The document discusses various causes and prevention methods for different types of stuck pipe situations, including solids induced pack-off, differential sticking, mechanical/wellbore geometry issues, and reactive formations. It then outlines recommended first and secondary procedures for addressing different sticking scenarios, such as jarring, spotting fluids, reducing mud weight, milling, fishing tools, and washover operations.

1. Stuck Pipe Prevention Prentice & Hill, LLC Second Day

2. Differential Sticking Causes High Differential Pressures Excessive Mud Weight Drawn Down Formations Poor Well Planning Well Bore Contact Poor Filter Cake Little or No Pipe Motion

3. Solids Induced Pack-off Formation Loose w/ Little or No Bonding Insufficient Hydrostatic to Hold Back Formation UNCONSOLIDATED FORMATIONS Causes

4. Pack-off Due to Unconsolidated Formations Prevention Gel up Mud / Run Hi Vis Sweeps Control Drill Spot Gel Pill Prior to TOH Plan / Anticipate:

5. Solids Induced Pack-off Increase Mud Weight, if possible Use Under-saturated Water Base Mud Pump Fresh Water Sweeps Design Casing to Handle Collapse Loads Causes MOBILE / PLASTIC FORMATIONS Formation Extrudes Into Well Bore Due to Overburden Forces. Prevention Proper Well Planning:

6. Solids Induced Pack-off Causes Control Drill & Ream Connections Anticipate Reaming on Trips FRACTURED / FAULTED FORMATIONS Prevention Loose Chunks of Rock Fall into Well Bore Plan / Anticipate

7. Solids Induced Pack-off Causes Raise Mud Weight, if possible Set Casing Appropriately OVER-PRESSURED SHALE COLLAPSE Prevention Shale “Pops” Off Wall Due to Pressure Plan / Anticipate

8. Solids Induced Pack-off Causes Use Inhibited Mud System Minimize Exposure Time Be Prepared for “Gumbo Attack” REACTIVE FORMATIONS Prevention Mud Filtrate Reacts Chemically with Formation Plan / Anticipate

9. Solids Induced Pack-off Causes Increase Annular Velocities Better Mud Properties Subject of another section POOR HOLE CLEANING Prevention Not Removing Cuttings From Well Bore

10. Mechanical / Wellbore Geometry Sticking Causes KEYSEATING Minimize Dog Leg Severity Case Off Curves Soon After Building Use Keyseat Wiper Make Frequent Wiper Trips Back Ream Out of Hole Abrupt Change in Well Bore Path (Dog Leg) Long Hole Section Below Dog Leg Prevention

11. Mechanical / Wellbore Geometry Sticking Causes UNDERGAUGE HOLE Always Gauge Bit & Stabilizers IN and OUT Run Gauge Protected Bits & Stabilizers Ream Suspected Undergauge Sections Undergauge Bit and/or Stabilizers Coring (Core heads slightly U.G.) Prevention

12. Mechanical / Wellbore Geometry Sticking Causes LEDGES & DOGLEGS Run Packed Hole Assemblies Ream on Trips Through Problem Zones Limber BHAs Hard - Soft Interbedded Formation Prevention

13. Mechanical / Wellbore Geometry Sticking Causes SHOE JOINT BACKS OFF Do Not Overdisplace Cement Thread Lock Bottom 3 Joints of Casing Drill Out Carefully Prevention

14. Mechanical / Wellbore Geometry Sticking Causes JUNK Good Housekeeping on Rig Floor Keep Hole Covered Inspect Equipment Frequently Prevention Something Manmade is Loose in the Hole

15. Mechanical / Wellbore Geometry Sticking Causes CEMENT BLOCKS Set All Casing As Close To TD As Possible Ream Casing Shoe & Open Hole Plugs Before Drilling Ahead Hard Cement Falls In From Casing Shoe or From Open Hole Cement Plug Prevention

16. Mechanical / Wellbore Geometry Sticking Causes GREEN CEMENT Wash Down Carefully to “Top of Cement” Pre-Treat Mud Before Drilling Green Cement Prevention Run BHA Into Un-set Cement

17. Mechanical / Wellbore Geometry Sticking Causes LINER & SQUEEZE CEMENTING Hazards in Liner Cementing Too Much Excess Overdisplacement Squeeze Cementing Hold Pressure on Back Side, If Possible Use Cement Retainers DO NOT Cement Up a Squeeze Packer (RTTS) Cementing Yourself in the Hole

18. Trend Analysis Plot Property -vs- Depth or Time and Analyze Drag on each Connection Torque -vs- Depth PWD -vs- Time Soap Box

19. Pressure While Drilling

20. Pressure While Drilling

21. Pressure While Drilling

22. Drag on Trip

23. Recovery Our Best Preventive Efforts Have FAILED WE’RE STUCK !! What Do We Do Now?

24. Identifying the Problem: “Why are we stuck?” Stuck Pipe Handbook Flowcharts

25. Problem Diagnosis Computer Intelligent System on Network at Cambridge Facility Charts in Front of Sedco Forex Handbook

26. Solving the Problem: “What do we do now?” First Actions

27. Solids Induced Stuck Pipe Stop pumps & bleed pressure to 500 psi Hold pressure & cycle drill string up to MUT with no up/down movement Try pumping if pressure bleeds off Begin working pipe up/down - max 50K overpull Formation Movement / Poor Hole Cleaning First Actions

28. Solids Induced Stuck Pipe Do not commence jarring Increase standpipe pressure to 1500 psi Work pipe Commence secondary procedures Continued First Actions

29. Differential Sticking Circulate at maximum allowable rate Set compression w/ 50% MUT Pull tension w/ 50% MUT Secondary Procedures Overbalanced, Filter Cake, Contact Area First Actions

30. Mechanical Sticking Maintain circulation Jar in opposite direction of last movement Light loads (50K) w/ systematic increases Secondary procedures Dogleg, Keyseat, Junk, Undergauge First Actions

31. Locating the Problem: “Where are we stuck? Pipe Stretch Measurements

32. Pipe Stretch Equation L = Length of Free Pipe (ft)  L = Length of Stretch (in)  F = Incremental Force (lbs) W = Weight of Drill Pipe (lb/ft)

33. Locating the Problem: “Where are we stuck? Pipe Stretch Measurements “Free Point” Tool Review Stuck Pipe Handbook Procedures

34. Stuck Here Pull On DP Measure Stretch Here Measure Stretch Here Free Point Tool

35. Solids Induced Stuck Pipe Jarring Back off and wash over Secondary Procedures

36. Differential Sticking Attack Filter Cake -- Spotting Fluid Spot within 4 hrs of sticking Omit after 16 hrs Rule of Thumb - Soak minimum 20 hrs and a maximum 40 hrs Secondary Procedures

37. Pipe Releasing Agents Spotting Fluids Pump “shear thinning” spacer Viscosity: 100 rpm value > drilling mud 50 to 100 bbl spacer Calculate volume of PRA - Example Spot at highest allowable pump rate Work pipe (up/down, torque) while soaking

38. Differential Sticking Reduce Hydrostatic Cut Mud Weight “U Tube” - Kick it free Caution - Well May Come In Back Off and Wash Over Secondary Procedures

39. Mechanical Sticking Jar in opposite direction of last pipe movement Back Off and Wash Over Secondary Procedures

40. Acid Pills Calcium Formations, Strip Filter Cake Typically 7.5% to 15% HCl Cover stuck zone Pump acid quickly to bit Large water spacers Work pipe while soaking Circulate out after 5 minutes Secondary Procedures

41. Fresh Water Pills Mobile Salt Cover stuck zone plus 20 bbl inside drill string OBM - Viscous weighted spacer Maintain overpull while soaking Repeat after 2 hrs Secondary Procedures

42. Drilling Jars - Benefits Jar stuck pipe immediately Minimize fishing / sidetrack potential Minimize surface loads (safety) Something to do while waiting on tools

43. Mechanical Jars Most basic type of jar Sliding sleeve inside shoulder sleeve Holding mechanism locks hammer Overpull stretches drill string Sudden release when holding mechanism is overcome

44. Mechanical Jars - Advantages Remain locked until loaded More freedom of placement in string No special tripping procedures Do not jar unexpectedly Short jar cycle Cost Availability

45. Mechanical Jars - Disadvantages Load may not be varied Jarring immediate once load is reached Large shock to hoisting equipment Rig may not pull over holding force Difficult to load in deviated wellbores

46. Hydraulic Jars Oil reservoir w/ orifice & bypass valve Oil bleeds slowly until piston reaches bypass valve Hydraulic delay

47. Hydraulic Jars - Advantages Allows time to set drilling brake No torque needed to operate Torque does not affect load Varied impact force Use in deviated holes

48. Hydraulic Jars - Disadvantages May jar unexpectedly Tripping more time consuming Longer jar cycle More expensive Availability

49. Reasons Jars Fail to Fire Incorrect weight - calculation incorrect Pump open force exceeds compression force Stuck above jar Jar mechanism failed Jar not cocked Drag too high to load jar

50. Reasons Jars Fail to Fire (cont.) Jar firing not felt at surface Torque trapped in mechanical jar No patience

51. Accelerators - Functions Compensate for short string Compensate for hole drag slowing contraction Act as a reflector to jar shock wave Intensify jar blow

52. Jar / Accelerator Placement Considerations Sticking point Jar direction required Differential risk Neutral point of tension / compression Buckling point Drag in the hole section Depth of hole section

53. Placement - Vertical Holes Above buckling point at maximum WOB Two DC’s above jars No stabilizers above jars Accelerators needed in shallow hole sections

54. Placement - Deviated Holes Do not run jars buckled Avoid tension / compression neutral point Calculate measured weight reading required Account for hole drag

55. Jar Placement Programs Do not typically account for buckling Accurately calculate and account for pump open forces Maximize jar impact at stuck point Example - Griffith Oil Tools

56. Fishing - Overshots Catches OD of fish Right hand torque operated Always run a bumper sub Circulating sub Basket grapple More sturdy, Easier to release Spiral grapple Stronger hold, Use in slim hole Wall hooks

57. Fishing - Spears Catches ID of pipe Consider stop ring Risk back off of wash pipe Rope spears

58. Fishing - Taps Use when overshot or spear cannot be used Taper Tap - Screws inside fish Box Tap - Screws over fish Cannot be released & subject to breakage String shot cannot be run through taper tap Excessive torque will split box tap

59. Fishing - Junk Magnets Junk Baskets “Confusion Blocks” Mills Pilot, Tapered, Concave, Flat-Bottom, Section, Fluted, Watermelon

60. Fishing - Milling Pilot Tapered Concave Flat-Bottom Section Fluted Watermelon

61. Washover Operations Run minimum size required - ¼” clearance inside, ½" clearance outside Maximum length 600' drill pipe, 300' BHA Conditioning trip Easy to differentially stick Run jars in deeper hole sections Steady feed when cutting formation “Jerky” feed when going over tool joints

62. Washover Shoes Short tooth mills (mill tooth) for medium to hard formations Long tooth mills for soft formations Cut faster Hang easier Harder to get over top of fish Flat bottom for stabilizers, reamers, tool joints, etc.

63. Solving the Problem: “What do we do now?” THE OTHER OPTION: S I D E T R A C K Free Point and Back Off as Deep as Possible Go Around the Fish

64. What Do We Do Now? Sidetrack or Fish? It’s Purely a Matter of Economics Sidetrack is a good choice when: Fish Inexpensive or Recovery Unlikely Hole is Cheap (read Fast) to Drill Soft Formation - Easy to Kick Off Spread Rate (Total Daily Cost) is HIGH