-122 5-1/4 x 5-5/8 4-3/4 5-1/32 3-9/16 4 1/2 – 16#FJWP

473-120 6 x 6-3/8 5-5/8 5-3/4 4 5 1/2 17#FJWP

473-125 6-1/4 x 6-3/4 5-7/8 6 4 5 1/2 17#FJWP

473-126 6-1/4 x 6-3/4 5-7/8 6 4-9/16 5 1/2 x -Line

473-130 6-7/8 x 7-1/4 6-1/4 6-1/2 4-5/8 5 1/2-17#FJWP

473-135 7-3/8 x 7-7/8 7 7-1/4 5 4 1/2 API Reg.

473-140 7-7/8 x 8-3/4 7-1/2 7-5/8 5-5/8 7 x -Line

473-141 8-3/4 x 9-1/2 8-3/8 8-5/8 6-1/4 7 5/8 x -Line

473-142 9-1/2 x 10-1/2 9-1/8 9-3/8 7-1/4 8 5/8-36#FJWP

473-143 10-3/4 x 11-7/8 10-1/4 10-1/2 8-1/8 9 5/8-43.5# FJWP

473-144 12 x 15 11-1/4 11-3/4 9 7 5/8 x -Line

Table 2-3: Bowen Itco Globe Type Junk Basket

Basket No. Hole Size Shoe O. D. Barrel O. D. Max. Fish O. D.

14590 3-3/4x4-1/8 3-5/8x4-1/8 3-5/8 2-23/32

14586 4-1/4x4-1/2 4-1/16x4-1/2 3-1/4 2-31/32

14595 4-5/8x5 4-1/2x5 3-7/8 3-9/32

14600 5-1/8x5-1/2 4-7/8x5-1/2 4-1/4 3-9/32

14506 5-5/8x6 5-3/8x6 4-3/4 4-1/16

14610 6-1/8x6-5/8 5-7/8x6-5/8 5-7/8 4-5/16

14615 6-3/4x7-1/4 6-1/4x7-1/4 5-3/4 4-3/16

14620 7-3/8x8-1/4 7-1/8x8-1/4 6-1/2 5-7/16

14625 8-3/8x9-1/4 8-1/8x9-1/4 7-1/2 6-3/16

14630 9-3/8x10-1/4 9-1/8x10-1/4 8-1/2 7-3/16

14635 10-3/8x11-7/8 10-1/8x11-7/8 9-3/8 8-1/16

14640 11-3/4x14-1/4 11-1/4x14-1/4 10-3/8 9-1/16

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 2-13

Reverse Circulating Junk BasketReverse circulating fishing tools are the preferred tools for use in hard formations. Itis not necessary to cut a core with a reverse circulating junk basket to recover junk.The following conditions should be confirmed before using reverse circulating junkbasket.

• Check the ID’s to ensure that the reverse circulation steel ball will pass through

• Determine the mud capacity of the workstring. Pump the workstring capacitybefore dropping the ball.

An example of the Bowen reverse circulating junk basket and direction of the fluidflow and junk destination is shown in Figure 2-6, specifications for the Bowen W7Rreverse circulating junk basket are listed in Table 2-1.

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2001 Weatherford. All Rights Reserved.

Page 2-14 February 28, 2001

Figure 2-6: Bowen Itco Type Junk Basket

Table 2-4: Bowen (W7R) Reverse Circulation Junk Basket Specifications

Hole Size Barrel O. D. Max Dia. Of Fish

3-3/4 x 4-1/8 3-5/8 2-3/4

4-1/4 x 4-1/2 4-1/8 3

4-5/8 x 5 4-1/2 3-3/8

5-1/8 x 5-1/2 4-7/8 3-5/8

5-5/8 x 6 5-3/8 4-1/16

6-1/8 x 7 5-7/8 4-5/8

7-1/8 x 7-1/2 6-3/4 5-1/4

7-5/8 x 8-1/2 7-5/16 5-5/8

8-5/8 x 9-1/2 8-3/16 6-1/2

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February 28, 2001 Page 2-15

9-5/8 x 10-3/8 9-1/8 7-1/8

11-3/4 x 13-3/8 11 8-5/8

Bowen Full Flow Reverse Circulating BasketThe reverse circulating junk basket (Figure 2-7 and Table 2-5) is the preferred tool forfishing jobs performed in hard formations (drill rate of less than 15-ft. per hour).

It is sometimes difficult to cut more than one foot with a shoe in a hard formationbecause the fingers will break before the core can be cut. It is not necessary to cut acore to recover the junk when using the reverse flow basket.

The reverse circulation of the fluid creates a vacuum in the barrel and the junk issucked up into the barrel and caught in the basket. Trying to cut and break off a coremay result in breaking the fingers on the basket because the formation is too hard tobreak a core.

Example Procedure1. Run the reverse basket to within several feet of bottom

2. Start the pump slowly and increase the rate to the maximum safe circulatingpressure. Circulate all the fill before dropping the ball.

3. Tag bottom and rotate to stir up the junk.

Do not drop the ball to initiate reverse circulation until a thorough pumping job isdone.

4. Drop the ball and pump it down at a moderate speed. It should fall at the rate of1-1/2 minutes per thousand feet. When the ball is seated, there should be a drop inpump pressure. The fluid is now diverted to the outside of the basket thus causinga drop in pressure inside the basket. Since the hydraulic pressure is now greateron the outside of the basket than on the inside, the reverse flow of the drilling fluidpushes the junk up inside the basket and is retained by the flipper dog fingers ofthe catchers.

Note: If a drill string has been dropped and all three bit cones have been shearedoff, it may be necessary to cut a core to recover them because they may beembedded in the borehole.

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2001 Weatherford. All Rights Reserved.

Page 2-16 February 28, 2001

Figure 2-7: Bowen Full Flow Reverse Circulation Junk Basket

Table 2-5: Bowen Full Flow Reverse Circulating Basket Dimensions

Hole Size Barrel OD Maximum Diameter Fish

4-1/8x4-1/2 4 2-1/2

4-5/8x5 4-1/2 3-1/16

6-1/8x6-1/2 5-3/4 4-3/8

7-1/2x8-1/4 7 5-1/8

8-3/8x9-1/2 7-7/8 6-1/16

9-5/8x10-5/8 9-1/8 7-1/16

10-3/4x11-5/8 10-1/8 7-11/16

11-3/4x12-1/2 11 8-5/16

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 2-17

Cone DimensionsThe dimensions of the cone MUST be known before deciding which tool to run.Standard rock bit cone dimensions are shown in Figure 2-8, this is the sameinformation that can be found in the Bowen user manuals.

• 7-7/8-in. bit cone = 5-17/64-in. OD

• Bowen Itco Type Junk Basket = 7-1/8-in. OD barrel x 5-28/64-in. ID

• Homco type H Junk Basket = 71/2-in. OD barrel x 5-40/64 ID

Figure 2-8: Rock Bit Cone Dimensions Example From Bowen Instruction Manual

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2001 Weatherford. All Rights Reserved.

Page 2-18 February 28, 2001

Junk Shot

A junk shot is a shaped charge used to break up large pieces of junk so thatthey are more easily recovered using conventional methods. A junk shotshould only be run in open hole because the shot could damage the casing.The shot must be run on drill pipe and collars to keep the force of itsexplosion from blowing it up hole. The tool is lowered to the junk and all fillis circulated off the junk. A go devil is dropped to set off the charge and itsdownward directed blow breaks up the junk. Occasionally, the force of theexplosion embeds the junk into the formation where it will not impede a rollercone bit. A short tooth bit with a boot basket may do the job. The junk willbe walled off and drilling resumes.

The junk MUST be on bottom. Ensuring that the junk is on bottom mayrequire a bit trip.

Poor Boy BasketPoor boy baskets are primarily used when the fish is too large or of irregular shapeand size for conventional junk baskets. They should be about ½-in. smaller than holeID. Poor boy baskets can be dressed with finger type bottoms for closing around afish or with tungsten carbide, wire, dimple rings, or rods. A spring tine basket is agood friction type basket. These baskets are custom made for a particular job and areconstructed of mild steel to allow bending action without breaking.

Figure 2-9: Finger Shoe, Poor Boy Basket, and Poor Boy Basket in Borehole

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 2-19

Recommended Fishing Tool UsageThe recommended fishing tool usage listed in Table 2-6 is a guide. All jobs haveunique circumstances that must be considered. Table 2-6 can be used as a startingpoint for making the decision regarding which tool to use. Each tool may be used oneor more times or in conjunction with other tools.

Table 2-6: Recommended Fishing Tool Usage

Debris Tool Type Comments

Drill Bit Cone A,D,E Magnet if only one cone, Reverse basket or po-boy basket ifmore than one cone.

24-in. pipe wrench D,E,F,H Core type basket, reverse circulating basket, po-boy basket,wire catcher basket

Tong dies A,D,E,F,H Magnet, core type basket, reverse circulating basket, po-boybasket, wire catcher basket

Drill Bit K,N

Chain A,D,E,F,H

Hammer A,D,E,F,G,H Magnet, core type basket, reverse circulating basket, po-boybasket, wire catcher basket

Wire Rope J

Rubber D,E,F,H Core type basket, reverse circulating basket, po-boy basket,wire catcher basket

Lead D,E,F,H

Shepherd’s Hook G,H,I Ping shoe, wire catcher basket, spring tine basket

Perforating Gun G,H,I

Table 2-7: Fishing Tools (use with Table 2-6)

Fishing Tool

A. Magnet

B. Mill

C. Boot basket

D. Core Type basket

E. Reverse Circulating

F. “Po-Boy” basket

G. Ping Shoe

H. Wire Catcher Basket

I. Spring Tine basket

J. Rope spear – Center Spear

K. Impression block

L. Wash pipe

M. Rope Spear – Two Prong Grabs

N. Taper Tap

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2001 Weatherford. All Rights Reserved.

Page 2-20 February 28, 2001

MillsJunk mills are the surest way to eliminate junk in the hole. The insert type is bestsuited for milling pipe/tools anchored securely in the wellbore.

CAUTION: Chatter, vibration or loose junk are detrimental to the inserts.

Crushed tungsten carbide mills perform well in almost all environments. These millsdo not perform well in hard abrasive formations. Consider using a Bowen Shock Subif milling drill pipe or casing to cut down on vibration.

A skirted flat bottom or concave type mill is best for milling a flared or burred top offish prior to engagement with an overshot. Because the skirted mill is stabilized andthe fish is contained within the skirt, it cannot slip off to the side. A blade type is themost aggressive style and is used to mill junk, or cast iron material which will breakup. Mills with stabilizer pads should be used inside the casing.

Mills require adequate circulation to flush the cuttings and cool the mill. A bootbasket is run directly above the mill. Because fluid circulating velocity is reduced uponreaching the upper portion of the cylinder, the metal cuttings will drop into the basket.

Mill by torque and not by weight. A standard rule of thumb is not to exceed 1,000pounds weight per OD inch of the mill.

Some examples of different types of mills are shown in Figure 2-10, and Figure 2-11on the following pages.

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2001 Weatherford. All Rights Reserved.

February 28, 2001 Page 2-21

Milling Rates in Surface Feet Per Minute (SFPM)The milling rates for the carbide on the mills is specified by the manufacturer inSurface Feet Per Minute (SFPM). Table 2-8 lists some standard milling rates. Otherrates may be computed using Equation 2-1.

The surface feet per minute must be converted to revolutions per minute (rpm). Thepms may bederirves fomy the(SFPd using ) Tj2348.75 0 TD -0.2967 Tc -0.2658 Tw (Equation ) Tj 41.25 0 TD 0.375 Tc 0 Tw (2) Tj 5.25 0 TD 0.0038 Tc (-) Tj 3.75 0 TD 0.375 Tc (1) Tj 5.25 0 TD 0.1875 Tc (.) Tj 2920.25 -15.75 TD /5 95.75 Tf 0.0667 Tc -034617 Tw (Table ) Tj 87.5 0 TD -0.115 Tc 0 Tw (2) Tj 5.25 0 TD -0.4967 Tc (-) Tj 5 0 TD -0.115 Tc (8) Tj 5.25 0 TD -0.063 Tc 039625 Tw : Sstandard(SFP1) Tj ET0.81980.81980.8198 rg .16 51 3.7512 0.75175 re f BT 647.255165 TD 0 0 0 rg /F295.75 Tf 024192 Tc 5 Tw (Mil1) Tj ET0.81980.81980.8198 rg 2813.551 3.75660.75175 re f BT2815.755165 TD 0 0 0 rg 0.1615 Tc (SFP1) Tj ET1641.255268.75 8.75 8.75 re f1641.255268.75 8.75 8.75 re f16255268.7512 0.75 8.75 re f2825.755268.75 8.75 8.75 re f2813.55268.75660.75 8.75 re f3 50.255268.75 8.75 8.75 re f3 50.255268.75 8.75 8.75 re f1641.2551 3.75 0.75175 re f2825.7551 3.75 0.75175 re f3 50.2551 3.75 0.75175 re f BT 647.254915.75 T /4295.75 Tf -0.0263 Tc 031867 Tw Crushves carbide mill

Equation 2-1showny blow0 to computy the(SFPdtan RPM(.) Tj 76.75 -19.5 TD -0.4.05 Tc 0 Tw Example:-) Tj 65 -19.5 TD -036984 Tc 055695 Tw (Mil Dia. = 4.5-in.e) Tj 0 -19.5 TD -0.3063 Tc 031758 Tw RPM( = 512 e) TjT*D -009896 Tc 0.8617 Tw Whats is the(SFPd? ) Tj 015.75-395.75 TD /85125 Tf 0215 Tc 0 Tw (SFP1) Tj -15.7505 TD /F3 25 Tf 5 Tc (42.) Tj 287.5 0 TD(.26.) Tj 5 0 TD (.) Tj 65 0 TD 0.5..Equation 2-1

T isflatsbottome coe buusper mile examples(shownying ) Tj2345 0 TD -0.7096 Tc 045817 Tw Figsuhe-2-0

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Page 2-22 February 28, 2001

Figure 2-10: Cone-Buster Mills

Cement MillsThe cement mills shown in Figure 2-11 has higher blades than those shown in Figure2-10 and is used primarily to mill cement.

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February 28, 2001 Page 2-23

Figure 2-11: Cement Mills

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Page 2-24 February 28, 2001

Notes:

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October 18, 2000 Page 3-1

Fishing Best Practices Manual

Pipe Recovery Methods

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

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Page 3-2 October 18, 2000

Contents

Introduction........................................................................................................................3-5

Formulas ........................................................................................................................3-6

Stretch Formula ..........................................................................................................3-6

Tapered String ............................................................................................................3-7

Blind Backoff ...............................................................................................................3-10

Free Point Indicator...................................................................................................3-10

Pipe Recovery Log ...................................................................................................3-12

String Shot Backoff.......................................................................................................3-13

Where to Backoff? ...................................................................................................3-13

Pup Joints.....................................................................................................................3-14

Chemical Cutter............................................................................................................3-14

Jet Cutters....................................................................................................................3-16

Super Jet Cutter............................................................................................................3-17

Shaped Charges............................................................................................................3-18

Severing Tool ...............................................................................................................3-19

Internal Mechanical Cutter ........................................................................................3-20

Operating Procedures For Internal Cutters ..............................................................3-21

Notes:..............................................................................................................................3-22

List of Figures

Figure 3-1: Pipe Separation Methods .........................................................................................3-5

Figure 3-2: Excel Spreadsheet for Free Point in Stuck Drill Pipe..................................................3-9

Figure 3-3: Pipe Sticking While Free Pointing...........................................................................3-12

Figure 3-4: Shot String Example ..............................................................................................3-13

Figure 3-5: Chemical Cutter and Severed Pipe .........................................................................3-15

Figure 3-6: Examples of Chemically Cut Pipe...........................................................................3-15

Figure 3-7: Jet Cutter .............................................................................................................3-16

Figure 3-8: Results of Super Jet Cutting on Tubing ...................................................................3-17

Figure 3-9: Severing Tool and Pipe After Severing Tool Used on It ...........................................3-19

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October 18, 2000 Page 3-3

Figure 3-10: Mechanical Internal Cutter...................................................................................3-20

List of Tables

Table 3-1: Advantages and Disadvantages of Chemical Cutters ................................................3-14

Table 3-2: How The Shaped Charge Works.............................................................................3-18

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October 18, 2000 Page 3-5

IntroductionThis section discusses retrieval of damaged or broken pipe from the borehole.

Most jobs require that the damaged pipe be separated from the rest of the pipe in thewell before it is recovered. In some cases the pipe must be cut while in the well.There are special tools that are appropriate for specific conditions inside the well. Itis important to select the appropriate tool/method before attempting to recover anydamaged pipe.

The three basic methods for separating damaged pipe in the wellbore (backoff, jet cut,and chemical cut) are illustrated in Figure 3-1.

Backoff Jet Cut Chemical Cut

Figure 3-1: Pipe Separation Methods

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Page 3-6 October 18, 2000

There are at least eight different methods used for parting pipe as listed below.

• Blind back-off (page 3-10)

• Controlled back-off (string shot) (page 3-13)

• Chemical cutter (page 3-14)

• Jet cutter (page 3-15)

• Severing tool (page 3-19)

• Radial cutting torch

• Mechanical cutters

• Reversing tool

FormulasThere are several formulas that may be used to determine the estimated free-point forstuck pipe. Following are each of the formulas and examples.

Stretch FormulaAny coupled Pipe..................................K = 1.4 ÷ weight of pipe per foot

Integral Joint tubing or drill pipe..............K = 1.5 ÷ weight of pipe per foot

Pipe Freelpul free of poundsK

stretchin inches =×

×000,000,1

Equation 3-1: Stretch Formula

Example:

Packer set at 8,000-ft. with 2-3/8-in. N80 tubing

The string weight is 37,600, mark the pipe with yellow chalk

Pull 20,000lbs over (57,600lbs) and mark again with yellow chalk

Measure the distance between the first and second yellow chalk marks

20,000lbs over pull; had 48-in. of stretch

1.4 ÷ 4.7 = .2978 (K)

FreePipex

x059,8

5956

000,000,48

000,202978.0

"48000,000,1 ==

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October 18, 2000 Page 3-7

Tapered StringMeasure stretch in inches with the following over-pulls:

2-7/8-in. DP = 25,000 lbs.

3-1/2-in. DP = 30,000 lbs.

4-1/2-in. DP = 35,000 lbs.

5-in. DP = 40,000 lbs.

−+

××=

1

21

2 1294,735

...ww

LP

wePSE

Equation 3-2: Tapered String

Where:

L1 = Length of big pipe ( above liner )

L2 = Length of small pipe ( in or below liner)

W1 = Plain end weight of big drill pipe (without tool joint)

W2 = Plain end weight of small drill pipe (without tool joint)

e = Stretch in inches

P = Over pull

Example Estimated Stuck Point (ESP)

What is the estimated stuck point for this tapered string?

Given:

L1 = 10,000-ft.

L2 = 2,200-ft.

Plain end W1 = 17.93 lbs/ft (5-in. x 19.5 lbs)

Plain end W2 = 12.31 lbs/ft (3-1/2 x 13.30)

Stretch = 41-in.

Over pull = 40,000 lbs.

If E.S.P.>L1 Stuck point is in or below L2

If E.S.P.<L1 Stuck point is in the upper string and the formula ( method 2 ) shouldbe used and the estimated stuck point recalculated.

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Page 3-8 October 18, 2000

.412,1293.1731.121000,10

000,4031.1241294,735 ftESP −=

−+××=

Since ESP ( 12,412 ) is > L1 (10,000 ), stuck point is at or below L2. This pipe isstuck in the BHA. The number 735,294 is a fixed constant.

Method No. 2

P

WeESP dp××

=294,735

Equation 3-3: Method Number two

Where:

e = Stretch

Wdp = Plain end weight of drillpipe (without tool joint)

P = Over pull

Example

What is the estimated stuck point for this non-tapered drill string?

Given:

Drill Pipe = 12,500-ft. of 5-in., 19.5 lb/ft plain end (tube) wt. = 17.93 lb/ft

Stretch = 38-in.

Over pull = 40,000 lbs.

.525,12000,40

93.1738294,735ftESP −=××=

This number indicates that the pipe is stuck in the BHA. If circulation is possible, spota pipe releasing agent such as Black Magic.

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October 18, 2000 Page 3-9

Calculations for Free Point in Stuck Drill PipeSingle or Tapered Strings

Enter the Information in the Red cells below, an estimatedfree point will be calculated

Stretch in inches 41 Measure Stretch in Inches

Overpull in Pounds 40,000 the Following Overpull(s)

Length of Larger Drill Pipe 10,000

Length of Smaller Drill Pipe 2,200 2-7/8" DP 25,000.00

Plain-end weight of Larger Drill Pipe 17.93 3-1/2" DP 30,000.00

Plain-end weight of Smaller Drill Pipe 12.31 4-1/2" DP 35,000.00

Weight per/ft w / tool jt. on single string Drill Pipe 19.5 5" DP 40,000.00

EFP = Estimated Free Point EFP

13,325 Use the following Weights

For Drill Pipe

EFP Plain End W / Tool Jt.

Method #2 single string of drill pipe 13,513 2-7/8" DP 9.72 10.40

3-1/2" DP 12.31 13.30EFP 3-1/2" DP 14.63 15.50

Method #3 Tapered String Larger / Smaller DrillPipe

12,412 4" DP 12.93 14.00

4" DP 14.69 15.704-1/2" DP 14.96 16.60

4-1/2" DP 18.69 20.00Note: If Stuck point is Less than the length of Larger Drill Pipe usethe answer from Method #1 or #2

5" DP 17.93 19.50

Figure 3-2: Excel Spreadsheet for Free Point in Stuck Drill Pipe

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Page 3-10 October 18, 2000

Blind BackoffA blind backoff is a backoff made without any idea where the fish is.

WARNING

Blind backoff operations are dangerous. All unnecessarypersonnel should be encouraged to vacate the rig floor until thebackoff operation is complete.

1. Tighten the workstring to the right before making a blind backoff.

2. Determine the amount of weight down to where the back-off will be made.

3. Mark the pipe with chalk at the point at which the correct weight is shown on theindicator. This will be the neutral point, and as you tighten the pipe to the right.Work to 20,000 lbs above and below this weight.

4. Depending on the size and type of pipe to be backed off, tighten the pipe up usingthe following chart as a guide.

Freepoint Tighten Back-off

Tubing 1/2 to 1 Rd. 1 to 1-1/2 Rd. 3/4 to 1-1/4 Rd.

Drill Pipe 1 Rd. 3/4 to 1 Rd. 1/2 to 3/4 Rd.

Casing 1/8 to 1/4 Rd. 1/4 to 1/2 Rd. 1/8 to 1/4 Rd.

5. After the pipe has been tightened, work the required torque to the left downincrementally one round at the time.

6. Use a long snub line on the tongs and work the string up from the neutral pointuntil it breaks. Do not slack off below the neutral point and do not exceed thetorque limit for the pipe you are attempting to back-off.

Free Point IndicatorA free point indicator is an electronic strain gauge run on a single conductor cable. Itis used to measure the amount of torque or stretch in a string of stuck pipe. The tool isanchored to the pipe ID at two fixed points by either bow springs, dogs or magnets.

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October 18, 2000 Page 3-11

When stretch or torque is applied at the surface, the gauge electronically transmitsthis information to the surface via the wireline. Following are the five requirements fora successful back-off:

• The connection to be backed off must be free.

• The correct amount of left hand torque is needed.

• The connection being shot must be at neutral weight.

• The proper size string shot is required.

• The shot must be across the tool joint when fired.

A string shot can be run in combination with the free point tool and usually will notdamage the connection. It can be run in a smaller ID than cutters.

A string shot can be used for an outside back-off, as a jar shot, such as to jar a testplug out of a well head, knock nozzles out of a bit, or to knock plastic and corrosionoff the ID of pipe prior to making a chemical cut.

An inside-outside back-off collar is run above an overshot and the overshot isattached to a plugged fish. A 35-ft. long string shot is deflected to the outside of thefish and fired. The plugged fish is retrieved.

Avoid pulling pipe into the wall/ free point with torque (Figure 3-3).

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Page 3-12 October 18, 2000

Pipe sticking here whilefree pointing withstretch, appears jars notworking below

Fishing Jars

Bumper Sub

Stuck Point

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October 18, 2000 Page 3-13

String Shot BackoffA string shot backoff is the process of unscrewing a tool joint or coupling withexplosives at a predetermined depth. The string shot is the primacord and blasting capthat is used to perform the backoff. The string shot backoff method uses the followingsteps to loosen the stuck pipe.

1. Apply left hand torque to a string of stuck pipe

2. Run the collar locator above the shot to locate the connection to be backed off

3. Detonate the shot across a free connection creating a backoff

Where to Backoff?It is important to figure out where to backoff. Performing a backoff in the wronglocation can be a costly mistake.

Do you intend to fish the well?

No – Backoff as deep as possible

Yes - At least one free joint above stuck point

Two free joints above a key seat

100 feet below a casing seat

Not immediately below a dog leg or a drop of angle

Shot Chart Example

Grains Per Foot

Mud 5000-ft 10000-ft 15000-ft

4-1/2 10 200 300 350

14 300 350 400

18 300 350 400

Figure 3-4: Shot String Example

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Page 3-14 October 18, 2000

Pup JointsPup joints are used when working with a wireline. Using Pup Joints has a number ofbenefits, including:

• supplied in a variety of lengths

• easier working at rotary rather than 20-ft. in air

• saves operator time and money

• promotes safe work environment

Figure the top of the fish and determine the number and lengths of pup jointsnecessary to be able to work the toolstring as close to the rotary as possible.

Chemical CutterA chemical cutter is the preferred method for parting tubing because it does not flarethe top. You must have fluid in the hole or the cutter will try to jump up the hole.Apply a 10,000 pound up strain on the tubing prior to firing the cutter. Parting the pipewith a chemical cutter is successful approximately 85% of the time. The advantagesand disadvantages of chemical cutters are listed in Table 3-1.

Table 3-1: Advantages and Disadvantages of Chemical Cutters

Chemical Cutter

Advantages Disadvantages

Flare Free Fish Heavy Mud Can Cause Problems

Leaves No Debris Limitations on Depth

Will not Damage Adjacent String Slips Can Punch Through Corroded Tubing

The chemical cutter works when an igniter initiates the gas generator grain causingthe gas pressure to set the slips. As the pressure increases, the seal disc cylinder isruptured releasing bromine Trifluoride which is forced through the catalyst and reactswith the oil igniting the steel wool. The combination of the chemical and reactantcauses the temperature and pressure to increase inside the cylinder. When theinternal pressure exceeds the hydraulic well pressure, a piston is pushed down,forcing the activated chemical out of the cutting head orifices at a high pressuresevering the tubing. The pressure then equalizes and the slips retract. The cutter isnow ready to be removed from the well. An example of a chemical cutter and pipesevered with a chemical cutter is shown in Figure 3-5. Examples of chemically cutpipe are shown in Figure 3-6.

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October 18, 2000 Page 3-15

Figure 3-5: Chemical Cutter and Severed Pipe

Figure 3-6: Examples of Chemically Cut Pipe

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Page 3-16 October 18, 2000

Jet Cutters

Figure 3-7: Jet Cutter

Jet cutters (Figure 3-7) are used when a back-off or chemical cutter is not anoption or they have been tried unsuccessfully. Jet cutters are used mostly forplug and abandonment work because they may damage the pipe. The topmay be badly flared as shown in Figure 3-8. Some of the features of jetcutters are listed below.

• available in sizes 1.156- to 12-in. OD to Cut 1.660- to 13.375-in. tubulars

• works on the shaped charge principle

• used to cut corroded tubing

• leaves a slightly flared fish

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October 18, 2000 Page 3-17

Super Jet CutterThe super jet cutter works on the same shaped charge principal as the jet cutter butuses more explosives. This cutter is used for passing through restrictions, cuttingthick wall tubulars, cutting deeper and under higher hydrostatic pressure. The superjet cutter damages the tublars as shown in Figure 3-8 and is used mostly for “plug andabandon” jobs.

Figure 3-8: Results of Super Jet Cutting on Tubing

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Page 3-18 October 18, 2000

Shaped ChargesTable 3-2 shows how the shaped charge fires and what happens in the wellbore asthe gasses expand.

Table 3-2: How The Shaped Charge Works

Shaped charges are made of high explosives (HMX or RDX) which are pressed intoa configuration that has an open end and an apex. This creates a cavity whichforms a “V”. This “V” is lined with copper.

It is detonated by a primer which runs through the center of the charge. The chargedetonates away from the center at a rate of 22,000 to 25,000 ft. per second. Thisgenerates pressures of approximately 5,000,000 psi.

The high pressure generated exceeds the yield strength of the dense metal linercollapsing at the apex. The metal liner forms a small high speed jet which is drivenby explosives that travel at 22,000 to 25,000 ft per second.

The liner material impact on the pipe exceeds the yield strength of the pipe causingthe pipe material to behave like a fluid.

Elements of the jet are consumed as the hole depth increases.

The width of the perforation or the cut area are larger than the diameter of the metaljet. The flare caused by a perforation or a jet cut is a result of the gas pressuregenerated by the explosion mechanically flaring the tubing.

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October 18, 2000 Page 3-19

Severing ToolThe severing tool (Figure 3-9) is used for drill pipe, heavy-weight drill pipe, and drillcollars. It will cut wall thickness in excess of 0.010-in. that conventional cutterscannot sever and is able to go through small restrictions. This tool should only be usedin openhole environments.

This tool is available in sizes ranging from 1-3/8-in. to 2-5/8-in. outside diameter.

A 2-5/8-in tool will sever up to 11-in. OD drill collars. This tool is used mostly as a P& A because it badly flares and splits the pipe. Flaring and splitting makes fishingeither impossible or very difficult. The tool should be fired in the tool joint, splitting thetool joint pin. If the shot if fired in the tube, it only swells or balloons the tube andwon’t break the tool joint. This tool will sever 11-in. drill collars. Take a 20,000-lboverpull before firing the tool.

Figure 3-9: Severing Tool and Pipe After Severing Tool Used on It

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Page 3-20 October 18, 2000

Internal Mechanical CutterInternal mechanical cutters are cost effective when used for making shallow cuts orused in large OD tubulars. These cutters can be used to cut and retrieve in a singletrip. Internal mechanical cutters are useful in environments where conditions are notsuitable for wireline operations

Figure 3-10: Mechanical Internal Cutter

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October 18, 2000 Page 3-21

Operating Procedures For Internal Cutters

Use the following procedures as a guide for using the internal mechanical cutter.

1. At the desired cutting depth, anchor the cutter by slow right hand rotation whileslowly lowering the workstring.

2. The wiper blocks will resist rotation and disengage the automatic bottom.

3. Continued lowering of the string causes the cone to move the slips and anchor thecutter in the pipe.

4. The knife block forces the knives to start the cut.

5. Cut the casing by slow rotation in low gear at idle speed.

6. Apply just enough weight to feed the knives, approximately 1,000 pounds.

7. As the knives cut into the fish, it will be necessary to lower the cutter slightly tomaintain the original 1,000-lb weight1.

8. When cut is made you will probably note a decrease in torque.

9. After pulling out of the hole, check the knives for signs of having made a cut.

1 A good way to apply a given amount of weight on the knives is to run one drill collar and a bumper sub above the cutter.

The free travel in the bumper sub will maintain constant weight.

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Page 3-22 October 18, 2000

Notes:

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October 18, 2000 Page 4-1

Fishing Best Practices Manual

Open Hole Fishing

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

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Page 4-2 October 18, 2000

Contents

Introduction........................................................................................................................4-5

Stuck Pipe Conditions .......................................................................................................4-10

Running Wash-pipe .......................................................................................................4-10

Shoe Selection ..........................................................................................................4-14

Differential Sticking ......................................................................................................4-17

Differential Sticking Force .........................................................................................4-19

Sticking Prevention....................................................................................................4-21

Key Seat Sticking .........................................................................................................4-21

Key Seat Sticking .........................................................................................................4-22

Bowen Surface Jars..................................................................................................4-24

Sloughing Shale or Hole Cave – In.................................................................................4-25

Signs that the hole is still sloughing..............................................................................4-25

Solution.................................................................................................................4-26

Blowout Sticking.......................................................................................................4-26

Under Gauge Hole Sticking........................................................................................4-27

Lost Circulation Sticking............................................................................................4-27

Mechanical Sticking ..................................................................................................4-28

Other Fishing Options ................................................................................................4-28

Economics of Fishing ....................................................................................................4-31

Actual Job Example ...............................................................................................4-32

Before Leaving the Well Site .....................................................................................4-32

Notes:..............................................................................................................................4-33

List of Figures

Figure 4-1: Determine the Operation at Time of Sticking.............................................................4-5

Figure 4-2: Rotating Operation Flow Chart.................................................................................4-6

Figure 4-3: Trip In Hole (TIH) Operation...................................................................................4-7

Figure 4-4: Tripping Out Of the Hole (or POOH) Operation .......................................................4-8

Figure 4-5: Static Flow Chart ....................................................................................................4-9

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October 18, 2000 Page 4-3

Figure 4-6: Washpipe Diameter Illustration ..............................................................................4-11

Figure 4-7: Kick Pad Welded on Shoe .....................................................................................4-13

Figure 4-8: Wash-over Assembly (with safety joint) .................................................................4-14

Figure 4-9: Example Rotary Shoe Designs From the Same Job..................................................4-15

Figure 4-10: Example of Differential Sticking ...........................................................................4-18

Figure 4-11: Differential Sticking Force Spread Sheet (Microsoft Excel).................................4-20

Figure 4-12: Single and Double Clutch Keyseat Wipers ............................................................4-23

Figure 4-13: Mechanical Sticking Examples .............................................................................4-28

List of Tables

Table 4-1: Weatherford Rotary Shoes .....................................................................................4-16

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Page 4-4 October 18, 2000

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October 18, 2000 Page 4-5

IntroductionOpen hole fishing can be complicated by many parameters of the formation. Severaldecision making flowcharts have been provided illustrating the decision makingprocess for open hole fishing. The chart in Figure 4-1 leads to the charts on thefollowing pages. Use the chart in Figure 4-1 to determine which chart to use next.

Operation at the time the drillstring

became stuck.

Rotating TIH POOH Static

Go to Drilling chart.

Go to TIH chart.

Go to POOH chart.

Go to making connection chart.

Drillstring has become stuck

Figure 4-1: Determine the Operation at Time of Sticking

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Page 4-6 October 18, 2000

Is downhole motion possible?

Is pipe rotation restricted?

Rotating

Wellbore geometry

Wellbore geometryBridge Packoff, Wellbore geometry

Is circulation restricted?

Yes

No

Yes

No

No

Figure 4-2: Rotating Operation Flow Chart

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October 18, 2000 Page 4-7

is downhole motion possible?

Is pipe rotation restricted?

Tripping In

Wellbore geometry

Wellbore geometryBridge Packoff, Wellbore geometry

Is circulation restricted?

Yes

No

Yes

No

No

Figure 4-3: Trip In Hole (TIH) Operation

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Page 4-8 October 18, 2000

Is Down Motion Possible?

Is pipe rotation

restricted?

Is Pipe Rotation Restricted

is circulation restricted? Is circulation

restricted?Is circulation

restricted?

Wellbore geometry

bridge packoff Wellbore geometry

Wellbore geometry

Bridge packoff Wellbore Geometry

Wellbore geometry

Tripping Out

No

No

No

Yes

Yes

Yes

Yes

No

No No

No

Figure 4-4: Tripping Out Of the Hole (or POOH) Operation

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October 18, 2000 Page 4-9

Static

Is down motion

possible?

Is pipe rotration

restricted?

Is pipe rotation

restricted?

Is circulation restricted?

Is circulation restricted?

Is circulation restricted?

Is circulation restricted?

Differential wellbore geometry

Differential wellbore geometry

Bridge Packoff Wellbore geometry

Differential

Bridge Packoff

Differential wellbore geometry

NoYes

Yes

Yes

Yes

Yes

Yes

No

No No No

No

YesNo

Figure 4-5: Static Flow Chart

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Page 4-10 October 18, 2000

Stuck Pipe ConditionsIt is critical to correctly identify what caused the pipe to stick before any fishingoperation is started.

The first item to determine is; what was the operation being performed when the pipebecame stuck.

Once you determine what operation was being performed at the time the pipe becamestuck the next thing do determine is if you can circulate. Jarring is rarely successful ifthe hole cannot be circulated. A formation can be mechanically squeezed byattempting to jar through a tight spot if the hole cannot be circulated. If, however, youcan circulate, even at a reduced rate, jarring might be an option. If the borehole ispacked off completely, success of jarring is greatly diminished. Wash over is theoption that will work.

The next thing to find out is, why is the pipe stuck? The answer to that question willlead to the solution.

In all cases, identify the problem before taking any action. If you determine there is ahole or mud problem, fix that before running fishing tools into the borehole and gettingthem stuck.

Running Wash-pipePrior to running wash pipe in a sloughing shale situation, it is important to first make abit trip to condition the mud and hole. Run a short string of wash pipe, approximately300-ft, of the minimum size that will cover the fish and still provide adequate room forcirculation. The preferred ID clearance is 1/4-in. and the preferred OD clearance is1/2-in. Local custom, hole conditions and clearance will help determine the length ofwash pipe to run. Shoe design should cut maximum clearance for the wash-pipe. TheOD should be 1/8- to 1/4-in less than hole size Figure 4-6. An example of a wash-over assembly is shown in Figure 4-8.

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October 18, 2000 Page 4-11

1 /4”

H o l e D i a m e t e r

M a x i m u mW a s h p i p eD i a m e t e r

Figure 4-6: Washpipe Diameter Illustration

Perform the following steps to run the wash-pipe into the wellbore.

1. Look through the wash-pipe before picking it up as there may be an old fish orother debris lodged in the wash-pipe.

2. Personally check the OD and ID with a set of calipers to insure that the wash-pipe is the correct size, also measure the length of the washpipe.

3. Use chain tongs to make the pipe up, then tighten to the proper torque with the rigtongs.

4. Run a safety joint, jars and drill collars above the wash-pipe.

5. Trip the wash-pipe in the hole slowly to avoid pressure surges that may breakdown the formation.

CAUTION: Pull out of the hole SLOWLY, otherwise you may swab the hole.

6. When you are near the top of fish, break circulation, and record all parametersprior to going over the fish.

7. Get over the fish with the kelly out of the hole so you won’t have to pull off it tomake a connection.

CAUTION: Wash-over pipe is easy to stick differentially. Keep the pipe moving at all times andinsure the rig controls are not left unattended.

8. Inspect the boxes and pins during trips and change out any pipe that shows ANYsigns of damage.

You may run feeler pins in the shoe to help determine when you are over the topof the fish. Use kick pads in the shoes if you are having trouble getting past tooljoints that are embedded in the wall.

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Page 4-12 October 18, 2000

9. Circulate a few minutes before making a connection.

10. After wash-over is complete, circulate bottom’s up before threading into the fish.

Note: If the Wash Over Back Off (WOBO) tool is being used, go slow the lastfew feet to allow time for the hole to clean up.

Remember to take care of the borehole you have before attempting to fishdeeper.

Should you encounter excessive torque off bottom, look for crooked pipe or thefish may simply be too large for the wash-pipe to cover. Pull out of the hole.

11. Make a back-off to recover what has been washed over thus far, then continue towash-over with a shorter string of wash-pipe. If excessive pump pressure isencountered, watch for swollen shale.

12. Begin lowering the water loss and proceed slowly.

Note: Make sure the hands keep the tongs away from the boxes to preventmashing them. Use the true circle tong bushings to break out wash-pipe that hasbeen over torqued if you are mashing any joints while breaking them out. Do useprotectors on all exposed wash-pipe threads and pick up nubbins.

An example of a “kick pad” welded inside of a rotary shoe is shown in Figure 4-7.

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October 18, 2000 Page 4-13

K i c k p a d w e l d e d t o t h ei n s i d e o f t h e s h o e

Figure 4-7: Kick Pad Welded on Shoe

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Page 4-14 October 18, 2000

Washover backoff safety joint

Washover pipe

Rotary Shoe

Figure 4-8: Wash-over Assembly (with safety joint)

Shoe SelectionRotary shoe selection and design is critically important to the success of a washoverjob. Different types of shoes perform best in different circumstances. Table 4-1 listssome of the rotary shoes available from Weatherford and their uses. The followingare general shoe categories:

• Short tooth or ocean wave shoes are used in medium and hard formations

• Longer toothed shoes are used in soft formations

• Flat bottom or ocean wave shoes are used to cut stabilizers, reamers, and tooljoints.

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October 18, 2000 Page 4-15

Figure 4-9 shows two rotary shoes of differing design that were used on the same job.The shoe on the left performed much better in the environment as noted in the figure.Shoe design MUST match the environment that it is to be used in.

T h i s s h o e o n l y c u t 6 6 f e e t o f c e m e n t e do v e r d r i l l p i p e o n t h e s a m e j o b a s t h a ton the le f t .N o t i c e t h a t t h e i n s i d e i s w o r n s m o o t ha n d t h e s i z e o f t h e r o d i s s m a l l e r t h a ntha t on the l e f t .

T h i s s h o e c u t 2 6 6 f e e t o f c e m e n t e d o v e rd r i l l p ipe .T h i s s h o e i s c o u n t e r b o r e d . Y o u c a n u s e ab i g g e r c a r b i d e r o d o n t h e i n s i d e w h e n t h es h o e i s c o u n t e r b o r e d .

Figure 4-9: Example Rotary Shoe Designs From the Same Job

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Page 4-16 October 18, 2000

Table 4-1: Weatherford Rotary Shoes

Type Description Type Description

A

This is a drag type shoe usedto cut soft formation , or whenrunning weak string. It cutson the bottom only.

H

This shoe is used to size anddress the top of the fishinside the casing. It makes atapered cut on the fishwithout damaging the casing.It cuts on the ID of the bottomonly.

B

The type B is a low torquetype shoe and used insidecasing to wash over and cuton the bottom only to avoiddamage to the casing or thefish.

I

The type I is used in openhole for washing over andcutting formation, metal, orcement with limited insideclearance. It cuts on the ID,the OD, and on the bottom.

C

This shoe is used to cutmetal on the fish withoutdamaging the casing. It cutson the bottom and on the IDonly

J

This shoe is used to cutmetal on the fish with nodamages to the casing. Theshoe cuts only on the ID andon the bottom.

D

This shoe is used in openhole for washing over andcutting metal and cementwith limited insideclearances. It cuts on thebottom and OD.

K

The Type K is used forwashing over and cuttingformation only. The shoecuts on the OD and bottomonly.

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October 18, 2000 Page 4-17

Type Description Type Description

E

The type E is used forwashing over and cuttingmetal, formation, or cement.It cuts freely on the ID, OD,and bottom.

L

This shoe is used for washingover and cutting formationonly. It cuts on the bottom,not on the ID or OD.

F

This shoe cuts metal on thefish without damaging thecasing because it does notcut ton the OD. This typecuts on the ID and on thebottom.

M

The type M is used insidecasing for washing over andcutting on the bottom only. Itdoes not cut on the OD orOD.

G

The type G is used in openhole with limited outsideclearance to cut metal orcement and a limited amountof formation without damagingthe fish. It cuts on the ODand bottom only.

N

The type N is a low torquetype shoe used for cuttingmetal, formation, or cement inan open hole. It cuts freelyon the ID, OD, and bottom.

Differential StickingDifferential sticking most commonly occurs when the pipe becomes embedded in thefilter cake opposite a permeable zone. Differential sticking intensifies with anincrease in wall cake thickness.

If the string sticks when the pipe is not moving, such as during a connection, you areprobably differentially stuck or what is commonly called “wall stuck”. If circulation isnot affected, but the string will not rotate or move in either direction, the string isprobably differentially stuck. The bottom hole assembly is probably stuck because ofdifferential pressure. The bottom hole assembly is likely held in place by the hydraulic

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Page 4-18 October 18, 2000

force of the hydrostatic weight of the mud. The hydraulic force holding the string iscommonly over 1,000,000 pounds. Ask the following questions to determine if thestring is differentially stuck.

• Did the string stick after remaining static in the hole?

• Will the mud circulate?

• Is there permeable formation above the bit?

Use the following steps to release a differentially stuck pipe

1. Apply torque and jar down if jars are in the hole and working. If there are no jarsor if the jars are not working, apply torque and stack out.

2. Spot a pipe releasing pill ASAP.

3. Determine what pills work best in this area?

4. Unless a releasing pill is spotted and/or the mud weight can be lowered, jarring israrely successful.

An example of differential sticking is shown in Figure 4-10.

Figure 4-10: Example of Differential Sticking

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October 18, 2000 Page 4-19

Differential Sticking ForceThe following information is inserted in the spreadsheet shown in Figure 4-11.

Hole size = 8.125-in.

Drill Collar Diameter = 6.5-in.

Assumed Imbedment = .25-in.

Assumed Stuck Length = 20-ft.

Formation Pressure = 4650 PSI

Depth = 10,000-ft.

Mud Weight = 10.5 Lbs./Gal.

Differential Pressure = 804 PSI

Sticking Force = 1,002,974 pounds of force into the wall

The Excel spreadsheet (Figure 4-11) calculates the sticking force based on severalcriteria. Changes in mud weight for instance, have a dramatic effect on the stickingforce.

Enter or change the data in the yellow cells. The red cells change according to theinputs in the yellow cells.

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Page 4-20 October 18, 2000

Inputs:

Drill Collar Diameter (inches) 6.5

Stuck Length (inches) 240

Imbedment (inches) 0.25

Hole Size (inches) 8.125

Calculations:

Hole Radius = (b) 4.0625

Drill Collar Radius = (a) 3.25

Imbedment 0.25

Center Offset = (c) 1.0625

Total Drill Collar Surface Area: 4901 sq. inches

Contact Area: 1247 sq. inches

Differential Pressure Inputs:

Mud Weight: 10.5 lb/gal

Formation Pressure: 4650 psi

Depth: 10000 ft

Differential Pressure Calculations:

Hydrostatic Pressure: 5454 psi Note: A negative number denotes

Differential Pressure: 804 psi higher formation pressure than

hydrostatic pressure

Differential Sticking Force Calculations:

Sticking Force: 1,002,974 lbs force into the wall of the wellbore

Figure 4-11: Differential Sticking Force Spread Sheet (Microsoft Excel)

By reducing the mud weight to 9.5lb/gal, the differential pressure is reduced to 285psiand the sticking force is reduced to 355,000lb. There is a good chance the fish can bejarred free. The impact load of the jars can be manipulated to exceed the stickingforce.

Angle "A" Angle "C"

Angle "B"

Instructions:Input well information intoYELLOW cells. The REDcells calculate automatically.

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October 18, 2000 Page 4-21

Sticking PreventionThe following operating parameters help to prevent differential sticking:

• maintaining minimum mud weight that will control the well

• keeping the string moving at all times; rotate the pipe slowly while makingconnections

• reducing wall contact by using spiral drill collars and heavy-weight drill pipe

• making daily short wiper trips

Key Seat StickingIf the string gets stuck while moving up, there is a good chance it is stuck in a keyseat. A key seat develops when the drill pipe in tension wears a slot (key seat) in thewall of the hole. This occurs when the hole deviates from true vertical, whethercontrolled or otherwise. As a key seat forms, it usually gives warning signs, such asencountering drag while pulling out of the hole.

Drillers must pay close attention to the information that the well is supplying.

When a key seat develops, it should be wiped out with a key seat wiper or stringreamer before it sticks the string. The bottom hole assembly usually sticks when anOD enlargement, such as the drill collars, try to enter the key seat. You will be able torotate, circulate, and work the pipe down, but it will not come up and pass through thekey seat. If the rig is equipped with a top drive, you must back ream the pipe out ofthe hole in very small increments, otherwise you must do so with the rotary slips.

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Page 4-22 October 18, 2000

Key Seat Sticking

• Drill Pipe in tension wears a groove in the sideof the borehole. This occurs when the welldeviates from true vertical, whether controlledor not.

• The groove is not large enough to allow drillcollars to be pulled through it.

• If the pipe was moving up when it becamestuck, and the mud will still circulate, its stuckin a key seat.

• Freepoint with torque and stretch.

• A stuck pipe log will show the pipe stuck in a shortinterval

• A back off should be made two to three jointsabove the stuck point.

Cross Section

Key Seat

Top View

Main Bore Hole

• Good application for a drill collar spear.

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October 18, 2000 Page 4-23

Single Clutch

D r e s s t h e s l e e v e s t o½ - i n . g r e a t e r t h a nthe d r i l l co l l a r s used( r e c o m m e n d e d ) .

Double Clutch

Figure 4-12: Single and Double Clutch Keyseat Wipers

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Page 4-24 October 18, 2000

Bowen Surface JarsThe Bowen surface jar is often used to free key-seated drill pipe and drill collars.The jar is designed to be installed at the surface and permits the operator to deliversharp downward blows against the fish. The Surface Jar is also used for transmittingheavy downward blows to release grappling tools which have become imbedded inthe fish.

The jar has a 48-in. stroke and is preset by Bowen to trip with a 30,000 pound overpull. The tripping load of the jar can be adjusted with a special wrench by turning thecontrol ring to the right for more tonnage or to the left for less.

The jar can be picked up below the Kelly to allow for circulation, or attached to drillpipe or a drill collar. 300 to 400 pounds of weight is needed above the jar to re-cock it.Start jarring with a light tripping load. Do not set the tripping load higher than theestimated weight of the free pipe to avoid pulling the fish tighter into the key seat.

CAUTION: Always get permission from the company man or tool pusher before attaching a jarto a top drive. Because of the way the jar works, it may damage a top drivenecessitating expensive repairs.

The jar is not very effective below about 3,500 feet because of friction.

Perform the following steps using the Bowen surface jars to free a key seat stuckpipe.

1. If the fish cannot be knocked out of the key seat, make a back-off leaving twofree joints.

2. Run a screw in sub with a long stroke bumper jar to aid in freeing the fish.

3. Hit the bumper jar only a few times, as you could part the string below thebumper sub. If this doesn’t work, a wash over job using the drill collar spear isrecommended.

4. Make a back-off leaving two free joints and run a short string of wash pipe. Thekey seat usually will not be over 30-ft. in length.

Note: Leave the surface jar in the open position before sending it in for service.

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October 18, 2000 Page 4-25

Sloughing Shale or Hole Cave – In

Drill Collars

Hole fell infrom formationabove

Drill Pipe

The sloughing shale condition typically occurs immediatelybelow a cavity and is usually caused by poor filter cake.

If the drill string becomes stuck and the hole is packed offso that circulation is either greatly reduced or is notpresent at all, the cause is probably sloughing shale.Sloughing shale usually takes place near the bottom(newest hole) and isn’t related to hydration or overexposure. For example, a driller picks-up to make aconnection and after picking-up a new joint, he cannotengage the Kelly drive bushing because the bottom of thehole is filled with sloughing shale. This shale isn’t overexposed but simply loses stability because the trappedwater is pressured in the shale and keeps the shale matrixfrom compacting and gaining rock strength. Sloughingshale is very common in shale transition zones. Theeffects can be minimized if the mud weight is adjusted towhat the formation pore pressure is in the shale. Once ashale sloughs the driller has to exercise patience until thesloughing is complete. How long a shale sloughs in aparticular section is unpredictable. You must keepreaming the hole until the bit can be lowered with outdown-drag or hole-fill. The driller must be sure to keep theproblem below him, in other words, don’t drill ahead untilhole stability is gained. Hole cleaning requires viscous pillswith a high yield point, and sometimes weighted pills tounload the large pieces and volume of shale. A mudweight increase and water loss reduction at this point onlyhelp to clean the hole.

Signs that the hole is still sloughingThe following are signs that the hole is still slogging.

• Can’t slack the bit off without the rotary and without the pump

• The pipe won’t go down without circulating and rotating

• Observe shale shaker for additional shale being produced from the hole

• Pump pressure increases and looses one or two pump strokes

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Page 4-26 October 18, 2000

Solution

Perform the following corrective actions to condition the hole so that drillingoperations may continue.

• Introduce high viscous pills and or weighted pills into the borehole

• Circulate and continue to ream

• Make a bit trip

• Lower the water loss and raise the mud weight just enough to hold the shaleback.

Note: In some parts of the world (Norway for example) you must havegovernment approval to change the mud weight.

Blowout Sticking

Sand or shale packedaround tool joint

What usually occurs in a blow out sticking situation is bridging and morethan one stuck interval. A free point tool only locates the top of the stuckdrill string.

A free point will sometimes show movement and you can back off, butnot pull the pipe. Run maximum free point with maximum stretch to limitthat possibility.

A pipe recovery log (in addition to the free point tool) is usually requiredto determine the best fishing procedure. The pipe recovery log uses asonic system that sets up a vibration in the stuck pipe. The vibration,measured by a receiver, decreases at stuck intervals in proportion to theseverity of the stuck condition. The logging instrument is calibrated inknown free pipe, normally near the bottom of the last casing string.After recording, a signal attenuation scale is placed in the log. This scale,expressed in percentages, accurately indicates the severity of stuckconditions at each interval.

While the pipe recovery log has had its greatest use in stuck drill pipeand drill collars, it also has been used successfully to evaluate the stuckcondition of wash-pipe, casing, tubing and liners. The pipe recovery logwill help you to determine the most practical method of recovery.

• Free pointing should be done with caution using torque and stretch.

• Free point can show free and have some bridging of sand, shale, formation or drillpipe rubbers packed off around the drill string.

• A back off can be made and the pipe cannot be pulled.

• As in most drill pipe operations, a back off is the preferred method of parting thepipe.

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October 18, 2000 Page 4-27

Under Gauge Hole StickingIn an under gauge hole sticking situation, first determine if the under gauge holeis above or below the bit. Under gauge sticking could be caused by swollenshale or under gauge hole For example, if you got stuck running a new bit intoan under gauge hole, upward jarring is usually successful. If the under gaugehole is above the BHA because of swollen shale, the fishing procedure is thesame as for sloughing shale.

Lost Circulation Sticking

Drill Collars

Hole fell infrom formationabove

Drill PipeLoss of circulation sticking occurs when the string sticks afterloosing returns and the hole caves in. Washing over is the bestfishing option.

A differential temperature log is used to determine lost circulationzones. Fluid taken by the formation is constantly being replaced byfluid being pumped into the well. The temperature recorded downto the lost circulation zone will be cooler than the temperature ofthe formation. Below the lost circulation zone, the fluid has beenstagnant in the hole and will be at much hotter formationtemperature; therefore a distinguishable change in temperature isnoticed at the lost circulation zone.

The theft zone must be sealed off before starting any wash overoperation. This is accomplished with time and LCM.

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Page 4-28 October 18, 2000

Mechanical StickingMechanical sticking occurs when there is a foreign object, junk in the hole, orcrooked/corkscrewed pipe. Run a free point and part the pipe at the appropriateplace, then run an attachment tool with a jarring assembly that will jar up or down.

Jarring is usually successful with crooked pipe or “junk” in the borehole.

It may be necessary to jet cut the pipe and jar it out in smaller segments.

It may be necessary to wash over with a short string of wash pipe using the drill collarspear.

Crooked pipe will notallow the torque to betransmitted down thehole.

Crooked Pipe

“Junk”

“Junk” or Foreign Object

Figure 4-13: Mechanical Sticking Examples

Other Fishing OptionsMechanical failure such as: Twist off, wash out, etc. run appropriate fishing tool(usually an overshot with jarring assembly) as soon as possible

In all cases, identify the problem before taking action. If there is a hole or mudproblem, fix it before the fishing tools gets stuck. The following items must beconsidered before proceeding with a fishing job.

• Hole conditions

• Local customs

• Is the formation hard or soft

• Salt water flow - gas pockets

• Is the hole prone to key seats

• Chalk – wash-pipe won’t stick

• Local custom – 600-ft. OK

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October 18, 2000 Page 4-29

The following is information from an actual job.

FISHING & CUTTING SERVICE REPORT

WO#

STORE

CUSTOMER: Oryx Energy BY: SUPERVISOR:

DATE:2-17-97

STATE: TX COUNTY: FIELD: LEASE: WELL: SERVICE LOCATION

CHARGE TO:

ADDRESS:

ATTN:

TOTAL:

SUPERVISOR’S TIME DAYS FROM: THRU: @

CAR NO. SUPERVISOR’S AUTO MILEAGE WITH TRAILER MILES @

OPEN HOLE � CASED: � TYPE OF FISH: DEPTH O FJOB: 5572-ft

TYPE OF JOB: Fishing HOLE SIZE: 7-7/8-in. OTHER SERVICES:

CUSTOMER SIGNATURE

PRINTED NAME

TITLE

Bit stuck 61-ft off bottom @ 5511-ft. Back off inside casing @ 997-ft.

4514-ft. fish: Bit, sub, 18 DC x 6-3/8

CUSTOMER COMMENTS

Trip#1-4:00 P.M. 2=17

Trip # 1-4:00 P.M. 2-17-97

Screw in sub, jars, drill collars etc.

Jar 1 hour: string parted in jars

Trip#2 w/os: Re. jars & 1 joint

Trip#3 w/386’ 7-3/8” wash pipe

Trip#4 w/screw in: Re. 499’

Trip#5-4:P.M. 2-18

12 joints 7-3/8” W.P. = 386”

Trip#6 w/screw in: Re. 375”

Trip#7 w/21joints w.p.= 668’

Trip#8 w/screw in: Re. 622’

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Page 4-30 October 18, 2000

Trip#9-10:P.m. 2=19

19 joints = 601’

Trip#10 w/screw in: Re. 573’

Trip#11 - 21 joints = 665’

Trip#12 w/screw in: Re. 626’

Trip#13 - 21 joints = 665’

Trip#14 w/screw in: Re. 665’

Trip#15-11:a.m.2-22

21 joints = 665’

Trip # 16 w/screw in: Jar fish free

Re. 900’ Job Complete

Re. 4514’ in 7 days: Av. 644’

Cost: 7 x $6500 = $45.000

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October 18, 2000 Page 4-31

Economics of FishingSome fishing jobs can go on for months before the fish is retrieved. After a certainperiod of time, however, the cost of fishing operations and lost drilling time becomeprohibitive. Generally, once these costs reach about half the cost of sidetracking andredrilling, fishing should be abandoned.

One way to calculate the number of days that should be allowed for fishing uses thefollowing equation:

D

S

CRCV

D++=

where:

D = number of days to be allowed for fishing

V = replacement value of fish

Cs = estimated cost of sidetracking

R = daily cost of fishing tool rental and services

Cd = daily rig operating cost

Suppose a fish worth $150,000 is stuck in a well being drilled at a cost of $5,000 perday. Sidetracking would take an estimated 5 days, and therefore would cost $25,000plus $20,000 for equipment and cement for a total of $45,000. Fishing tool rental andservices cost $2,500 per day. The number of days allowed for fishing by this methodwould be calculated as follows:

$150,000 + ($5,000*5) + $20,000 = $195,000

Days26500,7$

000,195$ =

An operator should consider some fishing jobs impractical from the very start. Forexample, drill collars accidentally cemented in or engulfed in barite are nearlyimpossible to recover and not worth the cost if they are recovered. In this case, thedecision is easy to make: start sidetracking immediately. Other decisions are moredifficult because the odds of eventual success may not be known.

The cost of sidetracking, can be estimated fairly easily. It takes about 5 days to set acement plug on top of a fish and kick off the hole to bypass it. Knowing the rate ofpenetration and the length of the original hole to be bypassed, the operator canestimate the cost of drilling a new hole to reach the original total depth.

Some fishing jobs are easy; others are harder, requiring special tools and the expertiseof a fishing specialist. Even then, the best tools and procedures sometimes fail. It isvital to know everything possible about the fish and fishing conditions before startingthe job. It is equally important to know when to stop fishing and re-drill.

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Page 4-32 October 18, 2000

Actual Job Example

Fish or Sidetrack?

fish to days 3.11000,20500,6

000,150000,150 =++

The fishing job was successfully completed in seven days. Because the fishing jobwas completed early, the client company realized a savings of $113.950 calculatedbelow.

4.3 days [saved from the 11.3 days allocated] x [daily fishing costs + daily rig costs]

4.3 x $26,000 = $113.950

Important Be certain that all equipment repairs are included on the bill to the customer and thatthe company man signs off on the charges.

Before Leaving the Well SiteFor the safety of your crew, others and the equipment, make sure that all thefollowing are completed before leaving the wellsite.

• Install thread protectors on all connections

• Store the grapples in a safe place

• Break all connections on the rig

• Insure that all Weatherford tools are accounted for

• Insure that all paperwork is completed and signed by the company man

If a Weatherford tool is left onsite, there is a strong possibility that the tool will bethrown away. If some other companies’ tool is “accidently” gathered up and broughtback to the store it must be returned. The cost to return the tool may be greater thanthe tool is worth. In either case above, a feeling that the Weatherford team isincompetent or sloppy may be created jeopardizing future jobs.

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October 18, 2000 Page 5-1

Fishing Best Practices Manual

Drilling Fluids

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

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Page 5-2 October 18, 2000

Contents

Introduction........................................................................................................................5-5

Common Formation Problems..........................................................................................5-8

Reactive Formations....................................................................................................5-8

Unconsolidated Formations ..........................................................................................5-9

Over-Pressured Shale Collapse..................................................................................5-10

Mud Properties.............................................................................................................5-10

Mud Weight..............................................................................................................5-11

Shale Control Inhibitors..............................................................................................5-11

Filtrate Reducers.......................................................................................................5-12

Annular Flow/Mud Viscosity......................................................................................5-13

Advantages of Laminar Flow.....................................................................................5-13

Cuttings Removal......................................................................................................5-14

Slip Velocity of Cuttings in Ft/Sec. .............................................................................5-14

Vertical and Highly Deviated Wells................................................................................5-14

Mud Pills ......................................................................................................................5-15

Circulating Time Prior to Tripping ..................................................................................5-15

Mud Cycling Time.....................................................................................................5-16

Volume of Mud in System.........................................................................................5-16

Capacity of Hole .......................................................................................................5-16

Miscellaneous Formulas.............................................................................................5-17

Rotation and Reciprocation............................................................................................5-17

Parameters...............................................................................................................5-18

Desired Annular Velocity Formula .............................................................................5-19

Annular Volume........................................................................................................5-19

Annular Velocity in Ft./Min........................................................................................5-20

Triplex......................................................................................................................5-20

Displacement............................................................................................................5-21

Filter Cake................................................................................................................5-21

Hydrostatic Pressure.................................................................................................5-21

Buoyancy Factor.......................................................................................................5-22

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October 18, 2000 Page 5-3

Mud For Fishing Operations...........................................................................................5-23

Notes:..............................................................................................................................5-24

List of Figures

Figure 5-1: Drilling Mud Report.................................................................................................5-7

Figure 5-2: Effect of Mud Weight on Drilling Rate ...................................................................5-12

Figure 5-3: Overburden Pressure ............................................................................................5-13

Figure 5-4: BHA Drag in Lateral Cuttings beds........................................................................5-15

List of Tables

Table 5-1: Shale Control Inhibitors...........................................................................................5-11

Table 5-2: Flow Rates in Extended Reach Wells ......................................................................5-14

Table 5-3: Volume of Pills ......................................................................................................5-15

Table 5-4: Circulation Relative to Bottom’s Up Time................................................................5-15

Table 5-5: Single Acting Triplex Pump Data ............................................................................5-20

Table 5-6: Buoyancy Factor....................................................................................................5-22

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Page 5-4 October 18, 2000

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October 18, 2000 Page 5-5

IntroductionThis section discusses the use of drilling fluids and their impact on fishing operations.

Drilling fluids, or drilling muds are used to perform the following functions.

• Remove solids to surface

• Cool and lubricate the bit

• Wall the hole with filter cake

• Control subsurface pressure

• Support part weight of drill string

• Increase the rate of penetration (ROP)

• Increase bit life

• Decrease horse power required for drilling operations

• Decrease torque required for drilling

Mud for fishing has slightly differing requirements as listed below.

• Weight sufficient to maintain well control; stop shales and water flow

• Viscosity is equal to four times mud weight

• Y.P. equal to mud weight if drilling; 20 to wash over, 30 + to mill

• Water Loss in a hard formation = 10

• Unconsolidated sand = 5 or below

Insufficient hole cleaning can cause the following problems

• Excessive torque and drag

• Hole pack-off

• Stuck pipe

• Formation break down

• Slow rate of penetration

• Loss circulation

Sloughing and swelling formations are unstable formations that plastically extrude intothe hole and close around the pipe while others slough and pack off the hole.Unconsolidated sands can slough producing large, over-gauge hole sections.Fractured limestone's have boulders falling into the hole.

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Page 5-6 October 18, 2000

Shale stability is affected by the weight of the overburden, earth movement, porepressure, original stresses, angle of bedding planes, and moisture content. Shales arebrittle,“popping,” or sloughing that break up and fall into the hole.

Several mechanical phenomenon affect shale stability such as: erosion caused by highannular velocities, drill string whip breaking down the borehole wall, pressure surges,swabbing during trips in and out of the hole, and relief of internal forces (gas or waterpressure) in the formation.

Sloughing is indicated by large amounts of shale coming over the shaker at “bottomsup.”

Shales swell as the result of chemical reaction with water known as hydration. Theswelling varies from the highly reactive “gumbos” to shales that slowly hydrate. Anyswelling shale is a potential cause of stuck pipe.

Refer to the drilling mud report (Example in Figure 5-1) for specific details about mudused in the well.

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October 18, 2000 Page 5-7

Figure 5-1: Drilling Mud Report

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Page 5-8 October 18, 2000

Common Formation ProblemsThe most common formation problems are, reactive formations, unconsolidated sands,and over-pressured shales. This section will give a brief description and solution foreach problem.

Reactive Formations

Water sensitive shales absorb water andswell into the wellbore.

The reaction is time dependent because thechemical reaction takes time to occur.

Add coating polymers to water based mudsto reduce water contact to the shale.

Use an inhibited mud system to reduce thechemical attraction of the water to theshale.

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October 18, 2000 Page 5-9

Unconsolidated Formations

An unconsolidated formation falls intothe wellbore because it is loosely packedwith no bonding between particles.

The supporting rock is removed as thewell is drilled. It’s like digging a hole insand on the beach, the faster you dig,the faster the hole collapses in on itself.

Unconsolidated formations requireadequate filter cake and have low waterloss.

Add fine LCM to stop seepage and spota gel pill before pulling out of the hole.

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Page 5-10 October 18, 2000

Over-Pressured Shale CollapseOver-Pressured shale collapse hasnatural pore pressure greater than thenormal hydrostatic pressure gradient.This is caused by under-compaction,naturally removed overburden and uplift.

There are a number of problemsassociated with over-pressured shalecollapse including:

• cavings [splintery] at the shaker

• increased torque and drag

• hole fill, circulation restricted orimpossible

• increase in rate of penetration

Minimize these conditions by: usingadequate mud weight, minimizing holeexposure time, and using gas levels todetect pore pressure.

Mud PropertiesThe following terms are used when discussing drilling mud properties.

Density the weight of a substance per unit volume e.g. 10lb per gallon or 10lb/gal

Viscosity a measure of the resistance of a fluid to flow

Yield point the ability of the mud to suspend and carry cuttings to the surface

Fluid loss the escape of the liquid part [water] of a drilling mud

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October 18, 2000 Page 5-11

Mud WeightMud weight influences hole cleaning by affecting the buoyancy of the cuttings. Asmud weight increases, the cuttings tend to float out of the hole where they can beremoved. In practice, other concerns must be applied to mud weight such as wellborestability, ECD, ROP, and differential sticking.

The following compounds are used as mud weighting materials:

• Barite (Barium Sulfate)

• Calcium Chloride

• Calcium Carbonate

• Lead Sulfide Powder

Shale Control InhibitorsTable 5-1 lists compounds used to control shale in the borehole.

Table 5-1: Shale Control Inhibitors

Compound Purpose Manufacturer

Drilmul Surfactant Barium Corp.

Cyfloc Inhibitor American Cyanamid

Drispac Inhibitor Drill Specialist

Shale-trol Inhibitor Milchem

T-8 Inhibitor Magobar

Asphalt Various Companies

C0-Polymers Various Companies

Figure 5-2 shows the effects of mud weight on the drilling rate.

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Page 5-12 October 18, 2000

Figure 5-2: Effect of Mud Weight on Drilling Rate

Filtrate ReducersThe following compounds are used as mud filtrate reducers.

• Wyoming bentonite [gel]

• Pregelatinized Starch

• CMC (Sodium carboxymethyl cellulose)

• Lignitic material

• Dextrid (organic polymer)

• Driscose (Pure grade CMC)

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October 18, 2000 Page 5-13

Figure 5-3: Overburden Pressure

Annular Flow/Mud ViscosityA correctly designed laminar or turbulent flow will clean a deviated hole. Whenlaminar flow exists, increasing the viscosity/YP will improve hole cleaning propertiesof the mud. In turbulent flow, reducing the mud viscosity will help remove cuttings.

Advantages of Laminar FlowLaminar flow has a higher cleaning capacity than normal flow. Viscous fluids carrythe cuttings better in the near vertical section. Viscous mud has better suspensioncapability when the circulation is stopped. Turbulent flow is difficult to achieve inanything but small hole sizes.

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Page 5-14 October 18, 2000

Cuttings RemovalIn holes inclined less than 30°, cuttings are suspended by fluid shear properties.Cuttings beds do not form in these holes. Holes from 30° to 60° deviation are theworst for forming cuttings beds. Cuttings removal is based on the vertical slip velocityof the cuttings

Slip Velocity of Cuttings in Ft/Sec.Cuttings fall back through fluid at the rate determined by the following equation.

( )W

WWD −1

Where:

D = diameter of cuttings

W = density of fluid Lbs./Gal.

W1 = Weight per gallon of cuttings

Weight of steel = 65.14 PPG

Weight of water = 8.34 PPG

Example

( )34.8

34.844.65250. − =

34.8

275.14 = 7116.1 = 1.3082

1.3082 x 60 = 78.49 rounded off to 80 Ft./Min.

1-1/2 times slip rate = Circ. rate of 120 Ft./Min.

Vertical and Highly Deviated WellsIn a vertical well, if the flow rate is greater than the slip velocity rate, the hole iscleaned by the mud circulation. In highly deviated wells, cuttings fall to the low sideof the hole forming beds of cuttings that are difficult to remove. Maintain a high flowrate to remove the cuttings and prevent cuttings beds from forming.

Table 5-2: Flow Rates in Extended Reach Wells

Hole Size (inches) Typical Flow Rates

17 1/2 1100 gpm minimumsome rigs achieve 1250 to 1400 gpm

12 1/4 Aim for 1100gpm although 800 to 1000gpm is typicallyachieved

8 1/2 Aim for 500 gpm

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October 18, 2000 Page 5-15

Figure 5-4: BHA Drag in Lateral Cuttings beds

Mud PillsMud pills improve hole cleaning in high-angle wells. High viscosity [weighted] pillsare more effective in hole sizes greater than 8 ½-inches. Low viscosity pills are moreeffective in holes less than 8 ½-inches. The number of pills used is determined byhole size.

Table 5-3: Volume of Pills

17 1/2 and 16-inch intervals 12 1/4-inch intervals 8 1/2-inch intervals

50 + bbl 30-to-50bbl 20bbl

Circulating Time Prior to TrippingUse mud properties for optimum hole cleaning. If packing off occurs, the flow rate istoo low or there has not been enough circulating time. In holes greater than 30°, theminimum circulating time prior to tripping is 1 1/2 times the bottoms-up time. Table5-4 lists circulation in various size holes at different penetration angles.

Table 5-4: Circulation Relative to Bottom’s Up Time

Hole Diameter

8 1/2-inches 12 1/4-inches 17 1/2-inches

0-10° 1.3 1.3 1.5

10-30° 1.4 1.4 1.7

Ho

le A

ng

le

30-60° 1.6 1.8 2.5

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Page 5-16 October 18, 2000

60° 1.7 2.0 3.0

Mud Cycling TimeUse the following formulas to compute the mud pump complete circulation time.

(bbls/min) output pumpbbls in volum surfaceactivehole in mud Bbl

Time nCirculatio Complete+=

Where:

Pump Output [gpm x .024 ] = Bbls/Min

Bbls/Min = Bbl/stroke x strokes/Min

Volume of Mud in SystemTo calculate the total volume of mud in the system, use the following formulas.

Total Mud = bbl mud in pit + bbl mud in hole

Where:

ftbblsftdepthwidthlength

/6.5

)(** =

Capacity of HoleUse the following formula to calculate the capacity of the borehole.

bbls/ft1029.4

(inches) hole theofDiameter 2

=

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October 18, 2000 Page 5-17

Miscellaneous FormulasThe following formulas are provided for your convenience.

Hydrostatic Pressure 0.52 * mud weight * depth

Hole Capacity bbls/ft1029.4

inches) in diameter (hole 2

=

Displacement

Steel weighs 65.14lb/gal

ntdisplaceme gallon65.14

weightstring =

42ntdisplaceme gallon

ntdisplacemebbl =/

Rectangle Tank Volume5.6

H(ft)*W(ft)*L(ft)ftbblsVolume =)/(

Cylinder Tank Volume1029.4

inches) in (diameterftbbl

2

=/

Rotation and ReciprocationFlow rate alone cannot always remove a cuttings bed. In extended reach holes,reciprocation and rotation are required to mechanically agitate and erode the cuttingsbed. Back ream the hole with rotating speeds of 150rpm to mechanically disturb thecuttings beds.

Reciprocate rather than rotate the pipe during circulation prior to tripping in verticalholes. This helps remove cuttings from stagnant zones near the wellbore wall. It isill-advisable to reduce the flow rate while circulating bottoms up merely to preventmotor wear.

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Page 5-18 October 18, 2000

ParametersPrior to washover, record all parameters:

Rotating torque, pump pressure, SPM, up drag, down drag, and shape and volume ofcuttings going over the shakers. If any of these parameters changes drastically, takecorrective action immediately.

The following equation is the optimum annular velocity according to MurchisonDrilling Schools, Inc.

diameter hole X weightmud11,800

ft/minvelocity annular =

Example: 9.5lb mud in 12.25-in. hole

101ft/min116

11,80012.25*9.5

11,800 ==

Example: 11.5lb mud in 12.25-in. hole

84ft/min140

11,80012.25*11.5

11,800 ==

Example: 9.5# mud in 8.5-in. hole

146ft/min80

11,8008.5*9.5

11,800 ==

sizepipe drill - sizeholegpm X 24.51

ft/minvelocity annular =

Required Annular Velocity to obtain 500gpm

High angle 8 ½-in. hole

236ft/min52

12,2554.5 - 8.5

500 X 24.51[ft/min]velocity annular ===

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October 18, 2000 Page 5-19

Desired Annular Velocity FormulaUse the following formula to determining the pump output (bbl/min) for a desiredannular velocity (ft/min).

Bbl/min=AV(ft/min) x (Dh²-Dp²)

Where:

AV = annular velocity in ft/min

Dh = ID casing or hole in inches

Dp = OD of pipe in inches

Example:

Bbl/Min for an annular velocity of 236 ft/min

in11.92bbl/m1029.412272

1029.452*236

1029.44.5(8.5*236PumpOutput 22

===−=

To attain an annular velocity of 236 Ft/Min w7 Tered to pumpat (11.9 (Bbl/Min) Tj 0 -19.5 TD -0.3578 Tc 0.2324 Tw (11.9 x 42p =500 GPM5) Tj -36-379.5 TD /F2 14.25 Tf 0.1974 Tc -036509 Tw Annular olumea) Tj 36 -19.5 TD /F3 11.25 Tf -0.3162 Tc 0.2337 Tw (Use the following formula to determise the annular olume Tereredain well.n) Tj ET264 3-18 m 0693-18 l S BT300 3060 TD /F7 12 Tf08 Tc 0 Tw (1029.4) Tj475 16.5 TD- 0.474 Tc(OD.) Tj -9.25 0 TD 0 Tc ( ) Tj-218.75 0 TD -0.0615 Tc Ppip5

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Page 5-20 October 18, 2000

Annular Velocity in Ft./Min.Use the following formula to determine the annular velocity of the mud in feet perminute.

[bbl/ft]Velocity Annular[bbl/min] Pump

[ft/min]Velocity Annular =

Example

236ft/min0.050511.92 =

TriplexUse the following formula to figure the triplex.

spm*4120

strokeof inches*linearbbl/min

2

=

Pump 6 x 12-in. x 114 SPM

in11.94bbl/m114*0.1048114*4120432

114*4120

12*6 2

===

11.94 Bbls. x 42 gallons = 501 GPM

Table 5-5: Single Acting Triplex Pump Data

Linear size = 6 id

Stroke = 12.000 inches

Answer (bbls/stroke) = 0.0882 bbls/stroke

Pump (eff) = 0.97%

Answer (eff) = 0.0837 bbls/stroke eff

Answer (gps eff) = 3.5172 gallons/stroke eff

Required strokes/gpm

Lenear size = 6 id

Stroke = 12.00 inches

Pump (eff) = 0.95%

Required gpm = 500gpm

Answer (req s/m) = 87 required strokes/minute

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October 18, 2000 Page 5-21

DisplacementUse the following formula to determine the displacement needed for pumpingsufficient mud into the well for fishing operations.

2750depth*foot per weight

ntdisplaceme total =

Example:

10,000 ft. 2-3/8 x 4.7pound tubing

tisplacemen17.09bbl/d2750

47,0002750

10,000*4.7 ==

Filter CakeThe filter cake is used to wall off the hole. Filtration occurs in wellbore through thefilter cake. Liquid from the mud is lost leaving a cake behind. Fine solids penetratethe cake and bridge the gaps creating an impermeable cake.

Hydrostatic PressureHydrostatic pressure is calculated using the following formula.

Pressure = Depth * mud weight * .052

Example:

The depth = 10,000ft and the mud weight is 14lbs

Pressure = 10,000 * 14 * 0.052 = 7,280 psi.

Mud is used to control well pressure

Hydrostatic Pressure = mud wt. x depth x .052

The gulf coast pressure gradient is 0.465 pounds per foot. Nine pound mud justbalances the pressure.

10,000 x .465 = 4650 BHP

10,000 x 9.0 x .052 = 4680 HP

Always drill at balance or slightly over.

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Page 5-22 October 18, 2000

Buoyancy FactorThe drilling mud will support part of the weight of the drill string. The portion of thedrill string weight that is supported is equal to the weight of fluid displaced. This isreferred to as the buoyancy factor and can be calculated by using the followingformula. Standard buoyancy factors are listed in Table 5-6.

165.63 weightmud

FactorBuoyancy −=

Example:

If the mud weight is 15lbs, what is the buoyancy factor?

77.0163.65

15 =−

Table 5-6: Buoyancy Factor

Mud weight factor mud weight factor

8.4 0.872 12.6 0.807

8.6 0.869 12.8 0.804

8.8 0.866 13.0 0.801

9.0 0.862 13.2 0.798

9.2 0.859 13.4 0.795

9.4 0.856 13.6 0.792

9.6 0.853 13.8 0.789

9.8 0.850 14.0 0.786

10.0 0.847 14.5 0.778

10.2 0.844 15.0 0.771

10.4 0.841 15.5 0.763

10.6 0.838 16.0 0.756

10.8 0.835 16.5 0.748

11.0 0.832 17.0 0.740

11.2 0.829 17.5 0.733

11.4 0.826 18.0 0.725

11.6 0.823 18.5 0.717

11.8 0.820 19.0 0.710

12.0 0.817 19.5 0.702

12.2 0.814 20.0 0.694

12.4 0.811

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October 18, 2000 Page 5-23

Mud For Fishing OperationsObserve the following parameters when selecting mud to be used during fishingoperations.

• Weight sufficient to maintain well control (stop shales and water flow)

• Viscosity = four times the mud weight

• Y.P. equal to mud weight if drilling

20 to wash over

30 + to mill

• Water Loss

Hard formation = 10

Unconsolidated sand = 5 or below

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Page 5-24 October 18, 2000

Notes:

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October 18, 2000 Page 6-1

Fishing Best Practices Manual

Fishing in Cavities

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

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Page 6-2 October 18, 2000

Contents

Introduction........................................................................................................................6-4

Getting Washpipe Over a Fish .........................................................................................6-4

Feeler Pins ..............................................................................................................6-5

Trahan Bushing...........................................................................................................6-6

Other Methods To Use ...................................................................................................6-7

Mule Shoe ..................................................................................................................6-8

Wall Hook................................................................................................................6-10

Kick Sub ..................................................................................................................6-10

Knuckle Joint............................................................................................................6-11

Consequences...........................................................................................................6-13

First Bad decision: .................................................................................................6-13

Second Bad decision:.............................................................................................6-13

Third Bad decision:................................................................................................6-13

Fourth Bad decision: ..............................................................................................6-13

Conclusion ............................................................................................................6-13

Overruled by Company Man......................................................................................6-13

Notes:..............................................................................................................................6-15

List of Figures

Figure 6-1: Getting Over Fish with Wash Pipe............................................................................6-5

Figure 6-2: Getting Side Tracked...............................................................................................6-5

Figure 6-3: Trahan Bushing.......................................................................................................6-7

Figure 6-4: Shorten the Washpipe to Get Over the Fish...............................................................6-7

Figure 6-5: Cripple Shoe Engagement........................................................................................6-8

Figure 6-6: Re-Top Fish with Spear...........................................................................................6-8

Figure 6-7: Bent Joint and Mule Shoe ........................................................................................6-9

Figure 6-8: Kick Sub ..............................................................................................................6-10

Figure 6-9: Re-Top Fish with Kick Sub....................................................................................6-10

Figure 6-10: Knuckle Joint ......................................................................................................6-12

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October 18, 2000 Page 6-3

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Page 6-4 October 18, 2000

IntroductionThis section discusses fishing in openhole environments. Openhole environmentspresent unique challenges for successful fishing jobs.

Important Consider the consequences before making a backoff. Company men sometimeswant EVERY joint they can get. The consequences of taking too many joints out ofthe hole too soon may be a fishing job failure. The backoff may be made in thewrong place if too many joints are taken before the fisherman arrives. Think beforeyou act.

Getting Washpipe Over a FishGetting washpipe over the top of a fish can be a trying experience. This is especiallytrue if the fish is laying in a cavity or stuck to the wall having no free pipe above it.Getting over the fish can make-or-break the fishing job. Most people do not realizethis until it is too late. The decision to run washover pipe is usually made after severaldays of fishing. Explain to the company man the consequences of using too muchforce trying to get the shoe over the fish. Operators are anxious to get the washoverjob complete and are prone to use force. The washover job cannot be forced. Useof force is certain to make the situation worse. Inexperienced personnel tend to puttoo much weight on the rotary shoe.

Too much weight tears up the rotary shoe or damages the top of the fish or both. Italso can easily cause the hole to be sidetracked by running washpipe along side thefish. Any tool run after the washpipe tends to follow the path of the washpipe, pushingthe fish further into the wall.

Don’t spend too much time trying to force a shoe over a fish, especially when othermethods are available. One hour should be long enough. If you haven’t gotten overthe fish in an hour, it is not likely that you will.

Have the tools on location to implement an alternate plan of action. Call yoursupervisor to get a second opinion, or better yet, have him come to the rig for support,if possible.

A useful tool in this situation is a Trahan bushing. The Trahan bushing acts as aportable Kelly, allowing you better control, so you can get over a fish without havingto get back off it to make a connection. This tool is used when there is no top drive orPower swivel on the rig. It is very helpful when the slips are riding one side of therotary, and you must slack off several inches to set them, thereby putting weight onthe shoe.

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October 18, 2000 Page 6-5

Figure 6-1: Getting Over Fish with Wash Pipe Figure 6-2: Getting Side Tracked

CAUTION: Do NOT put too much weight on the washpipe, damage to the rotary shoe or top offish may occur.

Feeler Pins

Feeler pins can be welded inside the shoe and used as an indicator that you aredefinitely over the fish. After you set down on the fish and slack off, at a certainpoint (usually about 6,000lbs) the pins will break off. The pump will wash the pins outof the way and you will know you are over the fish.

Tack weld ¼-inch diameter pipe nipples three feet inside the top of the shoe.

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Page 6-6 October 18, 2000

Trahan BushingWhen using the Trahan bushing (Figure 6-3) to get the washpipe over the fish,perform the following steps.

1. Set the slips on the drill pipe leaving about five feet above the rotary.

2. Place the bit breaker over the pipe and seat it in the rotary Kelly bushing pinholes.

3. Strip the Trahan bushing over the drill pipe and into the square bit breaker whereit is designed to fit.

4. Attach the clamp to the drill pipe.

5. Attach the Kelly to the string and begin rotating and circulating.

You are now ready to get over the fish using more control of the weight applied.

6. Check all parameters, and slack off slightly watching for any change in torque orpump pressure. The tool is collapsible like a telescope and has about five feet oftravel. You should get an increase in pump pressure as the washpipe goes overthe fish.

7. After getting over the fish, remove the bushing in the same manner as youinstalled it.

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October 18, 2000 Page 6-7

Figure 6-3: Trahan Bushing

Other Methods To UseOther ways of getting over a fish with washpipe include running less washpipe(Figure 6-4), using a cripple shoe (Figure 6-5), and hanging a limber joint of drill pipeout the bottom of the washpipe by using a drill collar spear without the slips (Figure6-6). The drill collar spear serves as a means to secure the joint of pipe while going inthe hole and to hold backups while screwing onto the fish.

After the spear is attached to the fish, it serves no other purpose and does notinterfere with the washover operation in any way because the slips have been left outalthough the top of the spear is now the top of the fish.

Figure 6-4: Shorten the Washpipe to Get Over the Fish

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Page 6-8 October 18, 2000

Figure 6-5: Cripple Shoe EngagementFigure 6-6: Re-Top Fish with Spear

Mule ShoeIf you have a tool joint box looking up as the top of the fish, the bent joint is usually themost expedient method available. A bent joint may be very successful if you “muleshoe” the pin.

A mule shoe is made when the first five threads are cut off about half way aroundwith a ten degree taper.

To create a mule shoe, perform the following steps.

1. Use a cutting torch to cut a mule shoe pin in the tool joint.

2. Clean the threads with a wire brush wheel and a file.

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October 18, 2000 Page 6-9

3. Thread a sub onto the pin to verify that it will make up properly.

Bend the joint first so the pin can be cut at the correct angle for maximum reach.Consider running a full stand of pipe on bottom of the jars so it will be limber. This is agood tool to run when there are no other fishing tools on location.

If available, a 1 to 3-1/2 degree bent sub may be used in place of the bent joint.

Figure 6-7: Bent Joint and Mule Shoe

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Page 6-10 October 18, 2000

Wall HookA wall hook and overshot can also be successful on a bent joint. Attach a wallhook/overshot combination to a joint and chain it down on the cat walk. Use the forklift to bend the pipe with the hook about 1/8 to 1/4 round to the left of center. Thisoffset will help get the wall hook onto the top of the fish. The wall hook is generallynot strong enough to pull drill collars out of a cavity, and doesn’t have a large enoughI.D. to allow drill collars into the hook. When using reach extenders, do not fisharound too long, because the extender will knock debris from the wall of the hole.

Kick SubA kick sub (Figure 6-8) is another proven way of getting onto the top of a fish in acavity. A kick sub, with a “J” type safety joint one stand up, is a good way to re-top afish (Figure 6-9), moving it up out of the cavity so that wash pipe can get over it. Thismethod is used if there is no free pipe that can be backed off below the top of thefish.

Figure 6-8: Kick Sub Figure 6-9: Re-Top Fish with Kick Sub

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October 18, 2000 Page 6-11

Knuckle JointThe Bowen-Lebus Knuckle Joint (Figure 6-10) adds lateral reach to a fishing tool byits ability to operate downhole. Unlike the previously discussed methods, it does not gointo the hole already bent.

1. Check the bore of the control piston to insure it is the proper size and make theknuckle joint up on the fishing string.

2. Check the action of the knuckle by hand. It should knuckle slightly behind the cutlip guide or wall hook guide. If it does not, add or remove the spacer washers.

3. Run the tool into the hole to near the top of the fish and establish full circulationthrough the tools.

4. Stop circulation and drop the restriction plug making sure the fishing neck is in theupward position.

5. Re-establish circulation and watch for an increase in pump pressure when theplug is seated.

6. Idle the pump after the plug has seated. The control piston will deflect and causethe tool to knuckle.

7. Lower the string to engage the fish. It may be necessary to raise and lower thestring several times, rotating 5 to 10 degrees each time the string is raised.

Note: After the fish has been engaged, it is not necessary to retrieve the plugunless you need to run some wireline tools.

CAUTION: Do not jar excessively on knuckle joints and do not bump down at all. knuckle jointsand wall hook combinations should not be used for long periods of time to avoid holedamage and fouling the hook.

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Page 6-12 October 18, 2000

Figure 6-10: Knuckle Joint

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October 18, 2000 Page 6-13

ConsequencesThe importance of following established procedures cannot be stressed enough. Thefollowing “Bad Decisions” are the result of not following established procedures andbeing in too much of a hurry to complete the job. Haste creates unsuccessful fishingjobs and can cause a well to be abandoned.

First Bad decision:

• Stuck @ 9104; backed off @ 91041

• Screw in, jar, soak 48 hours

Second Bad decision:

• Ran 377’x 7-3/8 wash pipe without bit trip

• Wash pipe: 7140; ream 7180

• Bit trip; reamed 6673 to top fish (21 hours)

Third Bad decision:

• Ran Lebus spear against advice

Fourth Bad decision:

• Attempt to get over fish three hours.2

Conclusion

Left the shoe in the hole

The hole had to be junked

Three to four million dollar hole was abandoned as a result of decisions made.

Overruled by Company ManIf you have followed the correct procedures and are overruled by the Company Man;

1. Record what took place in tally book and resume.

2. Have the Company Man sign resume.

1 The company man made the decision to backoff as near to the stuck point as possible making it difficult, if not impossible toget over the top of the fish. Because of this, there was a very poor chance to fish this without re-topping the fish.

2 Attempted too long using too much weight, cutting up the shoe eliminating other options.

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Page 6-14 October 18, 2000

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October 18, 2000 Page 7-1

Fishing Best Practices Manual

Fishing for Parted Pipe

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

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Page 7-2 October 18, 2000

Contents

Introduction........................................................................................................................7-5

Bottom Hole Assembly Options .......................................................................................7-7

Attachment Tool Rating System...................................................................................7-8

Screw In Sub..................................................................................................................7-9

Overshot ......................................................................................................................7-10

What Overshot do I Need?............................................................................................7-11

Series 150 Oververshot Tightening Torques ................................................................7-23

Mill Extensions..........................................................................................................7-24

Overshot in an Open Hole - Run Procedure....................................................................7-26

Releasing Overshots .....................................................................................................7-27

The Oversocket Fishing Tool.........................................................................................7-29

Clulow Socket Overshot................................................................................................7-31

Releasing Spears ..........................................................................................................7-31

Bowen Full Circle Releasing Spear.............................................................................7-33

Houston Engineers Releasing Spear ...........................................................................7-33

H.E. Releasing Spear Accessories..........................................................................7-34

Box Tap and Taper Tap................................................................................................7-42

................................ ................................ ................................ ..............................4-26 ..................................................................................................ol - 2 6

pu ol ....................................................................ol 7 2 6

................................................................................................ 7 2 6

.........................................................1-42

1442

.............................................................................................................1642

.............................................................................1742

................................................................

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October 18, 2000 Page 7-3

Figure 7-9: Spear with stop and Pack-off.................................................................................7-34

Figure 7-10: Releasing Spear Accessories ...............................................................................7-36

Figure 7-11: Releasing Spear Examples ...................................................................................7-36

Figure 7-12: Itco Type Bowen Releasing Spear and Catching Range Table – Sheet 1.................7-38

Figure 7-13: Itco Type Bowen Releasing Spear and Catching Range Table – Sheet 2.................7-39

Figure 7-14: Itco Type Bowen Releasing Spear and Catching Range Table – Sheet 3.................7-40

Figure 7-15: Itco Type Bowen Releasing Spear and Catching Range Table – Sheet 4.................7-41

Figure 7-16: Box and Taper Tap BHAs...................................................................................7-42

List of Tables

Table 7-1: Screw In Sub Rating ................................................................................................7-9

Table 7-2: Overshot Rating.....................................................................................................7-10

Table 7-3: Bowen Overshot Uses ...........................................................................................7-10

Table 7-4: Overshot Types .....................................................................................................7-11

Table 7-5: Series 150 Overshot - Tightening Torques................................................................7-23

Table 7-6: One Trip Operation Example (Dress and Engage Fish) .............................................7-25

Table 7-7: Overshot Fishing Tool - Available Sizes ...................................................................7-30

Table 7-8: Clulow Sockets ......................................................................................................7-31

Table 7-9: Releasing Spear Rating...........................................................................................7-32

Table 7-10: Full Circle Type Bowen Releasing Spears..............................................................7-36

Table 7-11: Box Tap or Die Collar Rating................................................................................7-43

Table 7-12: Taper Tap Rating .................................................................................................7-43

Table 7-13: Drill Pipe Pin Tap Rating ......................................................................................7-44

Table 7-14: Releasing Spear Rating.........................................................................................7-45

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October 18, 2000 Page 7-5

IntroductionWhen drillpipe parts during normal drilling operations, the cause is usually notexcessive torque but metal fatigue. Rough handling, scarring by tong dies, impropermakeup torque, erosion caused by a washout, and other damage create weak spots inthe drillpipe where cracks can form and enlarge under the constant bending andtorquing stresses of routine drilling. The pipe often separates in a helical break or in along tear or split (Figure 7-1). Surface signs of a twistoff include loss of drill stringweight, lack of penetration, reduced pump pressure, increased pump speed, reduceddrilling torque, and increased rotary speed.

Several questions must be answered prior to fishing for a parted string, including:

• Where is the top of the fish?

• What is the condition of the top of the fish?

• Can the fish be externally engaged?

• If the fish must be internally engaged, is the top of the fish open?

• Is the fish in a washed out portion of the hole?

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Page 7-6 October 18, 2000

Figure 7-1: Twisted Off Pipe

String has parted

String has parted in

connection

Tube has broken close to

connection

Tube will require dressing off?

Can string be engaged by a screw

in assembly?

Run overshot (extension) w/stop

ring and jarring assembly.

TIH with screw in jarring assembly.

Wash down to top of fish, circulate capacity of string.

POOH, change grapple, modify assembly (bend

joing, wall hook etc.)

Engage fish

Is fish free?

Prepare for free point and back-off or

suspension of fishing operations.

Run overshot with hollow mill container and

insert.

Establish parameters

Dress off fish

Job complete.

Yes

No

Yes

No

No

Yes No

Yes

No

Yes

Yes

No

Jar as required to free fish,

POOH.

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October 18, 2000 Page 7-7

Figure 7-2: Fishing for Parted Pipe Flow Diagram

Bottom Hole Assembly OptionsThere are several BHA options available as shown in Figure 7-3.

Drill Pipe

Accelerators

Oil Jar

Bumper Jar

B o xT apSpearAssembly

ScrewIn S ubOrJoint

Ov r s h tD r i C o l a r s

F i g u r e 7 - 3 : B H A O p t i o n s Note: Run a safety joint above taps.

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Page 7-8 October 18, 2000

Attachment Tool Rating SystemA rating system has been developed to help identify the attachment tool best suitedfor a specific environment. Points are given in each category, from zero to 100, zerobeing the worst and 100 most desirable.

Attachment tools are rated on the following criteria:

• Strength

• How easily can you circulate through it

• Is the attachment wireline accessible

• How well does the attachment withstand upward and downward jarring

• The ability to transmit torque

• Releasability

The following list is the overall rating for some of the attachments commonly used.

Attachment Tool Overall Rating

Screw in sub 100

Series 150 Overshot 89

Series 70 short catch overshot 79

Bowen/Itco spear 71

Box tap 39

Taper tap 18

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October 18, 2000 Page 7-9

Screw In SubThe screw in sub is ideal if a usable tool joint is available at the top of the fish. ratingsfor the screw in sub are listed in Table 7-1.

Table 7-1: Screw In Sub Rating

Criteria Rating Illustration

Strength 100

Circulation 100

Wireline 100

Jar Up 100

Jar Down 100

Torque capabilities 100

Releasable 60

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Page 7-10 October 18, 2000

OvershotWherever possible, a fish should always be externally engaged. The overshot is thetool of first choice. Introduced by Bowen in 1935, the Series 150 overshot is the mostwidely used fishing tool in the world. An overshot offers the most options. You canrun wireline through it, pump through it, torque it, jar with it, release it, or dress andengage a fish in one run. Bowen overshots are designated by series and types.

The rating for the overshot attachment tool is listed in Table 7-2.

Table 7-2: Overshot Rating

Criteria Rating Illustration

Strength 80

Circulation 60

Wireline 100

Jar Up 80

Jar Down 20

Torque capabilities 60

Releasable 100

Table 7-3 lists the series and uses for Bowen overshots.

Table 7-3: Bowen Overshot Uses

Series Description Use

10 Sucker rod overshotUsed mainly inside tubing. The spiral grapple control is made on andis part of the guide.

20Short catch suckerrod overshot

Used mainly inside tubing. This series carries a basket grapple only,that is loaded from the top.

70 Short catch overshot

Used inside tubing, casing or open hole. This type carries a basketgrapple only. This grapple is also loaded from the top. It does notaccommodate a pack-off and is used when you have a short area tocatch and a conventional overshot will not work. It does not have acut lip guide ,but one can be welded on to it.

150 Main releasing andcirculating overshot

Used in a short catch area where the overshot guide will go over therest of the fish. This type consists of three outside parts; the topsub, the bowl, and the guide.

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October 18, 2000 Page 7-11

Table 7-4 lists the different types of overshots and their uses.

Table 7-4: Overshot Types

Type Use

full strength bowl heavy pulling, torsional or jarring loads

extra full strength extreme environments

semi full strength special hole conditions

slim hole heavy pulling loads only

extra slim hole for a pick up job only

The top sub can have a sucker rod, tubing, tool joint or washpipe connection andshould be full opening. That means the ID is equal to or greater than the fish ID Anyovershot can be made full opening, up to the maximum catch size for that particularovershot, by having a special top sub made with the same I. D. as the fish. The topsub thread can be made the same as the fish, also. When fishing for the maximumcatch size for a given overshot, insure that the ID of the extension will accommodatethe fish. The standard ID of an overshot extension is 1/8-in. larger than the maximumcatch size for a basket grapple to fit that overshot. Any larger ID will reduce thetensile strength of the extension.

The bowl is what houses the grapple. The grapple is what actually bites or holds thefish. It has wickers on the inside and a tapered helix, to match the bowl, on theoutside. The tapered design allows the grapple to expand as the fish enters and tocontract as an upward pull is applied. The length of the grapple allows the strain andexpansion of an up pull to be distributed over a large area.

What Overshot do I Need?The guide is used to hold the grapple control in place and to aid in getting the overshotover the fish

The OD of the fish and the ID of the hole determines which overshot you can use.Under normal conditions, you should run the largest overshot that will go in the hole.The fish size will determine which grapple to use, spiral or basket, depending onwhether the fish to be caught is near the maximum size for the particular overshot. Ifthe fish is near the maximum catch of the overshot, a spiral grapple, spiral grapplecontrol and type A packer is used (Figure 7-4). If the fish diameter is considerablyunder maximum catch size,(usually ½-in. or more), a basket grapple and a controlpacker, either plain or with mill teeth, are used (Figure 7-4).

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Page 7-12 October 18, 2000

Spiral Grapple Assembly

Basket Grapple Assembly

Figure 7-4: Overshot-150 Grapple and Basket assemblies

The different types of grapples are the standard basket grapple, the long catch stopbasket, the short catch stop basket, and the spiral grapple (Figure 7-5) . The basketwith a long catch stop has a stop ring built into it and the basket with a short catchstop has two sets of wickers to catch different sizes. A spiral grapple will pull morebut the basket grapple is more durable and has a better pack-off.

Exact fish OD is important, grapples are manufactured with small tolerances in catchsizes. For example:

• The tolerance for a catch size of spiral/basket type grapples is 3/32-in. undersizeto 1/32-in. oversize. This only applies to FS type overshots.

• Basket grapple tolerances for slim hole overshots is 1/16-in. undersize with nooversize tolerance.

• Tolerances for slim hole spiral grapples are 1/16-in. oversize and undersize.

When the pack-off and grapple passes over a fish, there will be an increase in pumppressure. Know your measurements and when the fish bumps up on the top sub, thisis as far as it will go. If there is no weight gain when the fishing string is picked up,

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October 18, 2000 Page 7-13

the grapple is too large . The grapple must be down sized by 1/8-in. If you get overthe fish and experience a pressure increase as the fish inters the pack-off, but will notpass through the grapple, the grapple is too small. Rock the rotary a little, with a smallamount of down weight, but do not force a grapple over a fish. The grapple willpuncture the bowl and then it is not releasable. Too much force may cause thegrapple to break, complicating matters further. Pull out of the hole and change to thenext larger size grapple.

The grapple control locks the grapple in position so that it cannot turn independently ofthe bowl as torque is applied in either direction. There are several types of controls.They are the plain basket control, the plain control packer (no mill teeth), the millcontrol packer (mill teeth and tapered to fish OD) and the spiral grapple control(Figure 7-4).

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Page 7-14 October 18, 2000

Top Sub

B o w l

G u i d e

S p i r a l

Grapple

Top S ubB owlGuide

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October 18, 2000 Page 7-15

Right hand wicker grapples are available and they release to the left. This would beuseful if one overshot had been left in the hole and a second overshot was run.

Special Nitraloy grapples are used to catch chrome because of their hardness. Mostfishing necks on logging tools are chrome.

Overshots are available with left hand connections.

Figure 7-7 shows the grapple arrangement in the bowel.

The tables on pages 7-19 and 7-20 list cased hole fishing overshots/washpipe/cuttersand recommend drillpipe respectively.

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Page 7-16 October 18, 2000

Figure 7-6: Catch Pin

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October 18, 2000 Page 7-17

Fish

Grapple

B o w l

Figure 7-7: Grapple Wickers Biting the Fish

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October 18, 2000 Page 7-19

Cased Hole Fishing: Recommended Overshot/Washpipe/Cutter

Casing Pipe Connection Overshot Maximum Washipipe Maximum External Cutter Maximum

Size-Wt. Size-Wt. Type OD Sizer-Type Catch Size Washover Type/Size CutterClearance

4-1/2"9.5011.60# 2-3/8” 4.70# 8RD,3-1/16” 3-3/4” S.H. 3-1/16” 3-3/4” 3.1/8” Bowen Mech. 3-7/8” 3-1/16"

4-1/2” 13.50# 2.3/8” 4.70# 8RD,3.1/16” 3.3/4” S.H. 3.1/16” 3.3/4” 3.1/8” Turn Down 3.7/8” (3-3/4") 3.1/16"

4.J/2” 15.10# 2.3/8” 4.70# 8RD,3-1/16” 3-5/8” X.S.H. 2-7/8” 3-1/2” 2.5/8” None ...

5” 11.50-23.20# 2-3/8” 4.70# 8RD,3-1/16” 3-3/4” S.H 3.J/16” 3-3/4” 3.1/8” Bowen Mech. 3-7/8” 3.1/16"

5-1/2” 14.17# 2.3/8"4.70# 8RD,3-J/16” 4-11/16"F.S. 3.2J/32” 4-1/2” 3-3/4” H.E.4-9/16” 3.3/8"

5-1/2” 14.17# 2-7/8” 6.50# 8RD.3-21/32” 4-11/16” F.S. 3-21/32” 4-1/2” 3.3/4't Bowen 4-11/16” 3-3/4"

5.1/2” 20.00# 2.3/8” 4.70# 8RD.3.1/16” 4-9/16” S.H. 3-21/32 4-3/8” 3.5/8” Bowen Hyd. 4-9/16” 3.9/16"

5-1/2” 20.00# 2-7/8” 6.50# 8RD.3-21/32” 4-9/16” S.H. 3-21/32” 4-3/8” 3.5/8” Bowen Hyd. 4-9/16” 3-9/16"

5.1/2” 23.00# 2.3/8” 4.70# 8RD.3.1/16” 4-1/4” F.S. 3.1/8” 4.3/8” 3.5/8” 3.1/8�.44-3/8”

4-3/8(3.1/8”)4Tj 117.7579TD -0.126 T820 Tw (7Tj 63 0 55.D 0.0322 Tc (4-3/8”)08 Tw (9584 TD -0.0159 2410 Tw (Nonew (9599 TD -0.015 25(7.0008(---T 66 360 0.2360 -00 TD e f BT 83. 360 0.2360 -00 TD e f BT 83. 360 0.2360 -00 TD e f BT 83. 360 0.2360 -00 TD e f BT 83. 360 0.2360 -00 TD e f BT 83. 360 0.2360 -00 TD e f BT 83. 860 0.2360 -00 TD e f BT 83. 360 0.2360 -00 TD e f BT 83. 360 0.2360 -00 TD e f BT 83.360 0.2360 -00 TD e f BT 83.25 82 0.220..047 T01-0.0861 T4518RD.3-2-4) Tj 5 44-4961.5 073TD -0.0159 T470.0245 T0 0.00.3.4.4) .S.) 16.60#3 0 T9 TD -0.0159 0890.0276 8RD.3.XH,6-4)4Tj 117.7560 TD -0.0159 1595.0008 1164-1/4�-4)8.S.) S.H76.5 0 5 TD -0.015 Tc (4-3/8(3.1/8”)4Tj 117.757D (4.3/8�-4)8.S.)3 0 TD (4.3/8”) Tj 63 0 84 TD -0.0159 2410 Tw (Nonew (9599 TD -0.015 25(7.0008(---T 66 360 0.222 TD - TD e f BT 83. 360 0.222 TD - TD e f BT 83. 360 0.222 TD - TD e f BT 83. 360 0.222 TD - TD e f BT 83. 360 0.222 TD - TD e f BT 83. 360 0.222 TD - TD e f BT 83. 860 0.222 TD - TD e f BT 83. 360 0.222 TD - TD e f BT 83. 360 0.222 TD - TD e f BT 83.360 0.222 TD - TD e f BT 83.25 760 0.2360 0.-7231 T330.0861 T10(4-1/49-4) Tj 5 36053 5 61.5 078 -0.0159 02310.0262 Tw040.0/8�-4) .S.) 16.60#3 0 70.D -0.0159 0890.0276 8RD.3.XH,6-4)4Tj 117.7561.D -0.0159 0976.0245 T5418RD.3-2.1)8.S.

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Recommended Drillpipe & Drill Collars For Open Hole & Cased HoleDrill Collars Overshot

Drillpipe Recommended Drillpipe Recommended Recommended Washpipe Recommended Recommended

In Casing In Open Hole In Cased/Open Hole For Fishing For Fishing

API Casing Bit

Size & Wt. Size DP Size TJ OD DP Size Max TJ OD Min OD Max OD OD; Conn Weight ID OD Max Catch

4-1/2” 9.50#-II.6_ 3.7/8” 2-7/8” PAC 3-1/8” 2-7/8”PAC 3-1/8' 2-7/8” 3-1/16” 3-3/4” FJWP 9.35# 3.250” 3.3/4” 3-1/16”

4-1/2” 13.50# 3-3/4” 2-7/8” PAC 3-1/8” 2-7/8” PAC 2-1/2” 2-7/8” 3-1/16” *3.3/4” FJWP 9.35# 3.250” 3.J/4” 3-1/16”

4-1/2” 15.10# 3-5/8” 2-3/8” WFJ 2-1/2” 2-3/8” WFJ 2-3/8” 2-1/4” 2-1/2” 3-1/2” FJWP 8.81 2.992' 3-3/8” 2-1/2”

5' 11.50#-I5# 4-1/4” 2-7/8” PAC 3-1/8” 2-7/8” PAC 3-1/8” 3” 3-1/8” 4” FJWP 11.34# 3.428 4-1/2” 3.1/8”

5” 18# 4-1/8” 2-7/8”PAC, 2-3/8”SLH90 3-1/8” 2-7/8”PAC, 2-3/8”SLH90 3-1/8” 3” 3-1/8” 3-3/4”FJWP 9.35# 3.250” 3-7/8” 3-1/8”

5” 29.3#-24.2# 4”-3-7/8” 2-7/8”PAC, 2-3/8”SLH90 3-1/8” 2-7/8”PAC, 2-3/8”SLH90 3-1/8” 2-7/8” 3-1/16” 3-3/4”FJWP 8.81# 3.250” 3-3/4” 3-1/16”

5-1/2” 13#-17# 4-3/4” 2-7/8 RFO 3-7/8” 2-7/8 RFO 3-7/8” 3-1/4” 3-1/2” 4-1/2”FJWP 14.98# 3.825” 4-11/16” 3-21/32”

5-1/2” 13#-17# 4-3/4” 2-7/8” SH 3-5/8” 2-7/8” SH 3-5/8” 3-1/4” 3-1/2” 4-1/2”FJWP 14.98# 3.825” 4-11/16” 3-21/32”

5-1/2” 20# 4-5/8” 2-7/8” PAC 3-1/8” 2-7/8” PAC 3-1/8” 3-1/4” 3-1/2” 4-3/8”FJWP 13.58# 3.749” 4-9/16” 3-21/32”

5-1/2” 20# 4-5/8” 2-7/8” RFO 3-7/8” 2-7/8” RFO 3-7/8” 3-1/4” 3-1/2” 4-3/8”FJWP 13.58# 3.749” 4-9/16” 3-21/32”

5-1/2” 23#-26# 4-1/2” 2-7/8” IF 3-3/8” 2-7/8” IF 3-3/8” 3” 3-1/4” 4-3/8”FJWP 13.58# 3.749” 4-3/8” 3-3/8”

5-1/2” 23#-26# 4-1/2” 2-7/8” SH 3-1/8” 2-7/8” SH 3-1/8” 3” 3-1/4” 4-3/8”FJWP 13.58# 3.749” 4-3/8” 3-3/8”

6-5/8” 32# 5-3/8” 2-7/8”RFO 3-7/8” 2-7/8”RFO 3-7/8” 3-1/2” 4-1/8” 5”FJWP 17.93# 4.276” 5-1/8” 4-1/4”

6-5/8” 32# 5-3/8” 2-7/8”IF 4-1/8” 2-7/8”IF 4-1/8” 3-1/2” 4-1/8” 5”FJWP 17.93# 4.276” 5-1/8” 4-1/4”

6-5/8” 32# 5-3/8” 3-1/2”SH 4-1/8” 3-1/2”SH 4-1/8” 3-1/2” 4-1/8” 5”FJWP 17.93# 4.276” 5-1/8” 4-1/4”

7” 17#-23#-26# 6-1/4”-6-1/8” 3-1/2IF,4”SH 4-3/4” 3-1/2IF,4”SH 4-3/4” 4-9/16” 4-3/4” 5-3/4”FJWP 21.53# 5.000” 5-3/4” 4-3/4”

7” 17#-23#-26# 6-1/4”-6-1/8” 3-1/2IF,4”SH 4-3/4”-4-7/8” 3-1/2IF,4”SH 4-7/8” 4-9/16” 5” 6”FJWP 22.81# 5.240” 5-7/8” 5”

7” 29#-32# 6” 3-1/2IF,4”SH 4-3/4” 3-1/2IF,4”SH 4-3/4” 4-9/16” 4-3/4” 5-3/4”FJWP 21.53# 5.000” 5-3/4” 4-3/4”

7” 35# 5-7/8” 3-1/2IF,4”SH 4-3/4” 3-1/2IF,4”SH 4-3/4” 4-1/4” 4-1/2” 5-1/2”FJWP 16.87# 4.892” 5-3/4” 4-3/4”

7” 38# 5-3/4” 3-1/2”SH 4-3/4” 3-1/2”SH 4-1/8” 4-1/8” 4-1/4” 5-3/8”FJWP 18..93# 4.670” 5-9/16” 4-1/4”

7-5/8” 20#33-7# 6-3/4”-6-5/8” 3-1/2”IF, 4” SH 4-3/4”-4-7/8” 3-1/2”IF, 4” SH 4-7/8” 4-9/16” 5-1/4” 6-3/8”FJWP 24.03# 5.625” 6-3/8” 5-1/4”

7-5/8” 20#33-7# 6-3/4”-6-5/8” 4”FH 5-1/4” 4”FH 5-1/4” 4-9/16” 5-1/4” 6-3/8”FJWP 24.03# 5.625” 6-3/8” 5-1/4”

7-5/8” 39# 6-3/4”-6-5/8” 3-1/2”IF, 4” SH 4-3/4”-4-7/8” 3-1/2”IF, 4” SH 4-7/8” 4-9/16” 5” 6”FJWP 22.81# 5.240” 5-7/8” 5”

8-5/8”24#-40# 7-7/8”-7/5/8” 4-1/2”XH 6-1/4” 4-1/2”XH 6-1/4” 6” 6-1/4” 7-3/8”FJWP 28.04# 6.625” 7-3/8” 6-1/4”

8-5/8”44#-49# 7-1/2”-7-3/8” 4”FH 5-1/4” 4”FH 5-1/4” 5-1/2” 6” 7”FJWP 25.66# 6.276” 7-1/8” 6”

9-5/8” 29.3#-36# 8-3/4” 4-1/2”XH, 5XH 6-1/4”-6-5/8” 4-1/2”XH, 5XH 6-5/8” 6” 7” 8-1/8”FJWP 35.92# 7.250” 8-1/8” 7”

9-5/8” 40#-43.5# 8-5/8” 4-1/2”XH, 5XH 6-1/4”-6-5/8” 4-1/2”XH, 5XH 6-5/8” 6” 7” 8-1/8”FJWP 35.92# 7.250” 8-1/8” 7”

9-5/8” 47# 8-1/2” 4-1/2”XH, 5XH 6-1/4”-6-5/8” 4-1/2”XH, 5XH 6-5/8” 6” 7” 8-1/8”FJWP 35.92# 7.250” 8-1/8” 7”

9-5/8” 53.5# 8-3/8” 4-1/2”XH, 5XH 6-1/4”-6-5/8” 4-1/2”XH, 5XH 6-5/8” 6” 7” 8-1/8”FJWP 35.92# 7.250” 8-1/8” 7”

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October 18, 2000 Page 7-21

Note: The Chart above is a guide-line only and should be used as a rule of thumb; the final decision is that of the Customer; 4” Pin-up drillpipe is an option inside 7" casing. discusswith Fishing Tool Manager for guidance.

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October 18, 2000 Page 7-23

Series 150 Oververshot Tightening TorquesTable 7-5 lists the maximum recommended tightening torques for the most popularSeries 150 Overshots. The listed makeup torques are for the Top Sub to Bowl andbowel to guide connections. These values are the maximum torque valuesrecommended and are set at 50% of yield. These torques are not required for allfishing jobs and lower torque values will work with less wear and tear to threads. It isalso assumed that the torque is applied to OD's evenly so as to not collapse the OD.Torque is measured in ft/lbs.

Table 7-5: Series 150 Overshot - Tightening Torques

Assembly No Bowl No Grapple No Top End Top Sub Torque(Ft/Ibs) BottomEnd

Cut LipGuide

Torque(ft/Ibs)

9305 9306 9307 9311 2,600 9312 400

9270 9271 9272 9276 2,600 9275 500

C-1827 B-1828 A-1829 A-1834 3,100 A-1833 900

37585 37587 37589 37586 2,800 37592 500

C-1835 B-1836 B-1837 A-1842 2,500 A-1841 700

9105 9107 1741 9106 3,300 1746 900

C-4822 B-4824 B-791 A-4823 5,000 A-793 1,100

C-4619 B-4621 B-3607 B-4620 3,900 A-4622 1,200

9109 9111 L-6662 9110 3,200 6667 1,300

C-5129 B-5131 A-5130 5,500 A-5135 1,100

9120 9121 9110 3,400 9125 1,000

4716 4717 4718 5,000 4719 1,500

5896 5898 5897 8,300 187 2,600

8975 8977 8976 7,600 6121 1,700

C-7096 B-7098 A-7097 5,700 A-6391 2,000

C-5171 B-5173 A-5172 7,400 B-4371 2,100

7787 7788 7789 8,100 5946 2,700

6655 4503 6656 9,900 4504 3,200

9692 9694 9693 12,600 9125 1,000

C-2108 B-2109 B-2106 31,300 A-2075 6,000

9860 9862 9861 12,100 9867 4,100

C-5342 B-3711 A-5343 23,100 A-2376 6,400

C-5222 B-5224 A-5223 9,700 A-5229 4,200

275 277 276 18,100 205 7,200

9217 9219 9218 15,700 9226 4,700

C-3263 B-3264 A-3033 17,200 A-3269 6,200

C5265 B-5267 A-5226 17,100 A-5272 6,100

264 266 265 24,700 240 9,700

8960 8962 8961 33,500 8959 10,200

C-5305 B-5307 A-5306 33,800 A-5312 12,100

A-5322 36,000 A-5328 12,700

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Page 7-24 October 18, 2000

Assembly No Bowl No Grapple No Top End Top Sub Torque(Ft/Ibs) BottomEnd

Cut LipGuide

Torque(ft/Ibs)

A-12823 40,000 A-12829 14,900

5329 5331 5330 55,400 5336 15,300

15800 15802 276 48,100 15806 17,000

Mill ExtensionsThe mill extension is used to mill the top of the fish down to the catch size of thegrapple in the overshot. It is run between the bowl and the guide.

For example, if you are dressing the top of a fish using a hollow millextension with a hollow mill insert, the length of the extension allows for adistance of about three feet between the mill and the grapple. This isimportant because you do not want to rotate the grapple while going overthe fish. The extra length of the extension allows you to dress the top of thefish, stop rotation, then slack off to engage the fish with the overshot.

Use as little milling weight as is necessary to dress the top of a fish. If you force themill over the fish, it may not be milled down enough to pass through the grapple. Ifyou run too much weight, a sliver of fish may break off and plug the ID of the fish,making wireline entry impossible.

A fluted carbide dressing mill is sometimes run to dress the top of drillpipe that hasbeen twisted off. The carbide pads are laid inside a cut lip rotary shoe by hand and itis difficult to get the ID of the carbide to the exact size required. The carbide isplaced about one foot inside the cut lip to allow the fisherman to get over the fish firstand then dress the top. This is where having a qualified carbide welder pays off. Thefisherman also must be qualified and know the exact measurements of his tools. Heshould have recorded in his tally book the distance from the guide to the carbide mill,to the grapple, and where the overshot will bump up. He is then better prepared toanticipate what is going on downhole as the operation unfolds.

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October 18, 2000 Page 7-25

Table 7-6: One Trip Operation Example (Dress and Engage Fish)

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Page 7-26 October 18, 2000

Note: Use torque not weight to dress the fish.

The following steps are a guide to dressing and running an overshot.

1. Select the bowl according to the maximum allowable outside diameter.

2. Select the proper grapple size.

a. If 1/2-in. or more below maximum catch size, use a basket grapple.

b. Record grapple size on the daily resume.

3. Select the appropriate pack-off.

a. Select the type A packer if using a spiral grapple

b. Select the proper control packer for basket grapple.

4. Select grapple control.

a. Spiral grapples for each overshot use the same control.

b. Select a mill control packer for basket grapples if the top of the fish is burred.A plain control is best if you want to offer the fish the least resistance whileentering the grapple. A mill control packer will not dress a badly flared fish.

5. Select overshot accessories.

a. Select a cut-lipped guide for most applications especially if the top of fish islikely to be centered in the hole. Select an oversize guide if hole size is somuch larger than fish size that the overshot could pass along side the fish.Select wall hook guide if the fish is likely to be in a washed out area. Select afluted mill guide if the top of fish is badly flared or jagged. Add an overshotextension if needed to insure engagement and pack-off.

6. Match top sub tool joint to fishing string tool joint.

7. Assemble the overshot components into a thoroughly doped bowl.

Note: A bumper sub is usually run above an overshot.

Overshot in an Open Hole - Run ProcedureUse the following steps as a guide to running an overshot on an open hole.

1. Measure everything including the bump-up on the overshot top sub or stop.

2. Trip In the Hole (TIH) with the overshot to within 10- or 15-ft. of the fish.

3. Pick up the Kelly and any pup joints needed for space out and circulate longenough to displace the fishing string.

4. Record the pick up and down weight of the string and then tag the fish with theovershot.

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October 18, 2000 Page 7-27

5. Slow the pump down at this time and work overshot over the fish as gently aspossible. Don’t rotate, but if necessary, rock the rotary just enough to keep thegrapple going over the fish. Watch for increase in pump pressure and bump up onstop or top sub. This is where knowing your exact measurements pays off.

6. Maintain pump pressure at a low rate, 500 to 700 psi, and watch for pressurebleed off. Don’t rush this procedure. Allow plenty of time for cuttings to washthrough the bit. If circulation can be established, circulate long enough to displacemud around the fish and fishing string. Continually move the fishing string thedistance of the free travel in the bumper jars.

7. Pick up on the fish at this time, but not over 20,000 pounds, and do not allow thejars to hit. Keep pumping and if you have any movement, continue to work thestring with only enough pull to get movement. Patience is essential in thisoperation.

If the fish is moving, it will nearly always come out of the hole if you exercisepatience and common sense.

Releasing OvershotsFour methods of releasing overshots are detailed below:

• Downhole with Kelly in the string and bushing in the rotary table.

• Downhole with drillpipe in the rotary table.

• On the surface with the fish in the rotary table.

• Downhole on a production rig.

The steps used for each of the methods are detailed below.

1. Downhole with Kelly in the string and bushing in the rotary table.

a. Find the closed position in the bumper sub and mark the Kelly.

b. Pick up the length of the stroke in the bumper sub and bump down to withininches of this mark sharply. This may require a little practice until you get itright. Try turning the string to the right. If you cannot rotate the grapple, pickup bumper sub stroke again being careful not to pull up on the grapple.

c. Put in right hand torque with the rotary (about 1/2 round per thousand feet ofdepth).

d. Lock the rotary table and bump down harder on the overshot. When thegrapple freeze releases you will loose the torque.

e. Pick up slowly and turn the string to the right being careful not to pull toomuch and reset the grapple.

f. Continue this procedure until the grapple clears the fish.

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Page 7-28 October 18, 2000

It may take a lot of torquing and bumping down to release the grapple. Do notpull up on the grapple once you start bumping down and keep right handtorque on the overshot until the freeze is broken.

2. Downhole with drillpipe in the rotary table.

a. Close the bumper sub and mark the pipe.

b. Pick up the distance of the bumper sub stroke and bump down sharply two orthree times.

c. Pick up a foot or so keeping the bumper sub partially open.

d. Set the slips in the rotary table and rotate to right. If the grapple freeze isbroken, the pipe will rotate. If not, it may be necessary to hold the right handtorque in the string while bumping down and holding the torque with the backup tongs.

e. Check the tong snub line carefully before starting this procedure.

f. When the grapple releases, pick the string up slowly with the slips in therotary.

g. Rotate the pipe as necessary to clear the grapple from the fish.

h. Take just enough up strain and rotate to keep grapple walking off fish. If youpull up too hard, you will have to bump back down and go through theprocedure again.

Important: You should run a bumper sub in all applications where you use a grapple, because itis the only insurance you have to release the grapple freeze.

3. On Surface with fish in rotary table.

a. When your tools are at the rotary, set the slips on the bumper sub and makeup a lift nipple securely. Be sure the hook is unlocked before picking up onthe tools.

b. Set the slips below the overshot any place needed.

c. If the fish can be screwed into, remove the overshot with the fish in the table.If not, break at the next joint below and put the fish in the mouse hole.

d. To remove overshot here or in the table, put lead tongs on the overshot andback-up tongs on the fish. Place the tongs high up on the bowl to preventegging it.

e. Hold a tight bind and close the bumper sub as fast as possible. Try to get it tobump down. It may be necessary to tie the catline around the middle body ofthe bumper sub and drop the weight of the jars while holding torque with thetongs to break the grapple freeze.

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October 18, 2000 Page 7-29

f. Maintain a slight strain on the grapple while turning to the right until it is freeof the fish. If you doped the bowl thoroughly prior to running, it will be a loteasier to remove.

g. If for some reason you can not release the overshot, lay it down with the fishin it. Take the entire assembly to a machine shop to have them release theovershot from the fish. Do not tear up the overshot trying to get it off. Veryoften the fish can be removed with a little machine work, salvaging most or allof the overshot.

4. Downhole on production rigs.

a. For the most part, you will be depending on hydraulic tongs for rotation.

b. As with rotary usage, bump down on the overshot and turn it with thetongs.

c. Pick up easy and turn the string until it is free of the fish, being carefulnot to pull up too much on the grapple. Most fish on a work over rig canbe removed from the overshot on the ground more easily and safely thanin the slips.

The Oversocket Fishing ToolThe Oversocket fishing tool is a combination overshot and a Keylow socket thatoffers the strength of an overshot and the wide catch range of a Keylowsocket. It is offered by Bull Dog Tool, Inc. of Hobbs, New Mexico. The phonenumber is (505) 393- 1056.

The body of the tool has two separate bores; the first is parallel to thelongitudinal axis of the body but off-center to the outside diameter. The secondis at an angle to the first bore and concentric to the first bore at the lower endof the body. A pair of keys running vertically and parallel to the angled bore aredesigned to only retain a slip in the body of the tool at the proper alignment, notto sustain any stress from pulling on a fish. A set of slips ranging from minimumto maximum catch are designed to ride in the angled bore retained by the keys.

The back side of the slip has the same radius as the angled bore and is fullysupported against the angled bore as the slips ride up and down. Teeth are cuton the front side of the slip where they can engage the fish as it is pinchedbetween the slip and the opposite side. A set of five slips give the standard4-11/16-in. OD tool a catch range from 5/8-in. to 3-1/8-in. Each slip has a1/2-in. catch range.

A complete tool consists of a top sub, body, slip, guide bushing and bottomguide. Guides are available with either a cut lip or mill type bottom. The guidebushing is key-locked to the body and guides the fish into the off-center bore inthe body of the tool. The bushings are available in a variety of designs to controlthe size of the opening and permit dressing with kutrite to a specified size.

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Page 7-30 October 18, 2000

The Oversocket can be run with an extension, or in conjunction with anovershot dressed to catch tubing and the Oversocket dressed to catch rods.

Table 7-7: Overshot Fishing Tool - Available Sizes

Tool Size Catch Range Number TensileSeries No.

OD -inches inches of slips Strength Ibs.

12 - 100 3-3/4 5/16 - 2-5/16 4 187,000

12 - 200 3-7/8 7/16 - 2-7/16 4 187,000

12 - 300 3-15/16 7/16 - 2-7/16 4 282,000

12 - 400 4-1/2 1/2 - 3 5 332,000

12 - 500 4-11/16 5/8 - 3-1/8 5 332,000

12 - 600 4-3/4 1/4 - 3-1/4 6 332,000

12 - 700 5-3/4 1/4 - 4-1/4 8 432,000

12 - 800 5-15/16 7/16 - 4-7/16 8 450,000

12 - 900 6-1/8 5/8 - 4-5/8 8 468,000

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October 18, 2000 Page 7-31

Figure 7-8: Oversocket Fishing Sequence

Clulow Socket OvershotOne special tool is available when the fish is splintered or is very small such as tubingor pump rods. This tool is the Clulow socket made by Townsend Machine Company.Clulow sockets are available in three sizes only (Table 7-8).

Table 7-8: Clulow Sockets

Size (OD) Description

3-3/4-in.Has a 2-3/8-in. EUE pin and the cut lip guide is cast into the body.This tool can be ordered with a Bowen B-1837 top sub and guide.Maximum catch size is 2-1/16-in. OD

4-11/16-in.Uses Bowen #6662 top sub and guide. Maximum catch size is 3-1/16-in. OD

5-3/4-in.Uses Bowen #6112 top sub and guide. Maximum catch size is 3 -21/32-in. OD

The two larger sizes have five slips and only one slip is used at the time. The smallesttool has four slips. The larger tools use the Bowen overshot top subs and guides. AClulow socket could be used to fish for coil tubing.

Releasing SpearsThe preferred tool for fishing inside drillpipe, tubing or casing is the releasing spear.There are many types of spears, but the most popular ones are the Bowen-Itco type,the Bowen Full Circle and the Houston Engineers rotating and releasing spear.Bowen offers a flush type and a shoulder type. When running the spear, check toinsure that it is the correct size for the pipe to be caught and is properly assembled.Refer to the Bowen instruction manual catching range table at the end of section B.For example, a grapple to catch 9.625-in. by 47 to 58# casing will have a nominalcatch range of 8.597-in. with a minimum of 8.435-in. and a maximum of 8.755-in. Besure to check the gap of the spear grapple which is marked on the tang. Tape thegrapple in the catch position prior to running into the hole. A packer assembly may berun on the bottom of the spear to pack off. A bumper jar is also required to aid inreleasing the spear.

To engage and pull the fish, perform the following steps.

1. Lower the string slowly until the spear has entered the fish to the desired depth orthe stop sub.

2. If the fish is not caught, rotate one full turn to the left to make sure the grapple isstill in the catch position. This turns the mandrel down through the grapple, puttingthe grapple in the catch position. A straight pull will then wedge the grapple intopositive engagement with the fish.

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To release from the fish, perform the following steps.

1. Bump down with the bumper jars and/or the weight of the fishing string to breakthe engagement.

2. Rotate one round to the right at the tool. This moves the mandrel upward throughthe grapple, forcing the grapple down against the release ring and putting thespear in the release position.

3. If the spear does not release, bump down again then simultaneously rotate to theright while elevating the string until the spear is clear of the fish.

The Bowen spear has a mule shoe, a mill type, or a sub type nut. When it is desired torun an internal cutter below the spear, a sub type nut is installed in place of the bullnose nut. Sufficient pipe is made up between the internal cutter and the spear toenable the spear to remain above the fish during the cutting operation. After the cuthas been completed, the spear is lowered into the cut off section to retrieve it.

If circulation through the fish is desired, install the proper size spear pack off on thesub type nut. After the spear has engaged the fish, circulation through the fish addslifting power to the pulling force applied to the fishing string. At the same time itbegins to break down the formation between the fish and the wellbore to help free thefish. A spear pack off should always be installed if fishing in an open hole.

The releasing spear ratings are listed in Table 7-9.

Table 7-9: Releasing Spear Rating

Criteria Rating Illustration

Strength 100

Circulation 0

Wireline 40

Jar Up 80

Jar Down 20

Torque capabilities 60

Releasable 100

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Bowen Full Circle Releasing Spear

The Bowen Full Circle Releasing Spear is designed to assurepositive internal engagement over a long section of a fish. Thedesign of the full circle slips and the effect of the tapers of thebody upon the slips cause the expansion strain to be distributedevenly over a long vertical section and virtually over the entireinner circumference of a fish.

Lower the fishing string until the spear has entered the fish tothe desired depth. Rotate the string at least 1/6 turn to the leftand the pull on the fish by raising the fishing string. To release,bump down and rotate 1/6 turn to the right and pick up.

Houston Engineers Releasing SpearThe Houston Engineers Releasing Spear is very similar to the Bowen Itco spear. Thespear consists of a mandrel, grapple, bull nose nut and releasing ring. Larger toolsmay be purchased with segmented grapples for extended catch ranges. The spearmay also be purchased in extended length. The longer mandrel of the heavy dutyspear engages the fish over a larger area without damage or distortion of the fish. Thegrapples are made of Carburized grade steel.

The Houston Engineers universal rotating and releasing spear will transmittremendous torque in back-off operations, yet maintain an easy positive release.There are five major parts to the spear, all of which are locked together and cannotunscrew in the hole. Even after high torque loads in either direction, this spear can bedisassembled by hand for field maintenance. Full bore is maintained in all sizes tofacilitate the use of wire line equipment. The slip is the only part exposed to extremewear for this long life tool.

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The spear is run in the catch position, however if the fish is not engaged, one round ofleft hand rotation at the tool will reset it to the catch position. An upward pull will setthe slip in the fish. If torque is required, pull 30,000 to 40,000 pounds to set the slipsecurely, then slack off to 3,000 pounds over pull. Torque can then be applied in eitherdirection

SP

E

AR

S

PE

AR

S

T O P

S

PE

AR

PACKO F F

F i g u 4 57 -9 : 5 Spear with stop and Pack-off H . E . R e l e a s i n g S p e a r A c c e s s o r i e s The accessories listed below add versatility to the releasing spear tool.·5The type “F” stop sub is designed to be used in conjunction with the flushmandrel. The stop is designed to run above the H.E. spear limiting theengagement depth.·5The type “S” over size stop ring is used when a large OD stop is required. Thestop is installed on the shoulder mandrel using set screws.·5The mill type nut is used in place of the standard bull nose to mill the top of thefish to enable the spear to enter or to clean out other foreign objects.

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• The side hill nut is used in place of the bull nose and aligns the spear with a fishthat is embedded in the wall of the hole.

• The sub type nut is used in place of the bull nose and allows other tools to be runbelow the spear. The spear pack-off assembly is run on the sub type nut belowthe spear to enable circulation through the fish. The assembly consists of anadapter sub, packer thimble, packer and flush mandrel.

• The segmented grapple assembly is used to catch casing up to 20″ in diameter.The assembly consists of a grapple body, grapple segments, and grapple segmentscrews.

F Stop Sub Mill Nut

S Stop Ring

Sidehill Nut

Sub Nut

Pack-Off Assembly

Segmented Grapple Assembly

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Figure 7-10: Releasing Spear Accessories

Figure 7-11: Releasing Spear Examples

Table 7-10: Full Circle Type Bowen Releasing Spears

Complete Complete

Assembly Slip Yield Strength Assembly Slip Yield Strength

Number Number Of Body - Lbs Number Number Of Body - Lbs

6067 6069 3,300,000 6723 6725 628,000

6073 6075 4,300,000 7640 7642 172,000

6081 6083 5,961,000 7648 7650 296,000

6715 6178 56,400 9337 9339 454,000

6246 6249 110,400 9342 9344 628,000

6318 6320 1,761,000 9347 9349 945,000

6684 6686 134,000 9352 9354 1,228,000

6693 6695 71,500 9796 9798 1,060,000

6701 6704 224,000 10473 10475 2,324,000

6710 6712 275,000 10536 10538 376,000

6715 6717 318,000 10608 10610 1,414,000

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Note: All listed strengths are theoretical calculations based upon the yield strengthof the material and are accurate within 20% .They refer to the tensile strength of thebody and do not relate to the strength of the fish being engaged. Thin walled or oldcorroded pipe may allow the grapple to expand to the point where it can “jump" themandrel spirals. Jarring may amplify the pull load by a factor of 3 to 10.

Figures Figure 7-12 through Figure 7-15 list the Calculated strengths of the ITCO typeBowen releasing spears and catching range. These tables are taken from the ItcoType Bowen Releasing Spears Instruction Manual. Manual number 2/2300.

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Figure 7-12: Itco Type Bowen Releasing Spear and Catching Range Table – Sheet 1

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Figure 7-13: Itco Type Bowen Releasing Spear and Catching Range Table – Sheet 2

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Figure 7-14: Itco Type Bowen Releasing Spear and Catching Range Table – Sheet 3

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Figure 7-15: Itco Type Bowen Releasing Spear and Catching Range Table – Sheet 4

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Box Tap and Taper TapSince external engagement of a fish is preferred over internal engagement, theovershot should be used wherever possible. As a second choice, a box tap or diecollar may be used. A box tap is not releasable, so a safety joint should alwaysbe run immediately above a box tap. A cut lip guide is usually made on the endof a tap to help get it over a fish.

Use the following steps when running a box tap.

1. Trip-in-hole to the top of the fish and circulate any cuttings off the fish.

2. Tag the fish lightly and rock the rotary to thread the tap onto the fish.

3. As the tap cuts threads onto the fish, slack off while watching the weightindicator to accommodate for thread makeup.

4. Use straight pick up to pull the fish rather than jar, as jarring might free thetap from the fish.

5. It is difficult to gauge the correct amount of torque while making up a tap,however, when made up properly, a box tap can hold up to 100,000 pounds.

Run a taper tap only after the following points have been considered:

• Taper taps do not allow wireline instruments to pass.

• Circulation ability is very limited.

• Taper taps are brittle and can break. They cannot be bumped down on.

• Taps are non-releasable; run a safety joint and a bumper sub.

Figure 7-16: Box and Taper Tap BHAs

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Table 7-11 and Table 7-12 list the ratings for the box tap and taper taps respectively.

Table 7-11: Box Tap or Die Collar Rating

Criteria Rating Illustration

Strength 40

Circulation 0

Wireline 100

Jar Up 20

Jar Down 20

Torque capabilities 40

Releasable 0

Table 7-12: Taper Tap Rating

Criteria Rating Illustration

Strength 40

Circulation 0

Wireline 0

Jar Up 20

Jar Down 0

Torque capabilities 40

Releasable 0

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Pin Taps and Hollow Pin TapsWhen conventional releasing tools have failed because of a split or flared box, a pintap may be successful. A pin tap is used to engage a fish to make a back-off. The tapwill make up in damaged threads and have a full ID for wire line work. The threadedsection of the pin tap is longer than the API pin for a given thread. Pin taps are madefrom heat treated steel and are Carburized for hardness and strength. They areavailable with right or left handed threads.

A hollow pin tap is used when a shoe or length of washpipe has twisted off leaving afish sticking out of the top. The taps have the same ID and connection as thewashpipe they will be run on. The large inside diameter allows the pin tap to swallowa fish and thread into the twisted off shoe or washpipe. They have Carburizedwickers for hardness.

The ratings for the pin taps are listed in Table 7-13 and the ratings for hollow pin tapsare shown in Table 7-14.

Table 7-13: Drill Pipe Pin Tap Rating

Criteria Rating Illustration

Strength 8

Circulation 0

Wireline 10

Jar Up 4

Jar Down 0

Torque capabilities 8

Releasable 0

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Table 7-14: Releasing Spear Rating

Criteria Rating Illustration

Strength 6

Circulation 0

Wireline 10

Jar Up 4

Jar Down 0

Torque capabilities 6

Releasable 0

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Notes:

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Fishing Best Practices Manual

Jarring Operations

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

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Contents

Introduction........................................................................................................................8-3

Bumper Jars (Mechanical and Lubricated) ...........................................................................8-3

Bumper Sub Operation....................................................................................................8-4

Hydraulic Up Stoke Jars .....................................................................................................8-4

Hydraulic Up Jar Operation.............................................................................................8-5

Mechanical Up Jar Operation..............................................................................................8-6

Accelerator Jars.................................................................................................................8-6

Hydro-Mechanical Dual Acting Jars ....................................................................................8-7

Additional Jarring Procedures..............................................................................................8-8

Jar Failure..........................................................................................................................8-9

Pump Open Force...........................................................................................................8-9

Notes:..............................................................................................................................8-10

List of Figures

Figure 8-1: Hydraulic Jar Operation, 1 of 2 ................................................................................8-5

Figure 8-2: Hydraulic Jar Operation, 2 of 2 ................................................................................8-5

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IntroductionJars are used to release most stuck tool strings. They are available in a wide range ofsizes. Jars are normally full opening allowing fluid circulation and wireline tools suchas a free point tool or back off string shot to pass through them. Jars are run aboveany tool that may stick or any tools that may require a bump down on to effectrelease of a grappling device. They are capable of delivering an immediate highimpact blow in either direction, which enhances the chances of release. Jars work bydelaying the tripping action until the fishing string has stretched storing energy. Theenergy is released when the jar trips or fires. The force of the jarring blow isinfluenced by many of the following factors:

• Length of the jar stroke

• Hole friction

• Number of weight members above the jar [the hammer]

• The amount of stretch in the drill string

• The amount of overpull exerted prior to the jar tripping

• The upward movement speed of the hammer

CAUTION: Always get permission from the Company Man before any jarring operation isstarted if there is a top drive on the rig. Jarring can damage the top drive.

• Jar Accelerator/Intensifier

• Jarring work string

Bumper Jars (Mechanical and Lubricated)Bumper jars deliver a sharp downward blow to free a fish whenever needed. Thereare two types of bumper jars the mechanical bumper sub, which is nothing morethan a slack joint, and the lubricated bumper sub. If pump pressure greater then500 psi is expected, the lubricated bumper jar should be used because it is in aclosed housing protected by seal rings. When very high temperatures are expected,the mechanical bumper sub should be used. High temperatures may destroy theseals in the lubricated bumper jar. Splines built into the jar prevent internal rotation,therefore high torque can be transmitted through the jar to effect release. Uses forbumper subs include the following:

• Aid in the release of grappling tools (overshot or spears)

• Jar down on a fish to free it

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• To provide a means to move the work string approximately 18 inches if thestring is attached to a stuck fish.

• Help to get over the top of a fish.

• Apply a predetermined amount of weight to tools such as internal mechanicalcutters.

• To swage out collapsed casing.

• To run above a marine swivel to compensate for rig movement on floating rigs.

Some uses for lubricated bumper subs are as follows:

• Use a lubricated bumper sub instead of a mechanical bumper sub.

• More sealing elements, not as likely to wash out.

• In hot holes, a mechanical bumper sub is used, the heat will damage the packingin lubricated ones.

Bumper Sub OperationTo operate a mechanical or lubricated bumper sub perform the following steps:

1. Close the jar mandrel and mark the pipe for reference.

2. Pick up on the string until the mandrel is fully extended. This is determined whenthe weight indicator shows the free travel as the bumper sub is opening and thena rapid gain is noted on the weight indicator when the mandrel is fully extended.

3. Drop the string as fast as possible and stop abruptly a few inches above thereferenced mark. The elasticity of the string, plus the law of inertia, will causethe bumper sub to move downward rapidly, delivering a sharp blow to the fish.

Note: This procedure requires a little practice and finesse.

Hydraulic Up Stoke JarsThere are two basic types of jars, mechanical and hydraulic.The terms mechanicaland hydraulic refer to the method of tripping the jar. Hydraulic jars use hydraulic fluidto delay tripping the jar.

Tripping is delayed until a sufficient pull-load (stretch) is applied overcoming thetrapped oil in the jar. The jar then trips applying a high impact blow to the fish. Whenoverpull is applied to the jar, the time delay is provided by hydraulic fluid being forcedthrough a series of small jets (Figure 8-1). As the hydraulic oil is metered through thejets, the piston is slowly moving upward until it reaches an enlarged fluid bypass. Thisallows a rapid release of the fluid and the jar fires (Figure 8-2). The jar firing delay is

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determined by a combination of load applied and time. Do not exceed themanufacturers recommended maximum jarring load and do not exceed the tensilestrength of the fishing tools or work string.

Note: A computer program is required to precisely determine optimum jarplacement in deviated holes.

HydraulicFluid

Large Bore Area Pressure Housing

PressurePiston

InnerMandrel

Figure 8-1: Hydraulic Jar Operation, 1 of 2

Large Bore Area Pressure Housing

PressurePiston

InnerMandrel

Figure 8-2: Hydraulic Jar Operation, 2 of 2

Hydraulic Up Jar OperationTo operate a hydraulic up stoke jar perform the following steps:

1. Close the jar mandrel and mark the pipe for reference.

2. Pick up 20,000 lbs. over pull and let the jars bleed open.

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3. Take a significant over pull and mark the pipe for reference.

4. Close the jar mandrel again (the previous mark should be at the rotary).

5. Pull up approximately 1/2 of the jar manufacturers maximum jarring load and waitfor the jar to fire.

6. Slack off slowly (this saves the seal integrity) to cock the jars.

7. Check to see if any progress has been made by the position of the referencedmark on the pipe.

8. Continue jarring, while raising the overpull in 10,000 lb. increments every 15-minutes until the maximum jarring load is reached.

9. Continue jarring at the maximum jar capacity until the fish is freed, the jars wearor a decision is made to do something else because of a lack of progress.

Mechanical Up Jar OperationMechanical jars have a preset load setting that causes the jar to trip. They aresensitive to load only and not time. One must pull the preset load before themechanical jar will trip. Since hole friction can account for up to a 50% loss in thepull, mechanical jars are not recommended in holes with an angle greater than 30degrees. In cases where two jars are run, the mechanical jar would be the upper jar.

To operate a mechanical up stroke jar perform the following steps:

1. Close the jar mandrel and mark the pipe for reference.

2. Pick up on the string until the predetermined load is achieved. The jar will thenfire.

3. Remember, the mechanical jar is fired only by pulling the correct over pull.

4. Time has nothing to do with it.

Note: Jarring should start in the opposite direction to that which got the stringstuck.

Accelerator JarsAccelerator jars are know as accelerator, intensifier, booster and slinger jars. Thismanual uses the term accelerator jars. The accelerator consists of an outer barreland an inner mandrel. The inner mandrel slides in and out of the outer barrel. Thetwo are connected by an interference fit between a piston chamber on the outerbarrel and a piston in the inner mandrel. The piston chamber contains a solid, a fluidor a gas that acts as a spring. When a force is applied to the accelerator, the toolopens. The extension is dependent upon the applied force. When the extended force

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is released (the hydraulic jar fires) the tool closes under the spring force of thesubstance inside the piston chamber. The following are some of the uses for theaccelerator jar:

• Intensify the jar blow

• Compensate for the lack of stretch in a short workstring

• Compensate for slow contraction of the drill string caused by high side-wallfriction.

• Act as a reflector to the shock wave traveling up the workstring protecting thesurface equipment and work string.

Hydro-Mechanical Dual Acting JarsThe Bowen hydro-mechanical drilling jar is a dual acting combination tool. Thehydraulic mechanism is used only during up jar operation. The down jar is a frictionmechanical system. The metering action of the hydraulic mechanism is controlled byports on an insert within a piston. This configuration differs from other types, such asthe Dailey Jars.

The Dailey hydraulic jar consists of an inner mandrel and an outer mandrel. Theinner mandrel has two pistons that seal on the outer mandrel. Between the twoDaile50.c -0.127526on an ice Tfl posiism is Wb.

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Additional Jarring ProceduresThe correct use of jars and the correct application of jarring is critical to freeing stuckpipe.

the natural instinct of a driller is to jar up if the string becomes stuck when pulling outof the hole. If the string is packed off above a stabilizer, jarring up may make thesituation worse by compacting the pack-off.

One reason for the jars not firing is miscalculating the required pull at the surface tofire the jars. All jars have a firing force window for each direction that they fire in.A dual acting jar (one that can fire up or down) will have an up jar force and a downjar force envelope. The firing force envelope consists of two forces, one to cock thejar and one to fire the jar. A dual acting jar will therefor have two force envelopes,one for up jarring and one for down jarring. The jar envelope forces must beconsidered at the jar and at the surface. The jar firing force at the jar is known. It isthe drillers job to determine the required firing force at the surface.

For example, a compression force of 5,000 pounds is required to cock the jarin order to fire up. This is to overcome internal friction. Once cocked, the jarwill fire when the force at the jar reaches the predetermined firing load, lets say90,000 pounds. This is for a mechanical jar. To fire down at a predeterminedload of 20,000 pounds, 5,000 pounds must be applied to overcome internalfriction, plus another 20,000 to fire the jar. The fixed limits of 90,000 and20,000 are typical of mechanical jars.

A hydraulic jar will fire as long as the jar's internal friction is exceeded. The timerequired to fire is inversely proportional to the force applied; the greater the force, theshorter the waiting time. We have only considered the forces at the jar so far. Onlythe driller knows the force at the surface and must estimate the force at the jar.

It is usually easy to see on the weight indicator when the jars are opening or closing.The measured weight indicator needle will stop moving for a few seconds while thestring is still being moved up or down. This is a good indicator that the axial neutralpoint at the jar has been reached. This is often observed while drilling vertical wells,but can be difficult to observe in highly deviated, extended reach or horizontal wells.If this neutral weight is observed on the weight indicator, it is easy to determinesurface jarring forces. The measured weight at which the neutral point is observed isrecorded. The up trip force (mechanical only) is added to this value along with any updrag.

When stuck, any pull on the string results in an increase in drag over and above thenormal up drag. The full amount of overpull at the surface will not reach the jar. Indeviated wells this must be compensated for by additional overpull. If the pumps arerunning, then the pump open force must also be subtracted from the firing force ifjarring up, and added to the set down weight to cock the jars. The pump open force

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charts are found in the manual for the jar being used. The down trip force(mechanical only), the down drag, and the pump open force are subtracted from theneutral point reading.

Jar FailureJars thought to have failed in the field frequently test successfully in the shop. Thereason for this appears to be the inability to fire the jars, often in the down direction.An estimation of the force required to fire the jars is not always performed correctly.This section explains why jars fail and how to use the correct surface pull to fire thejars. Common reasons for jar failure include the following:

• Incorrect weight applied to fire the jar, assumptions in calculations incorrect.

• Pump open force exceeds compression force at the jar (no down jar action)].

• The string is stuck above the jar

• The jar mechanism failed

• The jar was not cocked

• Hole drag is high enough to prevent sufficient force to be applied at the jar to fireit (usually mechanical jars).

• The well path prevents compression being applied to the jar (no down jar action).

• The jar is firing but cannot be felt at the surface.

• Right hand torque is trapped in torque set mechanical jars.

• Not waiting long enough for the jar to fire.

Pump Open ForceThe jar pump open force (also called the jar extension force) is the effect of thedifference in surface areas of the jar exposed to pressures on the outside and insideof the jar. When a differential pressure exists, it causes a force that opens the jar.The effect on jarring can be considerable, if for example 2,000 psi is trapped insidethe jar when the string is packed off below the jar the pump open force acts to:

• Assist in firing the jar up.

• Assist cocking the jar after firing down.

• Oppose firing the jar down.

• Oppose cocking the jar after firing up.

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Notes:

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Fishing Best Practices Manual

Fishing in Lateral Wells

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

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Contents

Introduction........................................................................................................................9-3

Jars................................................................................................................................9-3

Tips on Torque Setting ....................................................................................................9-4

Example Job............................................................................................................9-5

Fishing String.......................................................................................................9-6

Impact and Impulse..............................................................................................9-6

Top of Fish is Inside the Casing ............................................................................9-7

Jars in Vertical Section.........................................................................................9-7

Impact and Impulse with no accelerometer jar .......................................................9-7

Notes:................................................................................................................................9-9

List of Figures

Figure 9-1: Avoid pulling pipe into the wall/ free point with torque................................................9-5

List of Tables

Table 9-1: Hole Description ......................................................................................................9-5

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IntroductionIn most cases, you can use the same attachment tools to fish in lateral wells that youwould in any vertical well. Success or failure depends on the design of the fishingstring, jar placement, and the backoff point.

Sliding friction, drag, tensile and torsional loads are much higher in extended reachwells. Inverted drill strings are used for this reason. Drill collars are kept in thevertical section of the hole. In the vertical position, weight members are effective inpushing the lower drill pipe sections to the bottom to maintain weight on the bit.Flexible service drill pipe, spiral weight, or heavy-weight is used in the angle buildingsection of the well, drill pipe is used in the horizontal section. A build-up rate of 20degrees per hundred feet can be achieved without damage to the tubulars. This isallowed because drill pipe in the curved and high angle sections of the well canwithstand large compressive loads without buckling. This concept is used in fishingoperations in highly deviated holes.

JarsMost fishing in lateral wells is performed in the jarring mode, one reason for this isbecause operators are reluctant to run washpipe in deviated holes.

Before a jarring operation can be put in place, a free point and back-off must be madefirst. After the free point has been located, study the well plot carefully and checkingfor true dog legs before deciding where to make the back-off. The backoff must bemade at the depth that offers the best chance of connecting to the fish. Ask for acopy of the directional drillers slide sheet.

Note: Do not back-off just below a dog leg or in the hole curve if possible.

Develop a plan for the most effective bottom hole configuration and jar placementprior to the back-off.

Do not place the jars in the curve (Figure 9-1). Place them either in the verticalsection or in the straight section below the curvature. If the fish is parted below asevere dog leg, it may not be possible to reach it with standard jarring assemblies dueto stiffness in the BHA going around the curvature.

In high angle holes, take extra care to get an accurate free point. You must rely ontorque readings to get a good free point. It’s almost impossible to get a good stretchreading due to the pipe partially sticking each time it is pulled into the wall with excesstension. Work the pipe down good before running the free point tool and then avoidpulling it into the wall again. Set the weight at slightly less than neutral. Experience isinvaluable during this type of procedure. Use a drill pipe swivel to aid in the operation

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and a long snub line, with a torque gauge, to determine if the torque is beingtransmitted down hole.

Run a combination shot to avoid wasting time while tripping the wireline for the shot.Fire the shot on the run to avoid line creeping. The process of getting a successfulback-off could take several hours, so be patient.

No effect will be noticed on the surface when the shot is fired, but this does not meana back off will not occur. After the wireline has been pulled up out of the way, workthe pipe until it backs off or you determine it is not going to. It may be necessary tofire another shot using a higher grains per foot shot.

Jars work by delaying release of the pull load until after the string has undergone itsstretch, thus providing sudden impact instead of gradual force. To move a fish, theimpact load must exceed the sticking force. The combined effect of the impact loadand duration is called impulse. Optimum jar placement occurs with the largest impulsefor an impact load greater than the sticking force. Jar effectiveness is determined bythe placement of the jars in the string relative to the attachment tool and the drillcollars or spiral weight drill pipe.

Tips on Torque SettingRely on torque readings rather than stretch.

1. To take a torque reading, set the weight at slightly less than the neutral weight.This tends to reduce hole drag around the curve while rotating to get a torquereading.

2. Carefully work the torque down, one round at the time, using a long snub line,with a torque gauge.

3. Fire the shot on the run to prevent line creeping.

The process of getting a successful free point and back off could take several hours,so be patient. Do Not Be Discouraged. When a string shot is fired, no effect may befelt at the surface. Pull the WL out, to see if the shot fired. Work pipe with torqueuntil you get it backed off or determine that it will not backoff. If necessary fireanother shot using a higher grains per foot shot.

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October 18, 2000 Page 9-5

Pipe sticking here whilefree pointing with

stretch, appears jars not

working below

F i s h i n g J a r s

B u m p e r S u b

Stuck Point

Figure 9-1: Avoid pulling pipe into the wall/ free point with torque

Example Job

Given:

7 5/8-in. casing

6 1/2-in. hole

BHA stuck at 8690-ft (60-ft up from the bit)

Number Length lb/ftDrill collars:

2 30 50

The hole description is listed in Table 9-1. The fish is differentially stuck.

Table 9-1: Hole Description

Interval Description Angle Depth/length

1st straight hole 0° 8,000-ft.

2nd build angle 20°/100-ft. 450-ft.

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Page 9-6 October 18, 2000

3rd straight hole 90° 300-ft.

Miscellaneous Data Input

Mud weight (lb/gal) = 10.5

Friction factor between string and hole=0.5

Maximum pull at jar = 100,000

Fishing String

Component No. Length (lb/ft)

drill pipe 33 30 13.30

intensifier, hevi – weight 12 30 25.30

Jar, 3-1/2 DP 1 30 13.30

Bumper, 3-1/2 ph4 tbg. 1 30 16.70

5-3/4 o.s. (may use right hand wicker grapple) if back reaming required.

Parameters for 3-1/2-in. PH 4 Tubing

I.D. of tubing is 2.480

Tension yield for P-110 is 503,000 lbs.

Make up torque is 9,500 ft/lbs.

Maximum torsional yield is 11,900 ft/lbs.

Parameters for 3-1/2-in. X 13.3 # S135 Drill Pipe

Tension yield is 488,820 lbs.

Impact and Impulse

Pull load (lb) = 100,000% of peak

Weight Jts. = 12 HWDP1 JT. 3-1/2 PH 4

One joint of the tubing is in the BHA

Impact No. Length Impact Impulse

5 2 60 382,629 2,794

10 2 60 382,629 2,794

20 3 90 339,162 3,247

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October 18, 2000 Page 9-7

Top of Fish is Inside the Casing

Impact and Impulse

Pull load (lb) = 60,000% of peak

Weight Jts. = 12 HWDP1 JT. 3-1/2 PH 4

Impact Impulse Pull Load Impact

5 60,000 274,604 8,435

10 60,000 274,604 8,435

20 60,000 274,604 8,435

By leaving the top of fish inside the casing, the possibility of connecting to it isretained, while the impact is good using 8 joints of HW below the jars.

Jars in Vertical Section

Pull load (lb) = 60,000% of peak

Weight Jts. = 12 HWDP1 JT. 3-1/2 PH 4

Impact Impulse Pull Load Impact

5 100,000 152,053 1,087

10 100,000 152,053 1,087

20 100,000 134,081 1,150

Poor impact and impulse is the result of placing the jars in the vertical section insteadof the horizontal section of the hole.

Impact and Impulse with no accelerometer jar

Pull load (lb) = Varies Weight Jts. = 2 HWDP

Pull Load Impact Impulse

20,000 41,154 309

30,000 63,408 479

40,000 85,662 648

50,000 107,915 818

60,000 130,169 988

70,000 152,422 1,158

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Page 9-8 October 18, 2000

80,000 174,300 1,325

90,000 196,086 1,493

100,000 217,778 1,661

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Notes:

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Fishing Best Practices Manual

Cased Hole Fishing

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

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Contents

Introduction......................................................................................................................10-5

Mud Stuck Tubing ............................................................................................................10-7

Sand Sticking....................................................................................................................10-8

Mechanical Sticking - Stuck Packer...................................................................................10-9

Bowen External Cutter ................................................................................................... 10-12

Running-In Precautions ............................................................................................... 10-16

Bowen Hydraulic External Cutters............................................................................... 10-25

Bowen Internal Cutter .................................................................................................... 10-31

Bowen Collar Finder....................................................................................................... 10-35

Weatherford Pressure Cutter .......................................................................................... 10-35

Retrieving Spears and Mills ............................................................................................. 10-36

Weatherford J-B Bushing............................................................................................ 10-37

Assembly ............................................................................................................... 10-37

Running Procedure.................................................................................................. 10-37

Releasing Instructions.............................................................................................. 10-38

Parameters and Observations .......................................................................................... 10-41

Milling Rates .............................................................................................................. 10-41

Rotary Shoes .......................................................................................................... 10-41

Packers...................................................................................................................... 10-43

Weatherford Washover Type Packer Milling Assembly .................................................... 10-47

Mechanical Sticking........................................................................................................ 10-54

Exercise..................................................................................................................... 10-58

Procedure One ....................................................................................................... 10-59

Procedure Two....................................................................................................... 10-60

Procedure Three..................................................................................................... 10-61

Procedure Four ....................................................................................................... 10-62

Procedure Five ....................................................................................................... 10-62

Notes:............................................................................................................................ 10-64

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List of Figures

Figure 10-1: Cased Hole Fishing Decision Chart.......................................................................10-7

Figure 10-2: External Tubing Cutter....................................................................................... 10-11

Figure 10-3: Slip Assembly, exploded view............................................................................. 10-14

Figure 10-4: Cutter, exploded view........................................................................................ 10-16

Figure 10-5: Bowen External Cutter Assemblies .................................................................... 10-18

Figure 10-6: Bowen Mechanical Cutters Specifications and Replacement Parts (page-1) .......... 10-19

Figure 10-7: Bowen Mechanical Cutters Specifications and Replacement Parts (page-2) .......... 10-20

Figure 10-8: Bowen Mechanical Cutter Exploded View.......................................................... 10-23

Figure 10-9: Mechanical Cutter Slip Assembly, Exploded View............................................... 10-24

Figure 10-10: Bowen Hydraulic External Cutter Assembly...................................................... 10-26

Figure 10-11: Bowen External Hydraulic Cutter Parts ............................................................ 10-27

Figure 10-12: Maximum Length and Load of Tubing and Drill Pipe Picked Up with Knives, Pressureand GPM to Make Cut.................................................................................................... 10-28

Figure 10-13: Bown Hydraulic External Cutters ..................................................................... 10-29

Figure 10-14: Bowen Hydraulic Cutters Specifications and Replacement Parts ........................ 10-30

Figure 10-15: Running in and Cutting..................................................................................... 10-32

Figure 10-16: Bowen Internal Cutter ..................................................................................... 10-33

Figure 10-17: Bowen Internal Cutter Parts............................................................................. 10-34

Figure 10-18: Bowen Collar Finder........................................................................................ 10-35

Figure 10-19: Mill Out Extension, Seal Bore and No Extension................................................ 10-36

Figure 10-20: JB Bushing-1................................................................................................... 10-39

Figure 10-21: JB Bushing-2................................................................................................... 10-40

Figure 10-22: Example Packer Data Sheet............................................................................. 10-42

Figure 10-23: Rotary Shoe Examples..................................................................................... 10-43

Figure 10-24: Bowen Packer Retriever.................................................................................. 10-45

Figure 10-25: Packer Sequence............................................................................................. 10-46

Figure 10-26: Baker Service Tool Packer Examples ............................................................... 10-47

Figure 10-27: Weatherford Washover Type Packer Milling Assembly with J Latch Type Retriever..................................................................................................................................... 10-48

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Page 10-4 October 18, 2000

Figure 10-28: Weatherford Pilot Mill Type Packer Milling Assembly with Shear Ring Type Retriever..................................................................................................................................... 10-49

Figure 10-29: H.E. & Bowen Simplex PRT’s......................................................................... 10-52

Figure 10-30: Cutting the Packer........................................................................................... 10-53

Figure 10-31: Mule Shoe Joint with “No-Go” ......................................................................... 10-55

Figure 10-32: 2 3/8-in. OD Special Washdown Mill ................................................................ 10-55

Figure 10-33: 9 5/8-in. 47 pound casing.................................................................................. 10-56

Figure 10-34: Seven-inch 29 pound casing.............................................................................. 10-56

Figure 10-35: Seven inch 35 pound Casing ............................................................................. 10-57

Figure 10-36: Worst Case – All Three Major OD of the Strings Coming Together at the Same Time..................................................................................................................................... 10-57

Figure 10-37: Baker A-5 Dual Packer Retrieval Method One ................................................. 10-59

Figure 10-38: Baker A-5 Dual Packer Retrieval Method Two................................................. 10-60

Figure 10-39: Baker A-5 Dual Packer Retrieval Method Three............................................... 10-61

Figure 10-40: Baker A-5 Dual Packer Retrieval Method Four and Five, Inside-Outside BackoffCollar............................................................................................................................. 10-63

Figure 10-41: Rope Spear ..................................................................................................... 10-63

List of Tables

Table 10-1: Outside Cutter Dimensions.................................................................................. 10-10

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IntroductionThere are several differences between openhole and casedhole fishing including

• metallic junk in a cased hole is more hazardous than in an open hole. A fewpieces of junk or cuttings on top of a fish, inside a cased hole, may make itimpossible for a tool to work .A few pieces of junk can foul the slips of a packerand make it impossible to set or pull.

• The small clearances in cased holes increase the chance of sticking because ofsand or junk.

• The junk has no place to go and can’t be walled off as in open hole.

• The fishing string is usually tubing that will not take the torque and weight loadsthat can be imposed on drillpipe. Some times it is necessary to bring in largerequipment to be able to use drillpipe instead of tubing, and be able to have thecapabilities of a rotary.

The most common workover fishing job involves stuck tubing. The stuck tubing maybe caused by a restricted packer, congealed mud or sand in the annulus, or by acombination of these factors. By the time a fishing tool supervisor is called to the site,the well operator usually has already tried to pull free by working the pipe andcirculating.

When pulling on a stuck packer, pressure differential across the sealing element orcirculating devise may cause the tool to appear to be stuck. In this case theapplication of pump pressure on the string will often permit circulation from thebottom and free the packer. If this does not free the packer, it may be useful toperforate one or more holes in the tubing string to permit circulation. After circulationis obtained near the packer, the string may be free to pull.

If circulation cannot be obtained, or if circulation does not free the pipe, the twoalternatives are to back-off and jar or to run washover pipe.

If the string is stuck solid, it is advisable to run a string shot and back off at a couplingjust above the stuck point. In many cases the well can be circulated clean at thispoint. Rather than pull the freed tubing, it is sometimes possible to screw the tubingtogether, run another free point and back off lower in the string. If this works,proceed in this manner until the whole string is freed by circulating fromprogressively lower points in the well.

Mud sticking is caused by the setting up or dehydration of mud in the annulus. Incasedhole environments, temperature could affect some mud additives, causing themto degrade, possibly allowing the barite to settle out.

If there is a hole or leak in either the tubing or casing, fluids can enter the mud systemand contaminate it. In an openhole, several contaminates may enter the mud system

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Page 10-6 October 18, 2000

and alter its properties. Common contaminants are shales, salts, and acid gases. Anyof these conditions can cause mud stuck pipe. Mud sticking is usually encountered incasedholes.

Figure 10-1 shows an example of a decision chart used for cased hole fishing.

Pull 2-7/8-in. Tubing and seals with landing joint

Landing joint made up in

hanger

Movement at hanger

Pull tubing and seals with shoulder

type Itco spear

Chemical cut above

PBR

Mechanical cut ten feet below

hanger

Jar out hanger

Free point and BO or cut at top

of stuck point

Decision to be based on the of stuck pipe and

depth of stuck pipe

Latch in and back out PBR with Itco spear

Mill and recover packer

Bit and scrapper

Job complete

Pull seals with overshot

YesNo

No

NoYes

No

Yes

Yes

Yes

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Figure 10-1: Cased Hole Fishing Decision Chart

Mud Stuck TubingTo free mud stuck tubing, perform the following operation(s) until the tubing is free.

The best method is to:

1. Free point and back-off. On the first back-off, a fall off in the free point shouldbe avoided.

2. Circulate out

3. Screw back together

4. Work the pipe more. Work the pipe both up and down.

5. A combination shot can be run.

Note: Barite can be cement like in consistency.

Free Point Readings

Free point readings tell you whether to back off and circulate or back off and prepareto run washpipe. For instance:

7,000 = 100% free

7,100 = 90% free

7,200 = 80% free

7,300 = 70% free

7,400 = 60% free

These readings indicates that you could circulate, work pipe, etc. and recover a lotmore fish before running washpipe.

Another example:

7,000 = 100% free

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Page 10-8 October 18, 2000

7,050 = 0% free

These readings indicate that the fish is hard stuck and a washover operation isrequired using the HE washover cutter.

Sand StickingSand sticking is normally a condition that occurs with tubing, although drillpipe canalso become sand stuck. Sand sticking in tubing is caused by a hole in the tubing, inthe casing or by a packer that is not holding. These conditions allow sand to enter intothe annulus preventing the tubing from being pulled. In the case of drillpipe, the wellcan kick or blow out and cause sand to blow up the hole forming a sand bridge. If thedensity of the drilling fluid is not high enough, it will allow sand to fall out around thedrillpipe tool joints and stick the string. Sand stuck drillpipe is treated the same as sandstuck tubing.

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Mechanical Sticking - Stuck PackerOne reason for stuck tubing is a frozen packer. Packers come in a large assortmentof types and sizes. It is very important that you obtain as much information as possibleabout the manufacturer, type, dimensions, and other information regarding the packer.If time permits, contact the packer manufacturer to look up the specifics of thepacker you will be retrieving.

• Permanent packers must be drilled or milled.

• Retrievable packers are releasable usually by an up strain pull and/or right handrotation provided there is no sand on top of the packer.

Packers are generally divided into two types; permanent and retrievable. Thisdistinction becomes meaningless when the problem is the removal of a stuckpacker. A stuck retrievable packer can be just as difficult to fish as a permanentpacker. An example of popular packers and how they are set are as follows:Model Description Set Type Type

D Retainer Production Packer Hydraulic Permanent

N Retainer Production Packer Mechanical Permanent

Retreiva D Mechanical Retrievable

FH Hydrostatically Retrievable

A-5 Hydrostatically Retrievable

R-3 Weight Retrievable

Permanent packers must be drilled out or milled over to retrieve them. Retrievablepackers are releasable usually by an up strain pull and/or right hand rotation providedthere is no sand on top of them.

If the tubing is free down to the packer, sometimes a string shot fired in the packerwill release the entire assembly and allow it to be pulled. This is referred to as a rattleshot. If the rattle shot doesn’t free the packer, the tubing is cut 1/2 joint above thepacker and either jarred loose or milled over and retrieved.

If the tubing is not wireline accessible, or cannot be jarred free, it is necessary to runan external cutter on the bottom of the wash pipe string. The washover pipe andcutter assembly, along with the cutoff portion of the fish are pulled from the wellwhen the cut is complete.

The H.E. type “D H” external cutter (Figure 10-2) is designed to washover, cut, andretrieve tubulars in one trip. The dimensions of the external cutter are listed in Table10-1. The tool can be rotated and reciprocated without damage. It uses the tubingcollar or integral joint to selectively activate the cutting section when needed. Thecutter can be manipulated to cut or release from collar connected or bottle neck pipe.This is achieved without any left hand rotation, jay joints, shear pins, or pump pressuremanipulation. The DH external cutter is made up of three sections; the overshot

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Page 10-10 October 18, 2000

section, the drive section and the cutting section. The cutting section cannot bedamaged by heavy loads placed on the overshot section. The load on the knifes arefixed by the way the tool is designed. By protection the cutting section, long andheavy loads can be recovered.

After the last washover section is completed down to a packer, pull on the fish in anattempt for a total recovery. Maximum bearing loads are specified to indicate thehighest load the cutter will handle safely. For example, the 5-9/16-in. OD cutteraccommodates up to 30,000 pounds. Cuts should not be attempted at this maximumload, but should be lowered to the specified cutting load.

Pump pressure and the direction of the flow have no effect on the releasing or cuttingaction of the tool.

The weight on the indicator while making the cut should be the weight of the fishingstring, plus the weight of the fish to be cut, plus the recommended maximum cuttingload weight. To release the cutter, slowly rotate while raising it simultaneously, it willwalk off the coupling. Another way is to pick up until the cutter overshot engages thecollar, taking a one or two thousand pound strain. Then slack off one or two inchesand rotate the string to the right.

To make a cut insure that all torque is released from the string, then pick up until thecoupling is engaged. Take the recommended pull load and rotate to the right cuttingthe tubing in one to five minutes.

To release the cutter from the fish, pick-up until the overshot section just takes a littleweight. Rotate to the right 1/4-turn and the cutter will walk off or release from thefish.

Table 10-1: Outside Cutter Dimensions

Nominal Size 3-3/4 4 4-1/2 5-1/2

Actual OD INS 3-3/4 4-1/8* 4-9/16 5-9/16

Actual ID INS 2-7/8 3-3/16 3-3/8 4

Tubing to cut 1 to 1-1/2 1-1/2 to 2-3/8 2-3/8 2-7/8

Max. Load on bearing 10,000 15,000 20,000 30,000

Maximum length tubing to cut 1,000’ 1,000’-2”Eue 1,000’-2”Eue 1,000’x2-1/2”Eue

Maximum cutting load 2,000 3,000 3,000 4,000

Cutting speed 20-60 rpm 20-60 rpm 20-60 rpm 20-60 rpm

Approximate cutting time 1-5 min. 1-5 min. 1-5 min. 1-5 min.

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Figure 10-2: External Tubing Cutter

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Bowen External CutterThe Bowen external mechanical cutter is what is generally referred to as a two tripcutter. As a first step, the stuck pipe is washed over using washpipe with a washovershoe slightly larger and whose inside diameter is slightly smaller than the externalcutter to be used. This establishes adequate clearance so that the external cutter maybe lowered over the stuck pipe. Secondly, after the washover is complete, thewashpipe is pulled and the washover shoe is replaced with the outside cutter.

Ensure that the external cutter has been properly assembled with the appropriateassembly (spring dog, ratchet pawl, or slip assembly) as dictated by the tool joints orcouplings of the stuck pipe.

The spring dog assembly (Figure 10-3) is used if the pipe or tubing to be cut hassquare shouldered tool joints, couplings or collars. The springs are closed in at the topin a regular pattern to form a small opening. This allows the spring dog assembly topass collars or couplings by deflecting outwardly, but close in around the pipe ortubing so that they will always be in a position to butt up against the bottom of thecollar or coupling when raised. The springs are closed in enough to catch any sizepipe or tubing that the cutter is designed to cut.

When the optional ratchet pawl assembly is used, a single pawl spacer is used with it.The purpose of the single pawl spacer is to add extra length to the ratchet pawlassembly to make their combined length the same as a standard spring dog assembly.

The length of a ratchet pawl assembly is half the length of the spring dog assembly, sothat if two ratchet pawl assemblies are run in tandem, the single pawl spacer isomitted.

When the optional slip assembly is used, an adapter is required. This adapter islocated between the cutter top sub and body. It forms an extra length housing for theslip assembly.

The upper end of the adapter screws into the top sub, and the lower end into thecutter body. An internal shoulder is situated just below the thread at the upper end,against which the slip spring pushes. The shoulder formed by the lower pin end of theadapter maintains the slip retainer bowl in position, when assembled for service.

The thrust washer and thrust bearing are situated between the Main spring and springdog assembly ( or ratchet pawl or slip assembly). Their purpose is to allow the entirecutter assembly except the spring dog assembly to rotate during operation.

The preload sleeve is a steel cylinder and is located between the thrust washer andthe top of the main spring. The purpose of the preload sleeve is to maintain sufficientpreload on the feed ring to effect a cut at any point on the fish, without the necessityof applying a pull load from the surface. If the operator prefers, the preload sleevemay be removed. When removed, it relieves all preload on the main spring, so that theknives must be manually fed from the surface. In deviated holes, the pre-load sleeve

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October 18, 2000 Page 10-13

may be left out to prevent shearing prematurely as caused by friction, and to allow alittle more working room to manipulate the cutter.

The feed ring is a cylinder in form. It has two shear pin holes situated diametricallyopposite. Its lower face is beveled to nest below the knife cutting ends. In operation,the feed ring forces the knives inward against the fish in the most efficient manner toeffect the cut. The shear pins maintain the feed ring in running-in position until theforce exerted against them by the pull from the rig floor shears the pins, releasing thefeed ring.

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Figure 10-3: Slip Assembly, exploded view

The main spring is a large spring wound from rectangular cross-section spring steel. Itis tempered to give long trouble free service. In operation it is pre-loaded by apredetermined amount calculated to exert the best cutting load to each knife, which istransmitted through the feed ring. The main spring is situated between the thrustwasher (or spring seat), and feed ring. Once the shear pins have been sheared, noload need be applied to the cutter from the rig floor to effect a cut. The cutter may be

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October 18, 2000 Page 10-15

moved down to any point on the pipe to make a cut. This is made possible by thecalculated preload on the main spring.

The shear pin is manufactured from a clean shearing brass rod. The size of the shearpin varies with the size of the cutter. The shear strength of each shear pin is listed inthe specification table on pages 11 and 12 of the Bowen External Cutter manual.

The ratchet pawl assembly is designed to catch tapered upset integral tool joints. Theratchet pawl assembly is a thick walled cylinder which contains a number of pawls(5to8) depending on size. These pawls are arranged so that they form a circle aroundthe pipe.

They are spring loaded to allow them to be deflected by passing a coupling or collar,then return to their horizontal position after passing the coupling. In operation, theycatch against the underside of the taper, transmitting the load from the pawls, throughthe pawl body, to the main spring.

The ratchet pawl assembly will effectively catch only one size pipe as a general rule,and a separate pawl assembly must be used for each size, or the pawl assembly maybe redressed with pawls of the proper length for each size for which it is used.

The slip assembly is used where the pipe or tubing has semi-flush or external flushtool joints. The slips grip the pipe or tubing at any random point to actuate the cutterand to retain the cut off section of pipe.

The slip assembly consists of a slip bowl, slips, slip spring, slip bowl retainer, slip bowlshear pins, and slip adapter. Shear pins provide a means of releasing from the fishdownhole if necessary. See the Bowen specification tables for strengths.

Check the Bowen external cutter to be sure that it is the proper size for the pipe to becut; refer to the Bowen specification table for dimensions and part numbers. Aftermaking the cutter up to the washpipe, tighten all connections but avoid placing tongsdirectly over the knife slots. It is recommended that the knives be wedged into theknife slots to prevent their falling toward the inside of the cutter and being damagedwhile going in the hole. Loop a length of soft line around the knives and pull it towardthe outside of the body. The string will hold the knife in the slot.

The Bowen external cutter (Figure 10-4) is an automatic spring fed pipe cutter thatprovides fast and efficient cutting.

When the desired depth is reached, the cutting string is raised until the dog assemblyengages the tool joint. A strain is taken which compresses the main spring and shearsthe feed ring shear pins. The shearing of the pins is clearly apparent by a quickmovement of the weight indicator. After shearing the pins, the cut can be made at anypoint on the pipe. The spring will provide the force to feed the knives into the pipe at apredetermined rate. It is not necessary to maintain an up strain against the collar orupset unless the preload sleeve has been removed. Begin rotating slowly,approximately 40 RPM’s, until the cut is made as indicated by a loss of torque and again on the weight indicator. The cut pipe is retained by the ratchet pawl, spring dogor slip assembly, and is ready to be pulled from the hole. Do not rotate out of the hole.

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Figure 10-4: Cutter, exploded view

Running-In PrecautionsAdhere to the following precautions when running a Bowen external cutting tool.

Upon reaching the top of the fish, break circulation to flush all mud cake and debrisfrom the cutter. Check all parameters for reference. Care should be used when going

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over the top of the fish. Rotate the cut lip over the top of the fish as needed. After thefish has entered the cutter, the cutter must not be raised any more than necessary topull the rotary slips. This is to ensure that upward movement does not shear the pinsand force the knives into contact with the fish. If this should happen, it becomesnecessary to cut the fish at this point because the cutter will not pass over the nextlower tool joint or coupling without breaking the knives.

The cut should be made one joint above the lowest position to which the rotary shoewas run. This leaves one joint of free pipe below the cutter which springs away fromthe wall and aligns itself in the cutter.

The slips always contact the pipe in cutters using the slip sub assembly. Raising thecutter shears the brass pins and forces the knives in against the fish.

Do not run the pump so that pulsations are transmitted to the cutting string, becausethis will cause the knives to move up and down resulting in an uneven cutting action.

There are several different changes in the action of the cutter that may indicate to theoperator that the cut has been made, all of which will become more familiar withexperience. If a short fish is being cut, the rotary speed will pick up and the torquewill be free when the pipe is cut. If a long fish is being cut, the weight of the pipeabove the cutter may be heavy enough to pinch the knives against the lower portion ofthe fish, just before the cut is complete, causing the cutter to torque up. The weightindicator may rise slightly while rotating indicating that the cut is complete and thecutter is carrying a portion or all of the weight of the cut piece. Pull out of the holeand strip the fish from the washpipe.

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Figure 10-5: Bowen External Cutter Assemblies

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Figure 10-6: Bowen Mechanical Cutters Specifications and Replacement Parts (page-1)

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Figure 10-7: Bowen Mechanical Cutters Specifications and Replacement Parts (page-2)

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October 18, 2000 Page 10-21

Standard External Cutters

Maximum Length and Load of Tubing or D.P. to be Picked Up With

External Cutter Knives Ratchet PawlsTubing or

Cutter Length Load Length Load

D.P. Size No. Ft. Lbs. Ft. Lbs.

1/050" Tbg. 32848 1,650 1,985 1,700 2,000

1.315" Tbg. 1,500 2,800 2,000 3,600

1.315" Tbg. 666 1,200 888 1,600

1.660" Tbg. 583 1,400 875 2,100

1.900" Tbg. 47127 552 1,600 965 2,800

2-1/16" Tbg. 500 1,700 1,029 3,500

2-3/8" Tbg. 468 2,200 1,400 6,600

1,660" Tbg. 2,420 5,800 3,630 8,740

1,900" Tbg. 47167 2,275 6,600 3,430 9,940

2-1/16" Tbg. 2,088 7,100 3,150 10,725

2-3/8" Tbg. 1,830 8,600 2,804 12,900

1.900" Tbg. 379 1,100 420 1,225

2-1/16" Tbg. 47210 347 1,180 375 1,275

2-3/8" Tbg. 276 1,300 275 1,290

2-7/8" Tbg. 260 1,700 300 1,930

2-1/6" Tbg. 1,545 5,250 2,320 7,875

2-3/8" Tbg. 47264 1,212 5,700 1,850 8,735

2-7/8" Tbg. 1,061 6,900 1,610 10,500

3-1/2" Tbg. 1,000 9,300 1,515 14,100

2-7/8" Tbg. 47309 1,307 8,500 1,965 12,750

3-1/2" Tbg. 1,258 11,700 1,905 17,700

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Standard External Cutters

Maximum Length and Load of Tubing or D.P. to be Picked Up With

External Cutter Knives Ratchet PawlsTubing or

Cutter Length Load Length Load

D.P. Size No. Ft. Lbs. Ft. Lbs.

2-38" Tbg. 500 2,350 750 3,525

2-7/8" Tbg. 415 2,700 625 4,070

3-1/2" Tbg. 47360 387 3,600 570 4,555

4" Tbg. 436 4,800 655 7,200

3-1/2" D.P. 315 4,790 470 7,180

4" D.P. 47422 325 5,100 500 7,750

4-1/2" D.P. 295 5,900 450 8,925

5" D.P. 395 7,700 600 11,625

3-1/2" D.P. 350 5,400 525 8,100

4" D.P. 380 5,950 570 8,925

4-1/2" D.P. 47541 335 6,700 500 10,125

5" D.P. 446 8,700 745 13,090

5-1/2" D.P. 412 10,400 640 15,640

5-3/4" Csg. 550 12,400 830 18,640

5" D.P. 287 5,600 440 8,440

5-1/2" D.P. 250 6,300 380 9,490

5-3/4" Csg. 52689 311 7,000 465 10,540

6" Csg. 335 7,700 500 11,500

6-5/8" Csg. 299 9,200 400 12,450

7" Csg. 250 9,900 375 15,150

7-5/8" Csg. 410 16,000 600 22,660

NOTE: These are masimum static loads. If shock loaded, reduce values 50%.

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Figure 10-8: Bowen Mechanical Cutter Exploded View

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Figure 10-9: Mechanical Cutter Slip Assembly, Exploded View

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Bowen Hydraulic External CuttersBefore running the Bowen hydraulic external cutter (Figure 10-10), a washover mustbe run to free the stuck pipe from the formation. The washover pipe must beequipped with a washover shoe having an outside diameter slightly larger and aninside diameter slightly smaller than the hydraulic cutter to be used. This establishesadequate clearance so that the cutter may be lowered over the stuck pipe. It is alsorecommended that the stuck pipe be washed over for at least one full joint, belowwhere the cut is to be made, so that the pipe to be cut is centralized in the hole at thepoint of the cut. After the washover has been made, the shoe is replaced with theexternal cutter.

Use the following steps to run the Bowen hydraulic external cutter.

1. Assemble the cutter (Figure 10-11) using the proper size piston assembly and runin the hole.

2. When the desired depth is reached, start the pump with all lines open to be sureno pressure is pumped downhole.

3. With the pump at idle, slowly close the by-pass valve to pump fluid down thework string until the pressure reaches approximately 145 psi shearing the pins.

4. Open the by-pass valve to release the pressure from the work string.

5. Begin slow rotation, 15 to 25rpm and slowly close the by-pass valve again topump fluid down the work string. This will begin feeding the knives to start thecut.

The amount of pressure and gallons per minute required depends on the sizecutter and piston assembly being used. The 6-1/16-in. OD cutter requires only40psi to make a cut. See page 5 of the Bowen Hydraulic External CutterManual.

CAUTION: Use caution to avoid surging of pump pressure when starting a cut. Pressure surgingcauses the string length to expand and contract, moving the cutter up and down.This motion prevents the knives from remaining in one position when making a cutand may easily break a knife.

As with the Bowen external mechanical cutter, once the fish has entered the cutter,the cutter must not be raised more than is necessary to get the rotary slips out. If thecutter is lifted against a collar, the pins will be sheared allowing the feed ring to forcethe knives against the pipe. If this occurs, a cut should be made at this point to avoidpassing another collar and damaging the knives. Once the piston segments are runpast a collar, it may not be pulled back. However, special piston segments with athreaded front edge are available that may be walked off a coupling with right handrotation.

6. To make a cut, the string is rotated slowly and the by-pass valve is slowly closeduntil torque is encountered indicating that the knives are cutting. A rough

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chattering action followed by the smoothing of the torque signals that the cut ismade.

To prove a cut, raise the string one or two inches or until the weight of the cut portionof the fish is lifted. If the string rotates freely, the pipe has been cut.

Figure 10-10: Bowen Hydraulic External Cutter Assembly

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Figure 10-11: Bowen External Hydraulic Cutter Parts

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Figure 10-12: Maximum Length and Load of Tubing and Drill Pipe Picked Up with Knives,Pressure and GPM to Make Cut

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Figure 10-13: Bown Hydraulic External Cutters

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Figure 10-14: Bowen Hydraulic Cutters Specifications and Replacement Parts

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Bowen Internal CutterBowen internal mechanical cutters are used to cut tubing, casing, or drillpipe rangingin size from 1.900-in. tubing up to 20-3/4-in. casing. See the specification tables in theBowen catalog for sizes, part numbers, and “can be dressed to cut” sizes. The cuttermay be run on tubing or drillpipe depending on the diameter of the pipe being cut.

The cutter consists of a wiper block (or a drag spring assembly) to accomplish settingit in the pipe, slips and cone assembly to anchor the tool and a main spring touniformly feed the knives. It also has wedge-like knife blocks to drive the knives upand outward to engage the pipe, and specially hardened knives to cut the pipe. Afeature of the tool is the automatic bottom which permits the operator to set the cutterat any desired depth, to release the tool by simply picking up, and resetting the tool atanother depth without coming out of the hole.

Figure 10-15 shows the internal cutter in both the run-in and cutting positions in a well.Figure 10-16 shows a cross-sectional view of the Bowen internal cutter. The parts ofa Bowen internal cutter are displayed in Figure 10-17.

Use the following procedures to operate the Bowen internal cutter.

1. Ensure that the cutter is properly assembled, properly dressed for the size pipe tobe cut, and that all threaded connections are made up tightly. The cutter is madeup on the bottom of the work string and run in the hole.

2. Check that the automatic bottom is fully engaged because this holds the cutter ina release position while tripping in or out of the hole.

Avoid right hand rotation because this will release the automatic bottom and setthe cutter. If this occurs, slowly raise the string and the wickered sleeve will bere-engaged by the grip jaws to reset the cutter.

3. As the cutting depth is reached, rotate to the right while slowly lowering the workstring. The wiper blocks or drag springs will resist rotation and lowering bymaintaining friction on the pipe to be cut. This disengages the automatic bottomfrom the grip jaws. Continued lowering causes the slips to move upward andoutward to anchor the cutter in the pipe. The mandrel is free to travel down underthe knife blocks forcing the knives up and out to start the cut.

4. Apply slight additional weight while slowly rotating to the right. The main spring inthe cutter is partially compressed by the weight and assists maintaining a uniformfeed to the knives.

A good way to set a predetermined weight on the knives is to run a bumper jarone joint up from the cutter. When the free travel is noted in the bumper sub, thatwill apply only one joint of pipe or drill collar weight to the cutter.

5. Apply slow rotation to the right to make the cut.

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CAUTION: Don’t hurry the cut or apply too much weight as this will cause the knives to dig intothe pipe burning or breaking the knife points.

6. For best results, the string is lowered in 1/8-in. increments and a total lowering of1-1/4-in. will complete the cut. Free rotation indicates the cut is complete.

7. Prove the cut by increasing the rotary speed, if no increase in torque is noted, itwill indicate that the cut is made.

8. Raise the string one foot which will cause the grip jaws to engage the wickeredsleeve, and now the tool is ready to be raised or lowered, as desired.

Figure 10-15: Running in and Cutting

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Figure 10-16: Bowen Internal Cutter

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Figure 10-17: Bowen Internal Cutter Parts

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Bowen Collar FinderBowen collar finders (Figure 10-18) are available for all sizes of Boweninternal cutters. They enable the operator to locate the collar nearest thecutting depth. With this information, the operator can then set the cutterabove or below the located collar while avoiding cutting in a collar. Bycutting just above or below a collar, the pipe is salvaged in more usablelengths.

Bowen collar finders are made up in the bottom of the bottom nut of thecutter. A bottom nut with a threaded plug is substituted for the standardnut. The collar locators are pressed out by the springs at angles thatpermit free lowering into the pipe. When the tool is elevated, The locatorswill engage in the space between two joints of pipe, locating the collar.The collar locator is released by taking enough up strain to shear theshear pins. When the pin is sheared, the locators drop into the sleeve andare retained there. To make another run, the shear pin must be replaced.

When running in the hole it is necessary to raise the string in order to pullthe slips. Should the collar finder be located in a collar as the string iselevated, there is a spring that absorbs over eight-inches of elevationbefore any pressure is exerted on the shear pin.

At the cutting depth, elevate the string slowly until a slight gain is noticedon the weight indicator. Mark the string at this point, you have nowlocated a collar. Make the cut accordingly.

Figure 10-18: Bowen Collar Finder

Weatherford Pressure CutterThe Weatherford pressure cutter or marine cutter is designed to cut single or multiplestrings of pipe from 4-1/2- to 42-inches in diameter using pump pressure to actuateeither three or four tungsten carbide coated knives. The cutter may be used to make asingle cut from a land based or offshore rig.

Follow the steps below to operate the Weatherford pressure cutter.

1. Select the proper size cutter and knives for the pipe being cut.

2. Check the knife sweep and adjust the indicator assembly.

3. Function test the cutter, tape the knives closed and trip in the hole.

4. Find a casing collar with slight pump pressure against the knives. Open the valveto the next annulus to check for trapped pressure.

5. At cutting depth, chain the brake down, mark the Kelly and drum, and set vernierhand at zero.

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Page 10-36 October 18, 2000

6. Engage the pump, record the pump rate then shut the pump down.

7. Begin rotating at 70 to 80rpms and record the free torque.

8. Bring pump pressure up to desired rate to induce torque against the knives.

9. As the cut is made, watch for change. The torque will be erratic just prior to thecut and smooth out after the cut is made. If the pipe is in tension, a bump will beheard. Watch for a pressure drop and a weight gain on the indicator.

10. Check the well for flow and pull out of the hole.

A more in depth discussion is provided during the P. & A. segment offered in theSpecial Applications class at the Weatherford Training Center in Houston TexasUSA.

Retrieving Spears and MillsThe most common packer retrieving spears and milling tools that Weatherford has tooffer are the Weatherford (J-B) bushing, the Bowen Simplex, and the H.E. packerretrieving tool. The requirement for a mill-out extension determines which packerretrieving tool to use. When a mill out extension (Figure 10-19) is provided, any ofthese retrievers may be used. If there is no mill out extension, you should use theWeatherford (J-B) bushing.

I

II

III

PermanentPacker Mill Out Extension

SealBore

PositionNipple

W/ No-Go

PupJoint

Re-EntryGuide

Figure 10-19: Mill Out Extension, Seal Bore and No Extension

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Weatherford J-B BushingThe J-B bushing consists of two main body parts. There is the outer body withwashpipe threads on both ends, and an inner mandrel with small diameter tool joints.The outer body contains a spleen, and the inner mandrel has two corresponding J lugsto control the release or attachment procedure. Shear pins in the outer body lock themandrel in position until the attachment procedure to the fish is completed.

The outside assembly consists of a rotary shoe, suited for this particular job, withsufficient washpipe space out extensions which are attached to the lower end of thebushing. Placed above the J-B bushing are, again, sufficient washpipe space outextensions, a washover boot basket, cross over sub, jars and drill collars. Ensure thatcasing diameter, weight, and packer ID are known. Match spear grapple to thecorrect size.

The inside assembly consists of the attachment tool, spear with stop sub or tap, spaceout extensions with PRT connections, a drain sub, safety joint if required, and themandrel.

AssemblyUse the following instructions to ensure proper assembly of the JB bushing.

1. Make sure shear pins are in place and tight, noting the number and shear values.

2. Ensure enough working space is available between the rotary shoe and theattachment tool; 4 to 5-feet is recommended to work the string as needed.

3. Make sure that the inside of the rotary shoe is large enough to pass over thecatching device.

4. Ensure that there is enough washpipe above the J-B bushing to cover the fish,plus the inner mandrel and the fishing tools.

5. If a spear is used, make sure the grapple is locked in the catch position with a pinbehind the tang.

Running ProcedureRun the JB bushing according to the following procedrue.

1. Trip in the hole with caution but do not engage the fish yet.

2. Break circulation slowly to avoid shearing the shear pins and record allparameters.

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3. If using a Kelly, make sure enough length is available above the rotary to engagethe fish, release from the J-B bushing, and mill over the entire fish1.

Releasing InstructionsUse the following steps as a guide to releasing the JB bushing.

1. Slowly lower the work string and make engagement to the fish.

2. Pick up to shear the pins, then slack off about one foot while holding 1/4 round ofleft hand torque at the tool . This should clear the lugs from the spleen.

3. Begin milling operations with 1,000- to 2,000-pounds of weight to groove the topof the packer for 1/2 hour, then continue normal milling operations.

1 Disregard if a top drive is available.

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F i g u r e 10-20: JB Bushing-1pin.

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Figu.5210 -21 : JB Bushing-2

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Parameters and ObservationsMost Drillers and workover rig operators will run too much weight on rotary shoes,wearing the shoe out prematurely. The maximum weight to run on a shoe is 1,000pounds per OD inch of the shoe. The only exception to this is when space rings orother parts of a packer begin to turn freely with the shoe. This condition is indicatedby a lack of torque in the string. In this case, dry drill with maximum drill collar weightuntil the fish locks up and begins to torque again. One should mill by torque and not byweight. If the shoe is torquing up, then whatever weight is on the shoe is enough.More weight will not increase the milling rate, it will only wear out the shoe.Generally, 3,000 to 4,000 pounds on the shoe is sufficient.

Milling RatesThe milling rate for carbide is listed in surface feet per minute (SFPM) from themanufacturer. Since there isn’t an SFPM indicator on the rig, SFPM must beconverted to revolutions per minute (rpm) to be useful to the fisherman.

The optimum rpm for crushed carbide dressed mills is 150 to 200 SFPM. The SFPMfor carbide insert type mills is 150 to 300. The ideal rate for rotary shoes is 125SFPM. The formula to arrive at this is:

262.0××= rpmerMillDiametSFPM

82.3×=erMillDiamet

SFPMRPM

With clear water workover fluids, try to get the annular velocity up to 120-ft.per/minute. Pumping high viscosity pills aids in lifting the cuttings to the surface.Check the cuttings coming over the screen to help determine how the milling isprogressing.

Note: Milling torque will cause 8 round tubing to make up at least 1-in per 1,000-feet of depth.

Rotary ShoesShoe design is very important and should be custom built according to specific needs.Incorrect design will result in poor performance, requiring two or three rotary shoes todo a job that should have been done with one. Having a qualified carbide welder todress the shoes is a must. Use 1018 mild steel, to prevent cracking, and counter borethe ID so that a larger size rod can be used for better cutting performance and longershoe life. The shoe length should be at least 3 feet, with a factory made crown largerthan the tube. This allows counter boring without loosing any wall thickness. Thecrown OD should be drift size of the casing to prevent leaving a sheet of junk that will

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be hazardous to the operation. The ID will depend on the type packer to be milledover. Either flat bottom or ocean wave type shoes are generally used to mill packers.

You should dress the ID of the shoe approximately 1/4-inch greater than the OD ofthe packer mandrel on permanent packers.

Dual packers and retrievable types require that you dress the shoe to cut as little aspossible off the packer , but still cut the slips to effect release. Using a shoe with toosmall of an ID to cut over a dual packer, can cause the head receptacle to break off,causing a multitude of problems, and prolonging the job.

Other types of single string packers, such as a Baker “S-2” Hydro-Set require thatthe shoe take out everything but the mandrel to prevent the shear seal assemblyreceptacle from breaking off. In this case, use the mill type, instead of shoe type,PRT.

Figure 10-22: Example Packer Data Sheet

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Figure 10-23: Rotary Shoe Examples

PackersThe part of the overshot that seals on the fish is called the pack-off. The pack-offenables you to circulate through the bit or whatever is on the bottom of the string.There are several types of packers including the following:

• Type A packer

• Plain control packer

• Mill control packer

The plain and mill control packers are available in two types; the type “ R”replaceable seal and the type “E” Vulcanized rubber seal. Both must have an O-Ring on the outside diameter so that they seal properly.

• The type “D” collar pack-off acts as a stop and seals on the ID of a collar.

• The high pressure pack-off assembly consists of a bowl that contains severalpackers and is assembled between the overshot bowl and guide.

Other overshot accessories include the extension bowl which provides a means to getthe grapple further over the fish to engage the catch area. The extension is usefulwhere a string of drillpipe or tubing has been pulled on, stretching the tube to less thanit’s normal OD. It is also useful if you had a short stub looking up and electe to catch

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the coupling or tool joint pin. After a grapple has been released from a tube at thesame place several times, the grapple may fail to bite. You should add anotherextension and catch the fish deeper.

An example of the Bowen packer retriever and a complete retrieving unit with abushing and shoe stringer attached is shown in Figure 10-24. A packer operationalsequence is shown in Figure 10-25 on the following page.

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Simplex Packer RetrieverComplete Retrieving unit with bushing, shoe and

stringer

Figure 10-24: Bowen Packer Retriever

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Figure 10-25: Packer Sequence

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Figure 10-26: Baker Service Tool Packer Examples

Weatherford Washover Type Packer MillingAssembly

This type of assembly uses a washover shoe to cut away the least amount of packerand slips to facilitate release. The retriever assembly is a shear ring type that allowspositive location of the packer in the well bore before stinging in and milling operationscommence. Applying weight shears the upper ring allowing the grapple to collapseand pass through the packer bore in the catch position below the packer. If themilling/retrieving assembly must be released for any reason, a straight pull to shear thelower ring allows the grapple to collapse and release through the packer bore. AVariety of shear ring strengths are available to suit the depth of the packer, availableweights and rig capacity.

The rotary shoe is 8.438 OD x 7.625 ID dressed to 8.600 OD and 7.438 ID flatbottom with a 8.375 FJWP connection.

The assembly shown in Figure 10-27 is used to mill over and recover single stringpackers in 9.625 casing, in one trip, after the seal assembly has removed.

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Page 10-48 October 18, 2000

Figure 10-27: Weatherford Washover Type Packer Milling Assembly with J Latch Type Retriever

The Weatherford Pilot Mill Type Assembly (Figure 10-28) uses a replaceable heavyduty mill to cut away the complete packer body and slips to facilitate release. Thepilot mill body has an eight-inch heavy duty acme box up and is dressed to 8.625-inchOD. This tool is useful when the upper portion of a packer tends to break in twowhen being cut over with a rotary shoe.

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October 18, 2000 Page 10-49

Figure 10-28: Weatherford Pilot Mill Type Packer Milling Assembly with Shear Ring TypeRetriever

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Page 10-50 October 18, 2000

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October 18, 2000 Page 10-51

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Page 10-52 October 18, 2000

Pickup Packer Hull and Remove from Well with Spear

Cut Packer Loose with Shoe

Trip in Hole and Engage Packer

Figure 10-29: H.E. & Bowen Simplex PRT’s

An example of how to cut a packer follows and is illustrated in Figure 10-30.

1. Duals are 90% retrievable if you clean the sand off top.

2. Clean out the ID of tubing with a Sand Bailer or Coil tubing.

3. Free point both strings - make decision accordingly.

4. Cut between the packers first.

5. Attempt to release the S.S. - cut 2nd.

6. Cut the long string last.

7. Step way down at 500 foot intervals - keep the tops 1-1/2 joints apart.

8. Use a 1- or 1 1/4-in. C.S. Hydril wash string if the annulus area permits.

9. Use a smaller O.S. For example: 4 11/16-in. instead of the 5 3/4-in.

10. Run thin shoes to mill the packer.

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October 18, 2000 Page 10-53

Last cut - optional

2nd Cut

1st Cut

25’

5’

25’

Figure 10-30: Cutting the Packer

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Page 10-54 October 18, 2000

Mechanical Sticking

• Caused by the two strings wrapping around one anotherwhile running them in the hole.

• In free pointing, stretch can be transmitted deeper thantorque.

• In almost all cases a cut should be made below the dualpacker first. This maybe the only opportunity to get downwith the wire line.

• Cuts have been made and pulled just above the dual packerwith only a minimum amount of movement showing on thefree point.

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October 18, 2000 Page 10-55

2.000 1.600

1.315 O.D.1” CS Hyd. Box Conn.

No-Go

.975 I.D.

2.000

48” +/-

Figure 10-31: Mule Shoe Joint with “No-Go”

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Page 10-56 October 18, 2000

3 1/2” DSS Tubing

3 7/8” O.D. x 2.920” I.D.

9 5/8” 47#Casing (8.681” I.D.)

3 1/2” O.D.Washdown Tool

Figure 10-33: 9 5/8-in. 47 pound casing

2 7/8” O.D.EUE 8RD Tubing --3.668” O.D. x 2.441” I.D.

2 3/4” O.D.Washout Assembly

7” O.D. x 6.184” I.D.

Figure 10-34: Seven-inch 29 pound casing

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October 18, 2000 Page 10-57

2.875

2.875

2.000

Collars on2 3/8” 8-Acme

Tubing

6.004

7.000

7”

35#

Cas

ing

Washtool

Figure 10-35: Seven inch 35 pound Casing

5 1/2” 17#Casing with4.892” I.D.

Fish in Hole:1 1/2” EUE10Rd (O.D. ofCoupling)

Wash String: 1”CS Hyd. (O.D.of Upset)

Fish in Well: 1 1/2”CS Hyd. (O.D.of Connection)

∅2.5000

∅2.1130

∅1.6000

Figure 10-36: Worst Case – All Three Major OD of the Strings Coming Together at the SameTime

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Page 10-58 October 18, 2000

ExerciseThere are five methods for retrieving a Baker A5 Dual Packer shown (withillustrations) on the following pages. Each of the discussed methods should retrievethe packer successfully. The presented methods are not the only ones that may besuccessfully employed to fish for a Baker A5 dual packer. The presented methodsillustrate that there is more than one acceptable method for retrieving a fish.

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October 18, 2000 Page 10-59

Procedure OneRefer to Figure 10-37 when using the following procedure.

1. Pull the short string

2. Chemical cut the long string at 6128-feet

3. Rec. /w.L., spear,1.660, shear pin

4. Run a 5-3/4 overshot

5. Chemical cut 1/2 joint below the dual packer and recover the packer

6. W.P., trip saver, retrieve seals and/or burn over the lower packer

2 3/8” 4.7#CS Hyd. Tubing

11,570’

Position NippleW/1.875” I.D.

7 5/8” 29.7#Casing

11,920’

2 3/8” 4.7”.8Rd Tubing

Baker A5 Dual Packer

5,500’ of 9/16” Lineand Swab Assembly

Baker DB Packer

Figure 10-37: Baker A-5 Dual Packer Retrieval Method One

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Page 10-60 October 18, 2000

Procedure TwoRefer to Figure 10-38 when using the following procedure.

1. Pull a short string.

2. Wash the sand to the top of the lower packer using 420-ft. of 1-inch CS Hydrilwith a mule shoe.

3. Chemical cut the long string at 6128-ft.

4. Run a 5-3/4 overshot with jars etc.

5. Recover the dual and seals from the lower packer.

6. Run P.K.R. for lower packer.

6,128’

11,570’

Position NippleW / 1.875” I.D.

2 3/8” Tubing Cut AboveWireline in Long String

Baker A5 Dual Packer

Swab and 9/16” LineLeft in Tubing

Baker DB Packer

7 5/8” 29.7#Casing

11,920’

Figure 10-38: Baker A-5 Dual Packer Retrieval Method Two

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October 18, 2000 Page 10-61

Procedure ThreeRefer to Figure 10-39 when using the following procedure.

1. Pull the short string.

2. Chemical cut the long string at 6128-ft. (just above the wireline).

3. Run a 5-3/4-in. overshot and an inside-outside back off collar.

4. Make an outside back-off with a 40-ft. long shot.

5. Fish exposed wireline with a rope spear (Figure 10-41).

6. Engage the long string with the overshot and chemical cut it 15-ft. below the longstring.

7. Recover the dual packer and proceed with fishing the tubing and permanentpacker.

Work String

5,500’ of2 3/8” CS Hyd.

Tubing

420’ of1” CS Hyd. Tubing

W / Mule Shoe

6,128’

Baker A5 Dual Packer11,570’

7 5/8” 29.7#Casing

Baker DB Packer11,920’

Figure 10-39: Baker A-5 Dual Packer Retrieval Method Three

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Page 10-62 October 18, 2000

Procedure FourRefer to Figure 10-40 for the following procedure.

1. Pull the short String

2. Chemical cut the long string at 6400-ft. (just above the wireline).

3. Run a 5 3/4-in. overshot and an inside-outside backoff collar.

4. Make an outside backoff with a 40-ft. long shot.

5. Fish the exposed wireline with a rope spear (Figure 10-41).

6. Engage the long string with an overshot and chemical cut it 15-ft. below the dualpacker.

7. Recover the dual packer and the fish for the tubing and permanent packer.

Procedure FiveRefer to Figure 10-40 for the following procedure

1. Pull the short string.

2. Chemical cut the long string at 6128-ft. (just above the wireline).

3. Run in the 5-9/16-in. H.E. wash down cutter and cut 300-feet below top ofwireline

4. Fish the exposed wireline with a rope spear (Figure 10-41).

5. Engage the long string with an overshot and chemical cut it 15-ft. below the longstring.

6. Recover the dual packer and proceed fishing for the tubing and permanentpacker.

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October 18, 2000 Page 10-63

Drain Hole

4.12

5”

5.75

0”

2 7/8” IF Pin Defection Window 2” I.D. 2 7/8” IF Box

Wireline Crossed Over From Work String to Casing

Fish4 9/16” O.D.Overshot

7 5/8”Casing

Inside-OutsideBackoff Collar Crossover

WorkString

Figure 10-40: Baker A-5 Dual Packer Retrieval Method Four and Five, Inside-Outside BackoffCollar.

Figure 10-41: Rope Spear

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Page 10-64 October 18, 2000

Notes:

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October 18, 2000 Page 11-1

Fishing Best Practices Manual

Casing Repair

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

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Page 11-2 October 18, 2000

Contents

Introduction ..................................................................................................................11-4

Casing Failure...............................................................................................................11-5

Downhole Video...........................................................................................................11-5

Casing Swage...............................................................................................................11-7

Casing Roller................................................................................................................11-8

Mills.............................................................................................................................11-9

Lace Joint ....................................................................................................................11-9

Casing Repair Tool ..................................................................................................... 11-12

Upper String Replacement........................................................................................... 11-12

Internal Cutters........................................................................................................... 11-13

Weatherford Internal Casing Patch.............................................................................. 11-15

Notes:............................................................................................................................ 11-22

List of Figures

Figure 11-1: Decision Chart ....................................................................................................11-4

Figure 11-2: Collapsed & Parted Casing ..................................................................................11-6

Figure 11-3: Swaging Tool......................................................................................................11-7

Figure 11-4: Casing Roller ......................................................................................................11-8

Figure 11-5: Lace Joint...........................................................................................................11-9

Figure 11-6: Casing Parted at 3,450-feet................................................................................ 11-10

Figure 11-7: Enter & Dress Parted Casing............................................................................. 11-11

Figure 11-8: Casing Repair Tool Sequence............................................................................. 11-12

Figure 11-9: Mill Types......................................................................................................... 11-15

Figure 11-10: External Casing Patch-1................................................................................... 11-17

Figure 11-11: External Casing Patch-2................................................................................... 11-18

Figure 11-12: External Casing Patch, exploded view............................................................... 11-19

Figure 11-13: External Casing Patch Grapple and Exploded View ........................................... 11-20

Figure 11-14: Casing Scraper................................................................................................ 11-21

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October 18, 2000 Page 11-3

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Page 11-4 October 18, 2000

IntroductionThe flow chart shown in Figure 11-1 gives an overview of the processes required todiagnose casing problems and possible solutions.

Determine depth and type of casing failure

Select:1. Impression Block2. RTTS Tool3. Casing Inspetion Log4. Downhole Video Camera

Casing Collapsed?

Casing Split

Select in order one through five:1. Swage and Safety Joint2. Casing Roller3. Tapered or string mill with lace joint4. Casing alignment tool5. Homco International Casing patch

To cut and pull, Select:1. Internal cutter2. Chemical cutter3. Jet cutter

Run external casing patch

Yes

No

Yes

Job complete

No

Figure 11-1: Decision Chart

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October 18, 2000 Page 11-5

Casing FailureCasing failure can be caused by erosion, corrosion, subsidence or a poor casingprogram where high pressures are encountered. The most common indication of thistype of problem is the presence of sand or shale inside the well when the tubing ispulled. Partial or complete collapse of casing causes marks on the tubing. Thesemarks ensure the exact determination of the depth of the problem. A packer,Halliburton RTTS tool, run on tubing can be used to locate a hole in the casing. If thepacker is set at intervals and pressure is applied between the tubing and casing, thepacker will cause a pressure shut off as long as it is above the hole. When the packeris set below the hole, the pressure in the annulus will bleed off.

Casing can be repaired using the following methods:

• squeeze cementing

• using a stressed-steel liner patch

• replacing the upper part of the string if the casing can be pulled with an externalcasing patch

• running a liner to cover the bad place in the casing string

• using a casing roller or swage

• millout with a string mill and run the casing alignment tool

Note: If an earth shift has occurred, thereby collapsing the casing, it’s probably notfishable because it may shift again. Consider swaging it out.

We are primarily concerned with the types of casing repair calling for replacing thedamaged casing or repairing collapsed casing. The first problem is to determine whichcourse of action to take. This can be done with a casing inspection log, an RTTS toolas previously discussed, a lead impression block, or a downhole video camera. Acasing caliper log would also be helpful.

Downhole VideoDownhole video cameras require a clear fluid such as water in the hole to workproperly. In the early days of downhole video, a rig was needed to continuously pumpclear water to keep oil off the lenses. A specialized lens surfactant was developed toovercome this problem.

Through the use of downhole video we’ve been able to determine that oil and waterquickly separate upon entering the wellbore. If a continuous phase of oil isencountered, the lens will be obscured until you come to clear water. The lenssurfactant is a milestone because a rig is not needed to continuously pump water.

Two types of downhole video systems are available from Downhole Video,International the Fiber Optic Video System and the Hawk Eye Video System.

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Page 11-6 October 18, 2000

The fiber optic system uses a fiber optic cable for live, full motion video needed forfluid entry surveys. The Hawk Eye is a highly portable video system. This system isdesigned to view mechanical problems in wells when a fiber optic system isunavailable, not economically viable to mobilize or the well is too corrosive for thefiber optic cable.

The Hawk Eye system uses the same downhole components except for the electronicchassis. The Hawk Eye system can be used with any wireline unit already onlocation. Images are displayed on a video monitor and recorded on video tape for laterreference. This system is ideal for diagnosing mechanical problems where there is asingle, still object to be observed and analyzed.

By developing a small 7/32-in. diameter fiber optic cable, DHV International providesreal time video surveys down to 14,000-ft. The light head is on the bottom of the tooland houses the video camera in a pressure vessel with a clear optic view port and a100 watt halogen lamp to illuminate the area in front of the camera. A polishedreflector and a quartz dome over the bulb serve to cast the light forward and toprotect the bulb. Above the light is a collapsible centralizer followed by the electronicchassis which carries the signal to the surface via the cable. The tool diameter is 1-1/16-in. and has a temperature limitation of 250°F.

Figure 11-2: Collapsed & Parted Casing

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Page 11-8 October 18, 2000

Casing RollerAs a second choice, run a casing roller to roll the casingout. The Bowen Casing Roller (Figure 11-4), utilizingthe eccentric cam, is very rugged yet simple in design.All moving parts are held in place on the mandrel bylarge ball bearings running in deep groves. It is used torestore collapsed casing to it’s normal internal diameter.

The roller consists of an eccentric mandrel upon whicha series of rollers and a tapered nose cone are mounted.The nose cone locks the rollers in place on the mandrel.The rollers are interchangeable.

The roller and drill string are lowered while rotating untilthe damaged area is located. Upon contact, increase therotary speed to 50 to 75 rpm’s and lower slowly withmoderate weight. A high rotary speed with too littleweight tends to wear the rollers without straighteningthe pipe. Experience is the best guide when determiningthe amount of weight and rotary speed to use. As longas steady downward progress is being made, theweight/speed ratio is producing the desired results.Circulation must be maintained during the operation.

Figure 11-4: Casing Roller

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October 18, 2000 Page 11-9

MillsIf the casing cannot be swaged or rolled out, it becomes necessary to mill through thecollapsed spot. Keep in mind that it is very easy to mill out through the side of thecasing and sidetrack the hole when the casing is completely collapsed together. Usemilling as a last choice because it will reduce the casing wall thickness and the casingstrength. If the casing is not completely collapsed, a string mill, dressed to bit size,with a stinger (lace joint) or drill collar locked securely below the mill will preventmilling out through the side of the casing.

The string mill must be run on a rigid and well stabilized string using very little weightand a fast rpm.

Lace JointIf a lace joint (Figure 11-5) is not readily available, make one by cutting off the pinend of a joint of drillpipe at an angle of 90° and weld a plate on bottom to blank off themule shoe. Then drill a 3/4-in. hole 180° from point of the mule shoe. Fluid pumpedthrough the hole forces the point of the mule shoe against the casing wall allowing youto attempt re-entry into the parted casing.

Drill

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Page 11-10 October 18, 2000

Figure 11-6: Casing Parted at 3,450-feet

After entering the casing stub, you should be able to slack the assembly off freelyuntil the string mill makes contact with the collapsed portion of pipe. Pick up a fewfeet and rotate at 100rpm. Begin opening up the casing with one to two points on themill. Again, mill with torque and not by weight. Work the string back and forth throughthe parted casing until the mill is free to move through the area without drag. Do notallow the mill to rotate too long in one place, and do not pull the lace joint above theparted casing until you are ready to pull out of the hole.

After the casing has been opened up sufficiently with the string mill, a casingalignment tool is run in the hole below a cement retainer.

The Halliburton Alignment Tool is an aluminum sleeve, much like a long boot basket,filled with cement. It is available from Pearland Manufacturing with 72 hours notice.

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October 18, 2000 Page 11-11

Workmule

shoe ofdrillpipe

with aidof pump

intocasing

Drillcollars

Drillcollar

Note: Do notpull mule shoe

joint frombelow partedcasing until

ready for trip

Stringmill

dressedto bitsize

Work mill backand forth

through partedcasing until

mill is free tomove througharea without

drag

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Page 11-12 October 18, 2000

Casing Repair ToolTrip in hole and place the casing alignment tool directly across the parted casing, withhalf the tool above and half the tool below the parted section. Set the cement retainerand pump the cement out the bottom of the repair tool and up the annulus for a 360°cement bond. After the cement has set, pick up a rock bit or cement mill on drillcollars and drill out the retainer and casing alignment tool.

Trip inthe hole

withcasingrepairtool

belowcementretaineron workstring.

Set cement retainerwith work string

after placing casingrepair tool directly

across partedcasing. Half of

repair tool shouldbe located belowthe parted casing

point and halfabove. Cement

casing in place bypumping cement

through the bottomof the cement repair

tool and back upthe annulus and outinto the parted area.

After thecementhas set

pickup arock bit on

the drillcollars

and drillout thecementretainer

andcasing

repair tool.

Figure 11-8: Casing Repair Tool Sequence

Upper String ReplacementIf the drilling or tubing string can be pulled from the well, the upper portion of thecasing may be cut and pulled provided it is not cemented. When casing is going to berepaired using the Cut and Patch method, the recommended procedure is to run aninternal mechanical cutter. Make up and trip in hole with the cutter.

1. At the desired cutting depth, anchor the cutter by slow right hand rotation andslow lowering of the string.

2. The wiper blocks will resist rotation and disengage the automatic bottom.

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October 18, 2000 Page 11-13

3. Continued lowering of the string causes the cone to move the slips and anchor thecutter in the pipe.

4. The knife block forces the knives to start the cut.

5. Cut casing by slow rotation at a low gear idle.

6. Apply just enough weight to feed the knives approximately 2,000 pounds.

7. As the knives cut into the fish, it is necessary to lower the cutter slightly tomaintain the original 2,000 lbs. Weight.1

8. When the cut is made you will probably note a decrease in torque.

9. Check the knives for signs of having made a cut.

When the cut is completed, the pipe is raised, the slips disengage, the knifes retract,and the friction assembly returns automatically to the run in position. A unique featureof the tool is the automatic nut which allows the resetting and disengaging of the toolany number of times without pulling out of the hole.

Internal CuttersBowen Collar finders are available for all sizes of Bowen internal cutters. Theyenable the operator to locate the nearest collar at the cutting depth. With thisinformation, the operator can then set the cutter above or below the located collar andthus avoid the possibility of attempting a cut within a collar.

Bowen Collar Finders assemble in the bottom of the bottom nut of the cutter. Abottom nut with a threaded plug is substituted for the standard nut. The collar locatorsare pressed out by the collar locator springs at angles that permit free lowering intothe pipe. However, when the string is elevated, the upper ends of the collar locatorswill engage in the first encountered space between two joints of pipe and thus locatethe exact position of the joint. After the joint is located, the collar finder may bereleased by exerting sufficient upward pull to break the shear pin. When the shear pinis sheared, the collar locators drop into the sleeve and are retained there.

While running in the hole, elevate the string to pull the rotary slips. The Bowen Collarfinder is equipped with a spring which will absorb over 8″ of elevation before any pullis exerted on the shear pin.

Other internal cutters are the Bowen Internal Pressure cutter or the A-1 Multi-stringpressure cutter. Both operate basically in the same manner. These cutters will bediscussed more in depth within the P and A section, but here is a brief set ofinstructions.

1 A good way to apply a given amount of weight on the knives is to run one drill collar and a bumper sub above the cutter.The free travel in the bumper sub will maintain the constant weight of the one drill collar.

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Page 11-14 October 18, 2000

1. Make up the cutter on drill collars or drillpipe. Function test the knife sweep, thenwire or tie the knives to retain them until ready.

2. Lower string to the desired cutting depth and begin rotation at approximately 30rpms.

3. Engage the pump with a by-pass line open initially. Pinch the by-pass line downuntil cutting action is indicated by torque build up. Usually, 900 P.S.I. Is adequate,however, this will vary due to depth and rig pump capability. Do not move thesting until the cut is completed.

4. Whenever the knives reach the preset diameter, the piston will separate from thevalve stem and provide increased mud flow through the tool, causing a markeddecrease in pump pressure. This is an indication that the knifes have cut the pipe.The preset knife sweep should be approximately 1/8-in. larger than pipe OD toallow for possible knife carbide wear.

5. Disengage the pump and allow pressure to equalize. Pick up on the string toretract the knives and to trip out of the hole.

6. In the event of a failed cut, always attempt the next cut at a greater depth.

The internal cutter leaves a clean top, however operators like to dress the top with adressing mill prior to running a casing patch.

After the cut portion of casing is removed, a casing patch is made up on new casingand run in the hole. As the fish depth is reached, slowly rotate and lower the patchuntil you get over the top, then slack off until you bump up on the grapple carrier. Pickup the patch to engage the grapple and set the seal. See Bowen (or manufacturer’s)instruction manual for the pick up load required to set the patch. Reduce pull load to40% of setting load and pressure the patch to Manufacturer’s recommendations.

Once the seals are set a minimum pull only is required to maintain them in the propersealing position. The tensile load required to set the slips to maintain the pipe is morethan adequate. For the packer type patch, pick up the running string and applysufficient pull to remove any slack from the string, and set the slips. No load isrequired to maintain engagement nor is any load required to maintain a seal.

The Bowen lead seal casing patch does not reduce the ID in any manner. Once thepatch is set, it becomes a permanent part of the string and is usually cemented inplace. Patches are available for standard and H2S service.

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October 18, 2000 Page 11-15

Bladed

Flat Bottom

Long Taper

String

Pilot

Figure 11-9: Mill Types

Weatherford Internal Casing PatchIf the upper portion of the casing cannot be pulled, run an internal steel liner casingpatch.

The Weatherford Internal Casing Patch is designed to permanently regain theintegrity of the wellbore by sealing many types of leaks including:

• seal perforations

• seal casing wall splits

• seal collar/thread leaks

• reinforce corrosion areas

• reinforce areas with internal wear

The method used is to place a thin walled steel liner inside the casing and across theleak to form a permanent seal. The patch arrives on location in a corrugated form, toreduce the OD and allow free passage downhole. It is normally 20-ft. long, but can bemuch longer in length. The liner is wrapped with a fiberglass cloth and is coated withan epoxy resin as it goes through the rotary table. With setting tool and patch in

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Page 11-16 October 18, 2000

position, the patch is expanded by stroking a cone and collet through same with ahydraulic cylinder assembly. Once expanded, it is permanently held in place by radialcompression with the epoxy acting as a seal.

The Weatherford Internal Casing patch is made of low-carbon 1010 annealed steeland has a temperature rating of 325° Fahrenheit. The wall thickness of the patch is0.12-in. and will reduce the drift ID by approximately 0.30-in.

First, the area to be patched must be located and identified. Then a casing scrapper isrun with a tapered mill 1/16-in. larger than drift diameter to insure passage of thepatch. A gauge run to simulate the OD and length of the patch and setting tool isrecommended in deviated holes. The well is circulated to clean the hole good prior torunning the patch.

When expanded, the steel patch forms symmetrically to the casing ID and makes theseal. Epoxy resin extrudes into leaks and cavities in the casing wall, acting as agasket and secondary sealing agent. Setting time normally requires less than 30minutes for a 20-ft. section. The epoxy resin on the patch is fully cured in 24 hours.Although no testing can be performed during that time, other well operations can becarried out while the epoxy is curing.

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October 18, 2000 Page 11-17

Figure 11-10: External Casing Patch-1

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Page 11-18 October 18, 2000

Figure 11-11: External Casing Patch-2

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October 18, 2000 Page 11-19

Figure 11-12: External Casing Patch, exploded view

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Figure 11-13: External Casing Patch Grapple and Exploded View

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October 18, 2000 Page 11-21

Figure 11-14: Casing Scraper

CAUTION: Do NOT rotate or try to mill with the scraper in the borehole.

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Page 11-22 October 18, 2000

Notes:

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Fishing Best Practices Manual

Fishing for Wireline

REV. # DATE REVISIONS PREPARED CHECKED APPROVED

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Page 12-2 October 18, 2000

Contents

Introduction ..................................................................................................................12-3

Problems and Precautions .............................................................................................12-6

Run in Procedures ........................................................................................................12-7

Proof of Overshot Engagement......................................................................................12-7

Side Door Overshot Procedures................................................................................... 12-11

Fishing for Parted Wireline .......................................................................................... 12-12

Center Prong Rope Spear........................................................................................ 12-13

Double Prong Spear ................................................................................................ 12-13

Crankshaft Spear .................................................................................................... 12-13

Notes:............................................................................................................................ 12-23

List of Figures

Figure 12-1: Wireline Open Hole .............................................................................................12-3

Figure 12-2: Wireline Cased Hole ............................................................................................12-4

Figure 12-3: Bowen Side Door Overshot ............................................................................... 12-10

Figure 12-4: Bulldog Screwgrab .......................................................................................... 12-14

Figure 12-5: Wireline Stripping Job Assembly No. 1 ............................................................... 12-16

Figure 12-6: Wireline Stripping Job Assembly No. 2 ............................................................... 12-17

Figure 12-7: Wireline Stripping Job Rope Socket .................................................................... 12-18

Figure 12-8: Wireline Stripping Job Spear Head Overshot ....................................................... 12-19

Figure 12-9: Wireline Stripping Job C-Plate and Spear Head Sub and Adapter ......................... 12-19

Figure 12-10: Wireline Stripping Job Clamp............................................................................ 12-20

Figure 12-11: Wireline Stripping Job Rope Socket Anchor....................................................... 12-20

Figure 12-12: Wireline Stripping Job Grapple Assembly .......................................................... 12-21

Figure 12-13: Wireline Stripping Job Spiral Grapple................................................................. 12-21

Figure 12-14: Wireline Stripping Job Basket Grapple ............................................................... 12-22

List of Tables

Table 12-1: Pressure Required to Rupture Disks in Pump Out Sub ...................................12-9

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October 18, 2000 Page 12-3

IntroductionThere are two flow charts included in this chapter (Figure 12-1 and Figure 12-1) toassist the decision making process.

Determine condition of

wireline

Below 3,000-feet?

Above 3,000-feet?

Source

center rope spear safety

joint bumper sub

jars drill collars

accelerator

Cut and strip

side door overshot

Stuck Parted

No

Yes

Yes

Yes

No

Figure 12-1: Wireline Open Hole

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Page 12-4 October 18, 2000

Determine condition of

wireline

Below 3,000-feet?

Above 3,000-feet?

Source

Center rope spear safety joint bumper

sub

jars drill collars

Accelerator

Cut and strip

Side door overshot

Stuck Parted

No

Yes

Yes

Yes

No

Two/Three prong safety joint bumper

subOr

Figure 12-2: Wireline Cased Hole

There are two methods used to fish stuck logging tools when the cable is not parted,the cable guide method and the side door overshot. The cable guide method is muchslower but safer, therefore it is the preferred method.

1. First, take an over pull on the cable of 1,000 pounds above the line weight andattach a T-Bar clamp to the cable.

2. Ensure that you have the correct size liners in the T-Bar clamp.

3. Tape or mark the line at the T-Bar to check for slippage, and bounce the T-Baron the rotary to test it.

4. Cut the cable with a cable cutter leaving a tail of approximately 8 feet.

5. Secure the part of the cable that is attached to the truck so that it will not run overthe crown and hurt someone.

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October 18, 2000 Page 12-5

6. Lower the block that supports the upper sheave so that the sheaves may berearranged on the derrick because the block must be used to handle the drillpipe.The lower sheave must be moved back from the rotary to be out of the way ofoperations on the rig floor.

7. After the sheaves have been rearrange properly, attach a rope socket, adapterand spear point to the well end of the cable. The slips and slip carrier must bechosen according to cable size. Use only new slips each time and use only once.

8. Attach a rope socket and rope socket overshot to the truck end of the cable, with10 feet of weight bars, a knuckle joint and a swivel joint.

9. Tighten the parts securely with a 24-inch pipe wrench.

10. Make a test pull by latching the rope socket overshot to the spear point, while theT-bar clamp is still attached to the cable, and take a 5,000 pound strain on thecable. After one minute, check for any movement by checking the tape marks. Ifall is O.K., slack off on the T-bar and disconnect the rope socket overshot.

11. Dress the Bowen 150 fishing overshot with the correct grapple to catch thefishing neck. Use a Nitraloy grapple if available. A plain grapple control issufficient since you can’t circulate through the fish.

12. Thread the restricted ID sub onto the overshot followed by a mud saver subwhich will screw onto the drillpipe. Use a doughnut shaped guide on the overshot.

13. Make all tools up by hand.

14. Thread the rope socket spear point through the overshot and replace the adapterwith the hexagon one that will not pass through the restricted sub if it is dropped.

15. Latch first stand of pipe and have the derrick man stab the wireline tools throughit.

16. Latch the rope socket overshot onto the spearpoint and take the slack out of theline.

17. Have the crew make the fishing overshot up onto the stand of drillpipe by hand.

18. Pick up on the wireline and remove the T-bar clamp.

19. Set the slips on fishing tools and tighten the connections.

20. Tighten the guide by hand with a pipe wrench and sledge hammer. We are nowready to start in the hole.

21. Have the winch operator adjust the tension to normal, plus at least 1,000 poundsof overpull and go in the hole slowly. It is important for the winch operator towatch the weight indicator in the truck for any change and to maintain 1,000pounds overpull on the line at all times.

22. When the first stand has been run in, place the C-plate in the slot between therope socket and spear point and the wench operator slacks off the cable until it issupported by the C-plate. The C-plate rests on top of the drillpipe tool joint for

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Page 12-6 October 18, 2000

which it is sized. The winch operator should put tape flags on the cable at thetruck as he will return to this exact spot for each stand of drillpipe run.

23. Release the rope socket overshot with special tongs.

24. After the driller has latched another stand of pipe, the winch operator pulls thewireline tools up for the derrick man to stab them into the drillpipe.

25. Drop the rope socket overshot down through the pipe to be attached to the spear.Careful timing of downward cable motion with pipe at rest in proper position isnecessary.

WARNING:

Keep your hands in a safe place; do not get fingers caught underthe C-plate. After the overshot is latched, the winch operatoragain picks up on the cable maintaining a 1,000 pound over pull.Make up stand number 2 and proceed in the hole at the rate oftwo minutes per stand, not counting make up time. Going in thehole slowly is the only safe way.

Urge everyone to be alert throughout this tiresome operation toprevent costly mistakes and/or a serious accident. Some of theprimary hazards are:

• The cable may be dropped

• A broken strand of wire may ball up ahead of the overshot

• Impact of tool on a bridge may cut the cable

• The cable may double back around the overshot if it is notremoved from the keyseat

Problems and Precautions• A failure of the spear head rope socket will leave a broken cable in the hole

• If the spear head with a rope socket and cable is accidentally dropped into thepipe, run the rope socket overshot down the pipe and attempt to engage the spear.It should be only a couple hundred feet below the rotary. If this fails, pull thedrillpipe until you find the cable. The hex adapter will not pass the restricted IDsub located immediately above the overshot.

• If the cable tension increases sharply, the cable may be stuck in a key seat anddoubled back outside the overshot. Picking up on the pipe should cause adecrease in tension. Increase the cable tension with the winch and the guideshould free the cable ahead of the overshot.

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October 18, 2000 Page 12-7

• When cable tension increases moderately fast, a broken strand of wire may beballing up at the overshot.

• If the tension increases gradually, (normal for a directional well), the elevation ofthe cable head spear will lower. If it lowers below the top of the pipe as youadvance into the well, a short length of sucker rod may be added between therope socket and the spear to prevent pulling too much tension on the line.

• If a bridge is encountered, it should be cleaned by circulating the mud. Circulationmay be accomplished unless the cable was cut by the initial impact.

• Ensure that at least 1,000 pounds of over pull is maintained at all times.

Run in ProceduresIf the line only has been stuck and is then freed, the winch operator will knowimmediately since he will loose the 1,000 pounds overpull on his weight indicator.

Pull the logging tool up several feet to prove that it is free.

Install the circulating sub and pump sufficiently to clean debris out of the overshot.The procedure to install the circulating sub follows.

1. With spearhead hanging on C-plate, thread circulating sub over rope socketovershot and hold it there by hand.

2. Latch the overshot into the spearhead, lift the cable and remove the C-plate.

3. Thread the circulating sub into the drillpipe.

4. Place a circulating baffle around the wireline and drop it into the circulating sub.

5. Lower the cable until the rope socket rests on top of the baffle.

6. Release the overshot.

7. Screw Kelly into circulating sub.

Proof of Overshot EngagementThe driller may reciprocate the pipe while circulating.

After the Kelly is set back, and the overshot reconnected, spool up the wireline until itis pulled into the overshot. If the cable tension decreases when picking up on thedrillpipe, you may be able to prove by equal cable and pipe motion that the tool ismoving with the overshot.

Review this procedure for proof of engagement with the customer. Pull off at theweak point only after the customer has instructed you to. Use the following procedureto part the cable at the weak point.

1. Install the cable clamp.

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Page 12-8 October 18, 2000

2. Latch the elevators around the cable under the clamp.

3. Clear the derrick floor. Allow no one near the cable.

4. Increase tension slowly by picking up on the blocks. Watch the weight indicatorand record the tension where the break occurs.

5. Cut the cables and remove the rope sockets.

6. Tie both ends of cable together in a square knot.

7. Pull up on the cable until the square knot is tight. Tape the loose ends and removethe cable clamp.

8. Spool the cable onto the truck, pulling the knot carefully over the top sheave untilthe knot is just before the measuring device.

9. Clamp off the cable.

10. Slack off the cable and remove the cable from the measuring device.

11. Remove the slack in the cable.

12. Remove the clamp.

13. Spool the knot onto the drum.

14. Clamp the cable.

15. Slack off the cable.

16. Reinstall the cable onto the measuring device.

17. Remove the slack in the cable.

18. Remove the clamp.

19. Continue spooling the cable onto the drum.

20. While cable is being removed, the driller should work the pipe.

21. Arrange for a man to catch the bridle when it arrives at the surface. Tie a 1/4-in.rope to the bridle, so that it can be pulled over the top sheave and lowered to thefloor without falling.

22. Install the Kelly and blow disk out of pump out sub

23. Pull the pipe and fish out of the hole without rotating.

24. Set the slips on the fish and secure it with a C-type safety clamp.

25. Release the overshot from the fish and turn the rest over to the logging companypersonnel.

CAUTION: Use extreme caution in all phases of wireline fishing, especially if a radioactivesource is involved, as this is a very dangerous and expensive procedure.

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October 18, 2000 Page 12-9

Table 12-1: Pressure Required to Rupture Disks in Pump Out Sub

Disk Material Burst Pressure in P.S.I.

3/8 0.010 thick bronze 3300 - 3500

7/16 2900 - 3200

½ 2700 - 2800

9/16 2400 - 2500

5/8 2100 - 2200

11/16 1900 - 2000

3/4 1600 - 1700

13/16 1500 - 1600

7/8 1300 – 1400

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Page 12-10 October 18, 2000

Figure 12-3: Bowen Side Door Overshot

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Side Door Overshot ProceduresThe Bowen Series 160 overshot is recommended for fishing in casedholeenvironments only. It is run on tubing or drillpipe. First you must secure the cable withthe T-bar cable clamp. Then hang the sheave to one side in the derrick to provideclearance for the block. Prepare the overshot to go in the hole using the followingprocedure.

1. Loosen the set screws and remove the grapple control ring.

2. Remove the grapple by rotating it clockwise.

3. Remove the side door by removing the socket head screws.

4. Connect the overshot to the tubing or drillpipe and tighten it with tongs.

5. Lay the cable through the side plate opening so it passes over the roller and downthrough the lower center part of the overshot.

6. Replace the plate and secure it with the socket head screws.

7. Select the correct size grapple and thread it around the cable.

8. Slide the grapple into the lower end of overshot and rotate it counterclockwiseinto the threads of the body.

9. Replace the control ring and tighten the set screws holding it.

The basket grapple has an enlarged slot which allows it to be threaded around thecable. The grapple control is held in place by set screws.

Use the following procedure to run the side door overshot tool.

1. After the overshot is dressed and made up on the pipe, lock the rotary table. Thisis necessary since the cable will be resting on one side.

2. Apply normal tension on the cable and set the winch brake. A segment of theslips will have to be removed to avoid damage to the cable.

3. Go in hole slow and use caution when setting the slips so as not to pinch thecable. Do not rotate the pipe in the hole.

4. Descend slowly watching the weight indicator for any increase in tension. Pipetally will indicate when the overshot approaches the fish.

5. Flush the overshot by circulating before engaging the fish. As the overshotengages the fish , an increase in tension will be noted on the wireline unit weightindicator.

6. Pick up and watch for slack in the cable indicating the fish is in the overshot.

7. When the tool is free, pull out at the weak point and spool it on the truck.

8. Pull out of the hole with the fish.

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Page 12-12 October 18, 2000

9. Release the overshot cautiously at the surface to avoid damage to the fish. Theside door overshot is not recommended when the following conditions exist:

• When fishing for a radioactive logging tool

• In a directional well

• With a stuck line situation

• At a depth below 3,000-ft.

• With a large OD quick connect

Fishing for Parted Wireline

CAUTION: Fishing for parted wireline with a spear is a dangerous operation and should only beperformed by a fisherman experienced in this procedure. It is easy to ball up awireline so badly that it is impossible to fish, forcing the customer to junk the hole.

Most people believe that when a wireline is separated it will fall a great distance andthen ball up at the bottom of the hole. Experience proves this is not true. In a largehole, 12 1/4-in. for example, the line will fall a maximum of only about 10% of thelength of line in the well.

The wireline will not coil up until weight is applied to it. This is because the line comeson a drum and tends to remain in the shape it was on the drum. For example; if a toolbecomes stuck at 10,000-ft and the line parts at the surface, the top of the line will befound between 100 and 500-ft. The drilling mud also helps the line to stand up.

Wireline parted in the hole can be retrieved by either a center prong rope spear,double prong spear, or crank type spear. A typical bottom hole assembly used to fishfor wireline would consist of the following components:

• Rope spear

• Stop ring

• Safety joint ( optional )

• Bumper sub

• Oil jars

• Drill collars

• Accelerator jar

• Fishing string

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If you snag the wireline with a lot of it above the spear, it will begin to ball up on topof the spear as the pipe is pulled and may stick the string. It may be necessary to jarthe barbs off the spear to get loose. Then you have an almost impossible situation.Running washpipe won’t help because the wire will ball up and bridge off about onefoot inside the shoe and twist off.

Watch out for swabbing the well if you are pulling a ball of wire out. Also, a ball ofwire may be to large to enter the bottom of the casing further complicating the job.

It is important to keep track of the amount of line recovered so you can makepreparations to fish for the tool on the bottom. When the line is being recovered youshould measure the length of it and keep a tally. If the line becomes too balled up tomeasure, you can always weigh it. For example, a 5-16-in. OD line weighs 192pounds per thousand feet. A simple set of bathroom scales is all that is required toadequately measure the wireline.

Note: If a prolonged wireline fishing job is encountered, it’s a good idea to openthe blow out preventer bonnets and remove any pieces of wireline that may fall backin the hole or interfere with the proper operation of the BOPs.

Figure 12-4: Bulldog Screwgrab

The Scrugrab® fishing tool (Figure 12-4) is designed to provide an improved methodto recover wireline or cable from a wellbore. The corkscrew-like design offers thefollowing advantages over the conventional two or three-prong grabs:

• The tool is designed to screw into the mesh of wireline in the hole rather than tospud on it.

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October 18, 2000 Page 12-15

• The corkscrew action tends to loosen the wireline rather than pack it down into acompacted ball ("bird’s nest") that will probably require a washover or a millingjob.

• The tool provides the torque strength to screw into the mesh of line and the tensilestrength to part the line once it is engaged.

Figures 12-5 through 12-14 are examples of the equipment used in a wireline strippingjob.

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Page 12-16 October 18, 2000

Figure 12-5: Wireline Stripping Job Assembly No. 1

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October 18, 2000 Page 12-17

Legend

A

B

C

D

E

F

Cable hanger

Spear head rope socket

Rope socket

Sinker bar

Spear head overshot

C plate

Figure 12-6: Wireline Stripping Job Assembly No. 2

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Page 12-18 October 18, 2000

Figure 12-7: Wireline Stripping Job Rope Socket

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October 18, 2000 Page 12-19

Figure 12-8: Wireline Stripping Job Spear Head Overshot

Figure 12-9: Wireline Stripping Job C-Plate and Spear Head Sub and Adapter

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Page 12-20 October 18, 2000

Figure 12-10: Wireline Stripping Job Clamp

Figure 12-11: Wireline Stripping Job Rope Socket Anchor

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October 18, 2000 Page 12-21

Figure 12-12: Wireline Stripping Job Grapple Assembly

Figure 12-13: Wireline Stripping Job Spiral Grapple

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Page 12-22 October 18, 2000

Figure 12-14: Wireline Stripping Job Basket Grapple

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October 18, 2000 Page 12-23

Notes:

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February 28, 2001 Page 13-1

Fishing Best Practices Manual

Reversing Tool

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Application

• The tool consist of a planetary gearing and anchoring system.

• As the upper section is turned to the right, the lower section turns to the left.

• Right hand rotation opens the toggle wings which have carbide points inserted.

• Carbide points set against the casing, thereby anchoring the tool.

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H.E. Reversing Tool

• Maximum torque ratio transmitted from above to below the tool is 1 to 1.7 ft/lbs.

• All connections below the tool must be left handed.

• A left hand work string is used if the fish is below the casing.

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Reverse Tool B.H.A.

• Attachment tool

• O.S.,spear,pin tap,box or taper tap

• Left hand safety joint

• Left hand bumper sub

• Left hand drill pipe

• Reversing tool

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8-7-2000

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H.E. Reversing ToolFishing String

H.E. Reversing ToolLeft hand Safety JointLeft hand OvershotLeft hand Bumper JarLeft hand work stringif 1quired

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Rig Requirements

Rig minimum requirements are:

• A good weight indicator

• A pump able to maintain 500 psi

• Insure that draw-works and rotary capabilities are sufficient.

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Attachment Tool

• It is recommended to engage the fish externally if practical. In some cases theO.D. of the fish will be too large for external engagement.

• In that case, a left hand pin tap should beused to engage the fish especially if a tooljoint box is looking up.

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B.H.A. Make-Up

• A left hand bumper sub is attached to the reversing tool

• A left hand safety joint is made up to the bumper sub

• The fishing tool is made up to the safety joint

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Locking Ball

• The locking ball must be of the proper guage size and pass through all connection.

• Jars and drill collars above the reversing tool are not necessary.

• Tighten string adequately to prevent down hole make up.

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Check List

• Rotate top section to insure toggle wings will open

• Rotate to left to close wings

• Insure carbide points are all the same height

• Lock rotary so tool will not turn and open prematurely

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Operating Procedures

• T.I.H. to desired depth and check weight up and down.

• Apply 2 points weight on the pin tap.

• Turn rotary to right counting the rounds and watching for torque build up.

• With tubing, many rounds may be needed before a back-off is achieved.

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Operating Procedures

• The left hand bumper sub allows for tap make up without pulling against the carbide points.

• Watch the weight indicator. If you are gaining weight due to tubing make up, slack off on the string.

• When a connection breaks, the

rotary will spin rapidly.

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Operation Procedures

• After back-off, rotate string 3 or 4 rounds to the left to close wings.

• To lock tool so entire string turns to right, drop ball and maintain 500 P.S.I.

• While pumping rotate to left a few rounds, then still pumping, the entire string may be rotated to the right.

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All Turns to Right

• The tool may then be torqued up to theright to break the left hand safety jointor release the left hand overshot as required.

• The left hand bumper sub will help to

release the attachment tool.

• Do not rotate while pulling out of hole

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Tool Capacity

• Do not exceed the maximum capacity forthe tool size.

• No.8 tool = 22,000 Ft./Lbs.

• Zero tension

• 22,000 x 1.78 = 39,160 Ft./ Lbs.

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AH and AJ Model Reversing Tool — General Specifications

(Metric) Table 4

Tool Model *AJ AJ AH AJ AH AJ AH AJ

Nominal Tool Size O.D. No.3 No.4 No.6 No.8

Actual Tool O.D. 3-3/4" 4-1/16" 5-13/16" 7-3/4"

Actual Tool I.D. 5/8" 1" 1-1/8" 1-1/8" 1-1/8"

Maximum Yeild Tensile Strenght 90,000 150,000 200,000 400,000

Input 4,000 ft/lbs. 10,000 ft/lbs. 14,000 ft/lbs. 22,000 ft/lbs.

Ratio 1-1.78

Maximum Yeild TorqueLoad – See Torque vs.Rounds/Thousands for

Various Pipe SizesOutput 7,120 ft/lbs. 17,800 ft/lbs. 24,920 ft/lbs. 39,160 ft/lbs.

Maximum Pump Pressure-Internal 5,000 psi 5,000 5,000 5,000

Minimum Pump Pressure-Internal 200 psi 150 psi 150 psi 150 psi

Minimum Pump PressureTo Lock Tool In Hole

600 psi 500 psi 500 psi 500 psi

Hole size For Top &Bottom Circulation Plugs

1/4" 3/8" 1/2" 5/8"

Drop Ball O.D. *9/16" NA 1-1/16" NA 1-3/16" NA 1-3/16" NA

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8-7-2000

Tool Capacity

• A back-off is not guaranteed.

• Frequently make up torque of tool joints is beyond the capacity of the tool.

• In all cases, a safe working capacity of the tool must not be exceeded or the gear teeth will be destroyed.

Page 349: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Recovery Rate

• Unless a string shot is used, there is no

way to determine how much fish will

be backed off.

• Generally, the fish will back off at or

near the neutral weight point

• However, holding more tension lessons

the torque ratio being transmitted

Page 350: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Torque Ratio

• The torque ration decreases in

proportion to the amount of tension

pulled on the tool.

• The greater the tension, the less

the ratio.

• With 20,000 lbs. Of tension, the

ratio is reduced to one to one.

Page 351: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

AH and AJ Model Reversing ToolInput to Output Torque Capacity Ratio

At Various Tension Loads and Static Load Capacity

(metric) Table 5* Torque Multiplication Ratio With Tension At:

NominalTool Size O.D.

Mechanical RatioO lbs (N)Tension

5,000 ft/lbs. 10,000 ft/lbs. 20,000 ft/lbs.** Input Torque Static Tensile Load

Capacity(90% Yield)

No. 3 1-1.78 1-1.60 1-1.40 1-1 4,000 ft/lbs. 90,000 ft/lbs.

No. 4 1-1.78 1-1.60 1-1.40 1-1 10,000 ft/lbs 150,000 ft/lbs.

No. 6 1-1.78 1-1.60 1-1.40 1-1 14,000 ft/lbs. 200,000 ft/lbs.No. 6 1-1.78 1-1.60 1-1.40 1-11 4 , 0 0 0 f t / l b s .

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8-7-2000

Page 353: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Torque Ratio

• This is still a good ratio, because the reason for running the tool was that sufficient torque could not be transmitted to where it was needed by anyother method.

• Provided the fish I.D. is clear, a string shot can be run with sufficient torque fora back-off.

Page 354: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

How Much Tension?

• A good rule of thumb as to how much tension to pull is:

• If the fish is wireline accessible, take a free point using stretch, and set the weight accordingly for the length of pipe that is free.

• If the fish is not wireline accessible, take a 20,000 pound over pull and torque up to the maximum capacity of the tool. Continue to trywith lesser over pull until a back off is achieved.

Page 355: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Check Torque Ratio

• Another way to check the maximum capacity of the tool is to count the rounds for the work string being used.

• The chart indicates that for new 4-1/2″″ grade E x 16.60# drill pipe, the tool is atmaximum capacity with 2-1/4 rounds per/1,000′′.

Page 356: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Page 357: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

H.E. Left Hand O.S.

• The H.E. left hand overshot was designed as a left hand high torque overshot to use below the H.E. reversing tool.

• The overshot consists of a top sub, body, cut lip guide, and one set of slips.

• Spring holds the slips down in catch position.

Page 358: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Tensile & Torsional

• The torsional strength at minimum yield

for a 5-3/4″″ H.E. left hand overshot is 55,000 ft./lbs.

• The tensile strength at minimum yield forthe same overshot is only 107,000.

• This overshot was clearly designed for torsional strength.

Page 359: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Slips are Locked In

• The lugs located between each slip segment hold the slips in the body while providing a lock during high torque loads.

• The gripping teeth on the slip segmentsare designed for high torque loads.

Page 360: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Engagement

• Make sure the overshot is in the catch position before attaching to the string.

• Lower the overshot over the fish and take a slight strain on the string.

• Excessive strain is not necessary to make the slip bite.

Page 361: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

To Release Overshot

• Apply slight down weight on

the fish.

• Rotate 1/4 round to the right

and pick up.

• The tool may be ordered

with right or left hand

release.

Page 362: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Page 363: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

2001 Weatherford. All Rights Reserved

February 28, 2001 Page 14-1

Fishing Best Practices Manual

Trip Saver Bushing

Page 364: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Page 365: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Weatherford Trip Saver Bushing

• Used to fish screened liners where one trip isneeded due to fast back fill of sand.

• The trip saver bushing is the ideal tool forthis application

• Simple tool: mandrel, J body, special I.D.pup Jt. & seal rings

Page 366: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

• Trip saver replaces top bushing

• An overshot, spear or tap is attached to themandrel inside the washpipe

• Special slick OD drill collars are used for slacking off through the seals

• Seal rings pack off around drill collars

• Seals are the same inner seal from Bowen’s type R mill control packer

Trip Saver Bushing

Page 367: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

• To seal properly, place the lip of the seal in the opposite direction of the fluid flow

• To release from the trip saver bushing, setslight weight on shoe, turn string 1/4 roundto the left and slack off

• To engage again, simply pick up

Releasing From The Bushing

Page 368: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Trip Saver Bushing

Mandrel

J-Body

Special ID Pup Joint

Seals

Page 369: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

J-B

ody

Special ID Pup JointSpecial ID Pup Joint

Special ID Pup Joint

J - body

Seal rings

Mandrel

Assembly

Page 370: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Washover Assembly

Page 371: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

One Trip Gravel Pack Recovery

Safety Joint Half Tattle-Tale Screen Gravel Pack Screen Bridge Plug

Trip #1 - Washover gravel pack assembly and circulate hole clean.

Drill Collar

Trip Saver

Overshot Wash pipe Shoe

Page 372: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

One Trip Gravel Recovery

After hole has been circulated clean, release overshot and lower toengage fish.

Pickup fish with overshot and re-engage the trip saver. Trip out ofthe hole with the wash over assembly and fish.

Page 373: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Versatile Tool

• Can do the job of three trips in one when milling over a permanent packer.

• With a little innovation, you can recover a free fish that is difficult to engage.

• To align a small milling string to mill out a restriction.

Page 374: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Trip Saver Solution to Fishing Problem

Unable to pull stingerfrom permanent packer.

Cut tubing above stuckpoint with chemicalcutter.

Trip in hole with wash pipe and trip saver.

Page 375: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Trip Saver Solution to Fishing Problem

Wash sand from around tubing down to packer.

FIRST TRIP SAVED - Release overshot and engage the fish, attemptto pull free from packer

SECOND TRIP SAVED - If unable to pull free, release overshot andre-jay trip saver; wash over packer.

THIRD TRIP SAVED - Release overshot and re-engage fish. Pulltubing, seals and packer body (hopefully) from well.

Page 376: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Trip In The Hole To The Top Of The Packer

Washover Packer Until Free

Release from Trip Saver Bushing and Spear I.D. ofPacker for Removal from Well

Wash over & recover packer

Drill Collar Trip-Saver Assembly

Spear Stop Sub Spear Wash pipe Extension

Shoe

Page 377: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Recovery Option for Fish that is Free butDifficult to Engage

Work over fish with shoe and wash pipe; circulate hole clean.

TripSaver

TaperTap

One Joint of Washpipe

Shoe

Release tap and lower in wash pipe until fish is engaged. Tap into fish andmake up as tight as possible. Usually the top of the fish is in such bad

shape that you will tap between the fish body and wash pipe wall. Trip outof the hole with fishing string and fish.

Page 378: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Special O.S. Top Sub as Guide

Engage fish with special overshot guide assembly utilizing the trip saver.

Release from “J” in trip saver and lower milling assembly into tubing; mill out restriction.

After restriction and tubing circulated clean, pull wash string and trip saver mandrel back up and re-engage tripsaver. Release over shot and trip out of the hole. Fish can now be engaged with a full open fishing string sothat the tubing below the dual packer can be cut with a wire line cutter.

Cement bailer stuck in long string side of dual packer while attempting a thru-tubing plug back. Bailer wasstuck while tripping in hole and is located across mandrel of dual packer. Attempts to fish from tubingresulted in the top of the bailer being pulled off leaving 1-3/4” O.D. bailer tube full of cement left in hole;approximately 12’ long.

Page 379: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Special Top Sub for Overshot

Page 380: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Parted Casing

Page 381: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

Trip Saver BushingsBuilt to Date

2 3/8” EUE 8RD Pin DownX 2 3/8” WFJ Box Up

2 3/8” API Reg. Pin DownX 2 3/8” PAC Box Up

2 3/8” API Reg. Pin DownX 2 3/8” PAC Box Up

2 3/8” API Reg. Pin DownX 2 3/8” API Reg. Box Up

2 7/8” IF Pin DownX 2 7/8” IF Box Up

3 3/4” O.D.

4” O.D.

4 3/8” O.D.

4 1/2” O.D.

5 1/2” O.D.

3 3/4” WP Hyd.

4” WP Hyd.

4 3/8” WP Hyd.

4 1/2” WP Hyd.

5 1/2” WP Hyd.

2 1/2” O.D.

2 7/8” O.D.

2 7/8” O.D.

3 1/8” O.D.

4 1/8” O.D.

Size Wash pipeConnection

MandrelConnections

DrillCollar O.D.

Page 382: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

8-7-2000

Page 383: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

2001 Weatherford. All Rights Reserved

February 28, 2001 Page 15-1

Fishing Best Practices Manual

Multi-String Cutting

Page 384: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-21

Multi-String CuttingWhen you complete this section, you will be able to:

• gather all information and equipment to perform a cutting operation

• select the proper cutter and knives

• determine the desired sweep and set the indicator accordingly

• cut single or multiple strings

• cut from land, jack-up or floating rigs

Page 385: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-3

Early Abandonment Procedures• Most wells were onshore ; abandonment

was simple.

• A large hole was dug around the cellar.

• A welder cut off the casing with a torch, removing the well head.

• The hole was plugged w/cement at surface.

• A plate was welded on top of the casing stub.

Page 386: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-4

Early Use of Cutters

• To seal off migrating gas with casings not cemented, simple mechanical cutters were used.

• The cutter body’s were just slightlyless than the I.D. of the casing to becut.

• The knifes would cut only one size.

Page 387: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-5

First Cutter Knifes

• Old knifes were made of hardened,heat treated alloy steel.

• Cutting time would take many hours.

• Took several trips to change knifes.

• A lot of guess work was involved.

• No way to know when cut made.

Page 388: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-6

Birth of the Offshore Industry

• Modern cutting operations began when theindustry moved offshore [1940s].

• Government entities began to mandate P.&A. procedures.

• It’s illegal to leave a casing stub above theseabed and cement plug requirements became more stringent.

• More efficient cutting methods were needed.

Page 389: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-7

Multi-String Cutter History

• Multi-string cutters were developed in theearly 1960’s by A-1 Bit & Tool Co.

• First was a 3 blade cutter

• Driven by fluid pressing a piston down against the heel of the knives

• With rotation, the knifes cut the pipe

Page 390: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-8

Cutting Technology• Cutting technology has continued to

evolve

• Today's cutters can cut and retrieve multiple strings in one trip

• An indicator assembly was developed toproduce a pressure drop at the surfacewhen the knives extend fully or to thedesired sweep

• The operator has a positive way to knowwhen the pipe is cut

Page 391: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-9

Other Improvements

• Cutter body was beefed up with larger size shafts & connections.

• A self stabilizing four blade cutter was developed to cut more efficiently

• Rugged knifes were dressed with crushed tungsten carbide in a nickel silver matrix.

• Knifes dressed with carbide inserts improved cutting performance.

Page 392: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-10

P. & A. Information1) Casing weight, Grade, I.D. and drift diameter

2) No. and sizes of casing to be cut

3) Cement in annulus at cutting depth?

4) Any special devices such as casing patches?

5) Water depths ( RKB, WH, Sea Bed )

6) Type of Well Head;Type thread on housing I.D.

7) Internal profile for S.C.O.R. tool/Pioneer STR spear

8) Outside profile of 18-3/4” housing ( For Most Tool )?

Page 393: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-11

Equipment Requirements

• Cutting package = two 8-1/4″″ & two 12″″ cutters w/spare parts.

• Knifes to cut any size, single or multiple with either cutter.

• Spears, stabilizers, x- over subs.

• Handling tools.

Page 394: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-12

Equipment Requirements

If working on a floater you will need additionally:

• bumper sub

• marine swivel

• spacer subs

Page 395: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-13

Surface EquipmentThe rig is responsible for providing:

• water or mud [preferably seawater]

• a means of pumping the fluid at a rate of up to 1,000 psi

• a way to rotate at 60-100 rpm

• a means of handling the work string/casing

Page 396: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-14

Selection the Proper CutterChoose the largest size cutter that will enter the casing to be cut.

This size OD cutter… is capable of cutting this size

casing…

3 5/8" 4 ½" through 7"

4 ¼" some 5" casing through 8 5/8"

5 ½" 7" through 13 3/8"

8 ¼" 9 5/8" through 36"

9 ½" 10 ¾" through 42"

12" l 13 3/8" through 42" (for multi-string)

l 48" through 96" (for singlestring)

Page 397: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-15

Selection the Proper Knives• The knives must sweep in excess of the

casing OD to cut thoroughly.

• If you do not want to cut outer layers of casing, set the indicator assembly accordingly.

• If cutting multi-strings, remember the casing is probably eccentrically aligned.

• Use the chart in the appendix to determinethe size knives that you need.

Page 398: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-16

Cutter Models #23 and #24

• The #23 tool is a three blade cutter, the #24 tool is a four blade cutter

• The newly manufactured blades for the tools are interchangeable, the old blades are not

• We now manufacture only the new blades

• Look in the appendix to determine which newblades replace the old part numbers

Page 399: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-17

Determining the Sweep

• Blade sweep is determined by size and number of strings to be cut

• If you wish to cut the 9-5/8″″ but do not want to cut the next outer string [13-3/8″″],set the sweep at 10″″

• Blades reach their desired sweep when theyare at an angle of 45-55° from vertical

• The best practice is not to set the angle at more than 60°

Page 400: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page15-18

Maximum Sweep• Maximum sweep is the maximum diameter that

the blades will extend

• You need to know the maximum sweep in orderto determine if a particular knife length willcut an eccentric string

• To determine the maximum sweep, add the ODof the cutter body to two times the distancefrom the cutter body to the end of the blades

Page 401: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-19

Determining the Desired Sweep

• Use the formulas on the following pages to determine the sweep necessary to cut two,three or four strings of casing

• The casings are assumed to be at maximumeccentric position

• The cutter body is assumed to be centralizedin the ID of the inner string

Page 402: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-20

Determining the Sweep Necessary to Cut Two Strings at Maximum Eccentric Position:Step Explanation Example

1 Subtract the inner string coupling ODfrom the outer string ID.

outer string ID

- inner string coupling OD

Measurement 1

In this example, you have 7" casinginside 9 5/8" casing.

The 7" casing has a 6.184 ID and a7.656 coupling OD.

The 9 5/8" has an 8.681 ID and a10.625 coupling OD.

8.681

- 7.656

1.025 Measurement 1

2 Add Measurement 1 to outer stringcoupling OD.

Measurement 1

+ outer string coupling OD

Measurement 2

1.025

+ 10.625

11.650 Measurement 2

3 Add 3 inches (for knife wear effects) toMeasurement 2. This gives you the desiredsweep.

Measurement 2

+ 3 inches

Desired sweep

11.650

+ 3.000

14.650

The desired sweep is 14.65.

Page 403: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-21

Determining the Sweep Necessary to Cut Three Strings at Maximum Eccentric Position:Step Explanation Example

In this example, you have 9 5/8" casing, inside13 3/8", inside 20".

Casing String Measurements

inner l 8.535 ID

l 10.625couplingOD

middle l 12.159 ID

l 14.375couplingOD

outer l 18.75 ID

l 21.00couplingOD

1 Subtract inner string coupling OD from middlestring ID.

middle string ID

- inner string coupling OD

Measurement 1

12.159

- 10.625

1.534 Measurement 1

2 Subtract middle string coupling OD from outerstring ID.

outer string ID

- middle string coupling OD

Measurement 2

18.75

- 14.375

4.375 Measurement 2

Page 404: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-22

Step Explanation Example

3 Add Measurement 1 to Measurement 2.

Measurement 1

+ Measurement 2

Measurement 3

1.534

+ 4.375

5.909 Measurement 3

4 Add Measurement 3 to outer string coupling OD.

Measurement 3

+ outer string coupling OD

Measurement 4

5.909

+ 21.000

26.909 Measurement 4

5 Add 3 inches (for knife wear effects) toMeasurement 4.

Measurement 4

+ 3 inches

Desired sweep

26.909

+ 3.000

29.909 Desired sweep

Determining the Sweep Necessary to Cut Three Strings at Maximum Eccentric Position:

Page 405: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-23

Determining the Sweep Necessary to Cut Four Strings at Maximum Eccentric Position:Step Explanation Example

In this example, you have 9 5/8" casing,inside 13 3/8", inside 20", inside 30".

Casing String Measurements

inner l 8.535 ID

l 10.625couplingOD

second l 12.415 ID

l 14.375couplingOD

third l 18.75 ID

l 21.00couplingOD

outer l 27.00 ID

l 36.625couplingOD

1 Subtract inner string coupling OD from secondstring ID.

second string ID

- inner string coupling OD

Measurement 1

12.415

- 10.625

1.790 Measurement 1

2 Subtract second string coupling OD from thirdstring ID.

third string ID

- second string coupling OD

Measurement 2

18.750

- 14.375

4.375 Measurement 2

Page 406: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-24

3 Subtract third string coupling OD from outerstring ID.

outer string ID

- third string coupling OD

Measurement 3

27.00

- 21.00

6.00 Measurement 3

4 Add Measurements 1, 2, and 3.

Measurement 1

Measurement 2

+ Measurement 3

Measurement 4

1.790

4.375

+ 6.000

12.165 Measurement 4

5 Add Measurement 4 to outer string coupling OD.

Measurement 4

+ outer string coupling OD

Measurement 5

12.165

+ 36.625

48.790

6 Add 3 inches (for knife wear effects) toMeasurement 5.

Measurement 5

+ 3 inches

Desired sweep

48.790

+ 3.000

51.790 Desired sweep

Determining the Sweep Necessary to Cut Four Strings at Maximum Eccentric Position:

Step Explanation Example

Page 407: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-24

What the Indicator doesThe stem indicator provides a pressure drop atthe surface when the blades have extended totheir desired sweep indicating the pipe is cut.

Other signs that the pipe is cut are:

• the pipe being cut tries to rotate

• the cutter locks up

• the torque frees up

• loss of circulation

Page 408: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-26

How it Works

• Fluid is pumped through a jet in the top of the indicator, pushing the indicator down, applying force to the top of the piston.

• The piston pushes on the heel of the knives, extending them outward.

• The knives reach their desired sweep when they extend to an angle that is 45° to 55° from vertical.

Page 409: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-27

How it WorksAt this point, the indicator spring is fullycompressed, but the fluid continues to push thepiston down, separating the stem from the piston,allowing fluid to bypass the indicator stem.

This creates a pressure drop at the surface, whichsignifies that:

• the blades have reached the desired sweep

• the pipe is cut

Page 410: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-28

Stem Indicator Components

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11-3-2000 Page 15-29

How it WorksSetting the indicator to provide the pressure dropinvolves:

• calculating the distance from the cutter body to the end of the knives when they reach the desired sweep

• setting the indicator so that the lock nuts fully compress the spring when the knives have extended to the desired sweep

Page 412: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 29

Figure 2.Showing circulation through“Stem Indicator” beforereaching present cutter knife sweep setting.

Figure 3.Showing circulation through“Stem Indicator” afterreaching preset cutter knifesweep setting

Note: A dropin pump pressure is indicated at this time

Page 413: Weatherford Fishing Best Practices Training - FANARCO Fishing Best Practices Training - FANARCO

11-3-2000 Page 15-31

Step Explanation Example

1 Subtract the cutter OD from the desiredsweep.

Desired sweep

- Cutter OD

Measurement 1

In this example, you are cutting 13 3/8"casing using a cutter with a 12" OD.The desired sweep is 14 ½".

14 ½"

-12"

2 ½" Measurement 1

2 Divide Measurement 1 by 2.

Measurement 1÷÷ 2 = Measurement 2

Measurement 2 is the ideal distancebetween the cutter body and the end of theblades.

2 ½" ÷÷ 2 = 1 ¼" Measurement 2

Calculating thedistance

The table below explains how to calculate the distance between thecutter body and the end of the blades when the blades reach the desiredsweep.

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Setting theindicator

The following procedure requires two people.

Step Action

1 Set tool upright with top sub removed.

2 Use a wrench to remove the indicator assembly from thecutter.

3 Run the lock nuts to the top of the stem, loosening the spring.

4 Screw the indicator down firmly until the wheel is run all theway down to the bottom of the threads.

5 Measure from the tool joint shoulder to the top of theindicator wheel.

Record this number as Measurement 1.

6 Press down on the top of the retainer cap until the bladesextend to the previously calculated distance between thecutter body and the end of the blades when the blades reachthe desired sweep.

Hold this position through the next step.

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7 While continuing to press on the retainer cap, measure thedistance from the tool joint shoulder to the top of the retainercap. (You can release the indicator after taking thismeasurement.)

Record this number as Measurement 2.

8 Subtract Measurement 2 from Measurement 1.

Measurement 1

- Measurement 2

Measurement 3

9 Remove the indicator and adjust the lock nuts so that whenthe spring is completely compressed, the distance between thetop of the retainer cap and the indicator wheel is equal toMeasurement 3.

10 Reinstall indicator assembly, making sure that the wheel isrun all the way down.

11 Press down on the top of the retainer cap and measure thesweep to ensure that the indicator is set properly.

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To cut 7-5/8″″ OD casing wehave determined the desiredsweep to be 8″″. We will beusing a 5-1/2″″ OD cutter.

8 minus 5-1/2 equals 2-1/2.

2-1/2 divided by 2 equals1-1/4. This is the distance theend of the knives should befrom the cutter body toproduce an 8 inch sweep.

With the lock nuts at the topof the stem and the wheelscrewed all the way down,measure from the top of theTJ to the top of the wheel.

Measurement # 1

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Measurement # 2Press down on the top ofthe retainer cap until theblades extend to thepreviously calculateddistance (1-1/4″″) from thecutter body.

Measure from the top ofthe tool joint shoulder tothe top of the retainer cap.

Subtract measurement # 2from measurement # 1.

4-3/4 minus 1 equals 3-3/4.

Measurement # 3 is 3-3/4″″.

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Measurement # 3Remove the indicator andadjust the lock nuts so thatwhen the spring is fullycompressed against theindicator bushing, the distancebetween the top of the retainercap and the indicator wheel isequal to measurement # 3.

Reinstall the indicatorassembly, making sure thewheel is all the way down.

Press down on the retainer capas far as it will go, and measurefor the correct knife sweep.(1-1/4″″) from tool body.

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Function Testing the Cutter

You dress the cutter with knives and set theindicator at the shop prior to sending to the job.

At the job site,check the cutter to insure:

• it is the correct size cutter for the job

• the knives are the correct length

• the indicator is set for the desired sweep

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Consequences of not Testing

Failure to function test the cutter could result in:

• cutting a string that was not supposed to be cut

• a blowout

• damage to Weatherford’s reputation

• possible injury or death

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Step Action

1 Stand the cutter upright.

2 Remove the top sub.

3 Press down on the retainer cap until the indicator seats on thepiston and the indicator spring is collasped.

Hold this position through the next step.

4 Use a gauge ring to measure the sweep.

5 Adjust the indicator as necessary.

IF the sweep is… THEN adjust the lock nuts…

less than desired, upward.

more than desired, downward.

6 Replace the top sub.

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Positioning Blades on Land/Jack-UpsWhen cutting multiple strings, you exchangethe blades for longer ones to cut the next string

• to cut 13-3/8″″, 20″″ and 30″″ cemented strings,start with 6.75 inch blades with a 12″″ OD cutter

• cut out and mill a window in the 13-38″″, POH

• change to 22.75″″ knives which will cut the 20&30″″

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Positioning the KnivesTo prevent cutting the inner string again with the longer knives you must:

• position the cutter so the longer blades will extend through the window milled

• raise the kelly an amount equal to the difference in blade lengths

• 22.75 minus 6.75 equals 16″″. Raise the kelly16″″

• proceed to cut the 20 and 30″″

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Key to Effective Cutting/Stabilizers

Non rotating stabilizers are auxiliary pieces ofequipment used on jack-ups and floaters

The stabilizers have:

• interchangeable blades

• sizes to fit the ID of every size pipe

• rubber sleeves

• integral blades for smaller sizes

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Cutting on Floaters

• On a floater, there is a certain amount of vertical movement no matter how stationarythe vessel

• To counter this movement, the rig provides amotion compensator that absorbs the heave

• The motion compensator works in conjunctionwith a marine swivel

• Some operators also use a bumper sub abovethe marine swivel to accommodate the heave

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Landing a Marine Swivel• Stab the cutter into the well head

• Land the marine swivel on top of the well headto stabilize the position of the cutter

• Apply app. 10,000 lbs. of weight down on the swivel to prevent it from lifting off the wellhead

• The swivel has a thrust bearing for easy rotation

• Run app. 30,0000 lbs. Of D.C. weight to preventwobbling of the string if in open water

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Elevating the Cutter

• As on a jack-up, a cutter on a floating vessel is located at a fixed vertical point for the first cut and then elevated a controlled distance for each subsequent cut in order to accommodate the longer blades needed to cut the larger pipe.

• On a floater you cannot raise the kelly, yet you must elevate the cutter so the longer knives will hit the window cut by the shorter knives.

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Elevation the Cutter• Spacer subs of assorted lengths are run between the cutter and the marine swivel

• When you change the knives, you remove a sub equal to the difference in the length of the knives

• This procedure will allow the longer knives to enter the window cut by the shorter knives

• Always run the spacer subs on the first run, just in case they are needed

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Example Space Out Subs• To cut 13-3/8″″, 20″″ & 30″″

• Use 7.88″″ knife w/32 inches of subs[one 8″″, one10″″ and one 14″″] for a total of 39.88 inches

• Cut window & P.O.H.

• 2nd. Run, use 25.75″″ knife with 14″″ long sub [leave out the 8 & 10″″] for a total of 39.75″″

• Longer knives slip into window with ease.

• Maximum sweep is 53.50 inches

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Example 20 & 30″″ Cemented

• 12″″ cutter w/16.75″″ knives and 8″″ long spacersub; total of 24.75″″.

• If 2nd. run is required use 22.75″″ knives andleave out 8″″ sub.

• 22.75 is less than 24.75 therefore,

• Knives will slip into window easy.

• The following chart will guide you in the selection of spacer subs

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IF your blade lengthis…

AND your blade partnumber is…

THEN run spacer subs ofthe following lengths:

7.88" 62303-002 l one 8-inch sub

l one 10-inch sub

l one 14-inch sub

13.50" 62303-006 l two 8-inch subs

l one 10-inch sub

Selecting spacersubs

18.75" 62303-008 two 10-inch subs

22.75" 62303-009 two 8-inch subs

25.75" 62303-010 one 12-inch sub

29.00" 62303-011 one 8-inch sub

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Making the Initial Cut on Land or a Jack-Up

Step Action

1 Trip in hole and find the casing collar.

Apply just enough pressure so that the blades extend and rundown the ID of the casing. When the blades hit the casingcollar, they will stop. Slack off the pressure and run the tooljust above the collar. Do not cut in the collar.

Note: Every 500 feet (or as necessary), fill the pipe at thesurface to equalize the pressure across the hydrostatic head.This will prevent the piston rubber from turning throughitself.

2 At the cutting depth, chain the brake down.

3 Mark the kelly and the drum.

Procedure

4 Set the venier hand on the weight indicator at zero.

5 Set the torque limit switch at 6,000 ft/lbs or the amountappropriate to the work string.

6 Open the valve to check for pressure in the next annulus, ensuringthat there is no trapped gas.

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7 Engage the pump and record the psi at a given number of pump strokesas a reference.

Stop the pump.

Example: Engage the pump and record the pressure at 30 strokes perminute. Thirty strokes per minute provides 1,000 psi.

8 Rotate to 80 RPM and record the free-rotating torque.

9 While rotating, engage the pump and bring the pressure up slowly toprevent the shattering of the carbide tips on the blades.

The parameters are:l 60–100 RPMl increased torque

l 400–800 psi.10 Monitor the torque.

The torque will be erratic prior to the cut and it should smooth out as thecut is made—unless you are cutting a non-cemented string. (See thenext step.)

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11 Monitor the string weight.

Guidelines:

l As the blades extend, they lift against the casing, causing aweight increase.

l If you are cutting a non-cemented string, the cutter couldlock up. If the string is in compression, then the cut pipewill sit down on blades. If this happens, stop rotating andP.O.H.

12 Watch for the pressure drop that indicates the blades areextended to the desired sweep.

Note: At times you may also get other signs that the pipe iscut, such as:l the pipe being cut tries to rotate (if you can see the pipe)l the cutter locks upl the torque frees upl loss of circulation.

13 Stop the rotation and pick up on the cutter.

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Cutting Multiple Strings on Land or a Jack-up

Step Action

1 Once the casing has been cut, gradually mill up by applying pull onthe cutter and let the blades mill off to cut a one or two foot windowin the casing.

When the venier hand is at zero, pick up the pipe several inches andlet the blades mill off again. Repeat this several times to cut thewindow.

You can move the pipe up and down to check the size of the window.

Procedure

2 Pull out of the hole and switch the blades to the size needed to cutthrough the next string.

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Step Action

Procedure 3 Raise the kelly an amount equal to the difference between the lengthof the blades.

Example: If you exchanged 6.75" blades for 22.75" blades, thenraise the kelly 16 inches.

4 Trip in hole, finding the window with the blades.

5 Cut the remaining strings using the procedure for Making the InitialCut and this procedure.

Note: Cutting time will be 2–4 hours, depending on the eccentricityof the casing.

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Cutting on a Floating Vessel

Step Action

1 Trip in hole.

Note: Every 500 feet (or as necessary), fill the pipe at the surface toequalize the pressure across the hydrostatic head. This will prevent thepiston rubber from turning through itself.

2 Stab B. H. A. into the wellhead.

3 Land the marine swivel on the wellhead, with 10,000 lbs. down weight.

4 At the cutting depth, chain the brake down.

5 Mark the kelly.

Procedure

6 Set the torque limit switch at 6,000 ft/lbs or the amount appropriate tothe work string.

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Procedure Step Action

7 Engage the pump and record the psi at a given number of pumpstrokes as a reference.

Stop the pump.

Example: Engage the pump and record the pressure at 30 strokesper minute. Thirty strokes per minute provides 1,000 psi.

8 Rotate to 80 RPM and record the free-rotating torque.

9 While rotating, engage the pump and bring the pressure up slowlyto prevent the shattering of the carbide tips on the blades.

The parameters are:l 60–100 RPMl increased torquel 400–1,000 psi.

10 Monitor the torque.

The torque will be erratic prior to the cut and it should smooth outas the cut is made—unless you are cutting a non-cemented string.

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11 Watch for the pressure drop that indicates the blades are extendedto the desired sweep. If using a mud motor, watch for a sharpincrease in pump pressure indicating the cutter is locked up (andthe pipe is cut).

Note: At times you may also get other signs that the pipe is cut,such as:l the pipe being cut tries to rotate (if you can see the pipe)l the cutter locks upl the torque frees upl loss of circulation.

12 Stop the rotation and pick up on the cutter.

13 If you need to cut additional strings, then:

l pull out of hole

l switch blades to the size needed to cut through the next string

l remove a spacer sub equal to the distance between the lengthof the blades. For example, if you exchanged 6.75" blades for22.75" blades, then remove a 16-inch spacer sub.

• repeat this procedure, starting at Step 1.

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Step Action

1 After the casing is cut, pull the cutter out of the hole.

2 Release the hold down bolts in the wellhead.

3 Pick up spear with pack off.

4 Engage casing with a spear.

5 Circulate the annulus.

6 Recover the casing.

7 Set the cement plug.

Government bodies mandate plug and abandonment procedures.The company man will provide you with the exact procedure.

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AppendixThe appendix is organized into three main sections:

• a checklist to help gather all the informationthat you need to prepare for a cutting job

• charts to help you determine the correct bladelength for a given cutter OD and a casing size

• charts that list the new knife part numbers formodel # 23 and # 24 cutters

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Table of contents Topic See PageJob Preparation Checklist/Job Aid 31

Selecting Blades for 3 5/8” OD Cutter 32

Selecting Blades for 4 1/2” OD Cutter 33

Selecting Blades for 5 1/2” OD Cutter 34

Selecting Blades for 8 1/4” OD Cutter 36

Selecting Blades for 9 1/2” OD Cutter 37

Selecting Blades for 12” OD Model 23 Cutter 39

Selecting Blades for 12” OD Model 24 Cutter 40

Blade Part Numbers for Model 23 and 24 Cutters 41

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Job Preparation Checklist/Job Aid

Customer: Date Shipped: Lease:

Co. Man: Start Rental: Lease #:

Office #: Stop Rental: Prop. #:

Mobile #: Job Loaded By: A.F.E. #:

Fax #: Job CheckedBy:

State: County:

Trucking Out: Trucking In: D.T. #:

Directions:

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Question AnswerCasing weight?Casing grade?Casing ID?Casing drift diameter?Number and sizes of casing to be cut?Drill collar connections?Is cement in the annulus at cutting depth?Pump capacity?Any special devices such as casing patches?Depth from kelly bushing to the wellhead?Depth from kelly bushing to theseabed/mudline?Type of wellhead?Type of threads on housing ID?Internal profile for S.C.O.R. tool/PioneerSTR spear?Outside profile of 18 ¾" housing for theM.O.S.T. tool?

The recommended best practice is to have the company manfax you the following information

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Single-String

Multi-StringCemented

BladeLength

MaximumSweep

DressedBlade Part

Number

Blank BladePart Number

4.50" or5.00"

-- 3.1" 5.68" 11167 13571

7.00" 7.00" 5.6" 10.50" 11163 13574

4.50" or5.00"

-- 3.25" insert 6.00" 12930-001

7.00" -- 4.3" insert 8.00" 12930-002

Crushed Tungsten Carbide–Type Blades

Blades for 3-5/8″″ OD CutterYou choose the cutter based on the ID of your inner string [see selection theproper cutter]. Select the blade length depending on the size of thecasing/casings that you need to cut.

The blade lengths below have the ability to cut through the casing sizesreferenced, however, it may not be the best practice.

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Blades for 4-1/2″″ OD Cutter

Crushed Tungsten Carbide–Type Blades

You choose the cutter based on the ID of your inner string [see selection theproper cutter]. Select the blade length depending on the size of thecasing/casings that you need to cut.

The blade lengths below have the ability to cut through the casing sizesreferenced, however, it may not be the best practice.

Single-String

Multi-StringCemented

BladeLength

MaximumSweep

DressedBlade Part

Number

Blank BladePart Number

5.500" -- 2.81" 6.25" 10148 13575

7.000" or7.625"

-- 4.06" 8.75" 10150 13576

8.625" -- 4.81" 10.63" 10152 13577

9.625" or10.750"

5.500" in9.625"

6.94" 14.38" 10154 13578

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Inserted-Type BladesBlade Length Maximum Sweep Dressed Blade Part

NumberBlank Blade Part

Number

2.81" 6.25" 62199-001 62198-001

4.06" 8.75" 62199-002 62198-002

4.81" 10.63" 62199-003 62198-003

6.94" 14.38" 62199-004 62198-004

Blades for 4-1/2″″ OD Cutter

You choose the cutter based on the ID of your inner string [see selection theproper cutter]. Select the blade length depending on the size of thecasing/casings that you need to cut.

The blade lengths below have the ability to cut through the casing sizesreferenced, however, it may not be the best practice.

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Blades for 5-1/2″″ OD CutterYou choose the cutter based on the ID of your inner string [see selectionthe proper cutter]. Select the blade length depending on the size of thecasing/casings that you need to cut.

The blade lengths below have the ability to cut through the casing sizesreferenced, however, it may not be the best practice.

Crushed Tungsten Carbide–Type BladesSingle-String

Multi-StringCemented

BladeLength

MaximumSweep

DressedBlade Part

Number

Blank BladePart Number

7.00" -- 3.63" 7.50" 10125 13580

7.63" -- 4.44" 9.12" 10126 13581

8.63" -- 4.88" 10.00" 10128 13582

9.63" -- 5.75" 11.75" 10130 13583

10.75" 7.00" in9.63"

6.38" 13.50" 10132 13584

13.38" 7.00" in10.75"

7.75" 15.75" 10134 13585

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Inserted-Type BladesBlade Length Maximum

SweepDressed BladePart Number

Blank BladePart Number

3.63" 7.50" 61131-001 61130-001

4.44" 9.12" 61131-002 61130-002

4.88" 10.00" 61131-003 61130-003

5.75" 11.75" 61131-004 61130-004

6.63" 13.50" 63168-001 63167-001

7.75" 15.75" 63168-002 63167-002

10.38" 21.00" 63168-003 63167-003

15.25" 30.75" 63168-004 63167-004

Blades for 5-1/2″″ OD Cutter

You choose the cutter based on the ID of your inner string [see selection theproper cutter]. Select the blade length depending on the size of thecasing/casings that you need to cut.

The blade lengths below have the ability to cut through the casing sizesreferenced, however, it may not be the best practice.

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Crushed Tungsten Carbide–Type BladesSingle-String

Multi-StringCemented

BladeLength

MaximumSweep

DressedBlade Part

Number

Blank BladePart Number

9.63" or10.750"

-- 5.63" 12.00" 9866 13589

11.75" or13.38"

-- 7.38" 15.50" 9882 13591

16.00" 13.38" 9.88" 20.50" 9883 13592

20.00" 16.00" 11.63" 24.00" 9884 13595

24" or 26" -- -- 29.00" 9886 13597

30.00" 20.00" 16.13" 33.00" 9885 13598

33" or 36" 26.00" 20.13" 41.00" 9887 13599

60.00" 36.00" 32.13" 65.00" 12279 13600

48.00" 30.00" 25.63" 52.00" 61862 61863

Blades for 8-1/4″″ Cutter

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Inserted-Type BladesBlade Length Maximum Sweep Dressed Blade Part

NumberBlank Blade Part

Number

5.63" 12.00" 61133-001 61132-001

7.38" 15.50" 61133-002 61132-002

9.88" 20.50" 61133-003 61132-003

11.63" 24.00" 61133-004 61132-004

16.25" 29.00" 61133-005 61132-005

Blades for 8-1/4″″ Cutter

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Crushed Tungsten Carbide–Type BladesSingle-String

Multi-StringCemented

BladeLength

MaximumSweep

DressedBlade Part

Number

Blank BladePart Number

10.75" -- 6.00" 12.63" 9929 13601

13.38" -- 7.13" 14.88" 9931 13603

16.00" 13.38" 8.88" 18.38" 9941 13605

20.00" 16.00" 11.13" 22.38" 9939 13607

20.00" 16.00" 13.13" 26.38" 9914 13610

24" or 26" 18.00" 14.88" 30.38" 9933 13611

30.00" 20.00" 16.88" 34.38" 9937 13613

36.00" 24.00" 18.88" 38.38" 9935 13615

42.00" 26.00" 20.88" 42.38" 9927 13617

48.00" 30.00" 24.88" 50.38" 9925 13618

52.00" 33.00" 27.88" 56.38" 9923 13620

60.00" 36.00" 30.88" 62.38" 9839 13621

Blades for 9-1/2″″ OD Cutter

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Crushed Tungsten Carbide–Type BladesSingle-String

Multi-StringCemented

BladeLength

MaximumSweep

DressedBlade Part

Number

Blank BladePart Number

13.38" -- 6.75" 15.50" 9921 13623

16" and 18" 16.00" 7.88" 17.75" 9920 13625

20.00" 18.00" 10.38" 22.75" 9919 13626

20.00" 18.63" 12.25" 26.50" 9936 13627

24" and 26" 20.00" 13.50" 29.00" 9894 13629

30" and 33" 24.00" 16.75" 35.50" 9895 13632

36.00" 26.00" 18.75" 39.50" 9896 13634

42.00" 30.00" 22.75" 47.50" 9897 13636

48.00" 33.00" 25.75" 53.50" 9899 13638

52.00" 36.00" 29.00" 60.00" 9832 13639

60.00" -- 31.50" 65.00" 9731 13640

72.00" -- 37.50" 77.00" 9730 13641

Blades for 12″″ OD Model 23 Cutter

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Crushed Tungsten Carbide–Type BladesSingle-String

Multi-StringCemented

BladeLength

MaximumSweep

DressedBlade Part

Number

Blank BladePart Number

13-3/8"-18" 16" 8.88" 19.36" 2413 13642

20"-26" 20" 14.13" 29.86" 2420 13643

30"-33" 24" 17.13" 35.86" 2430 13644

36"-42" 30" 23.13" 47.86" 2436 13645

52" 36" 29.38" 60.36" *2452 *13646

*Special body required

Blades for 12″″ OD Model 24 Cutter

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Old Part Number New Part Number

9921 62303-001

9920 62303-002

Model 23 blades

9919 62303-004

9936 62303-005

9894 62303-006

9895 62303-007

9896 62303-008

9897 62303-009

9899 62303-010

9832 62303-011

9731 62303-012

9730 62303-013

Blade Part Numbers for Model 23 Cutters

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Old Part Number New Part Number

2413 62303-003

2420 62303-006

Model 24 blades

2430 62303-007

2436 62303-009

2452 62303-011

Blade Part Numbers for Model 24 Cutters

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2001 Weatherford. All Rights Reserved

February 28, 2001 Page 16-1

Fishing Best Practices Manual

M.O.S.T. Tool

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Deepwater

M.O.S.T.™

Tool

Subsea

Wellhead

Retrieval

System

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n Designed for water depths in excess of 4,500’

n Cut and retrieve in a single trip

n Able to cut in tension or compression

n Eliminates most lateral whip

n Prevents well head from turning or listing

n Utilizes Weatherford mud motor

Features and Advantages

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n Visual latch and unlatch confirmation

n Confirms cut without tripping

n Minimal internal well head damage

n Easy knife removal from completed cut

n 600,000 pull capacity

n Grapples available to retrieve 18 ¾” Vetco,

Cameron, National, and Drilquip wellheads

Features and Advantages

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Rotary or top drive for:

n Shallow water or low water current

Mud Motor for:

n More efficient operations

n Less rig time to cut

n Moderate or deep water

n Areas with high water current

n Any combination of the above

Cutting Options

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Compression Cut Version

The mud motor[compression cut] version of theMOST tool is typically used with a split 9.5″″ ODDrilex mud motor.

The drive section is run above the MOST tooland the bearing package is run below it.

The two sections are connected by a drive shaftrunning through the MOST tool mandrel.

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Tension Cut Version

The tension cut version is designed to be usedwith a 9.5″″ OD modified Dailey mud motor.

The motor is not split and is connected directlyabove the MOST tool.

A bumper sub is required between the cutterand the MOST tool so the grapple can bereleased should the cutter become stuck.

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