Anadrill  -_2_days_stuck_pipe_2nd
Upcoming SlideShare
Loading in...5
×
 

Anadrill -_2_days_stuck_pipe_2nd

on

  • 1,884 views

Directional drilling training, part 2

Directional drilling training, part 2

Statistics

Views

Total Views
1,884
Views on SlideShare
1,884
Embed Views
0

Actions

Likes
0
Downloads
91
Comments
0

0 Embeds 0

No embeds

Accessibility

Upload Details

Uploaded via as Microsoft PowerPoint

Usage Rights

© All Rights Reserved

Report content

Flagged as inappropriate Flag as inappropriate
Flag as inappropriate

Select your reason for flagging this presentation as inappropriate.

Cancel
  • Full Name Full Name Comment goes here.
    Are you sure you want to
    Your message goes here
    Processing…
Post Comment
Edit your comment

    Anadrill  -_2_days_stuck_pipe_2nd Anadrill -_2_days_stuck_pipe_2nd Presentation Transcript

    • Stuck Pipe Prevention Prentice & Hill, LLC Second Day
    • 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
    • Solids Induced Pack-off
      • Formation Loose w/ Little or No Bonding
      • Insufficient Hydrostatic to Hold Back Formation
      UNCONSOLIDATED FORMATIONS Causes
    • Pack-off Due to Unconsolidated Formations Prevention
      • Gel up Mud / Run Hi Vis Sweeps
      • Control Drill
      • Spot Gel Pill Prior to TOH
      Plan / Anticipate:
    • 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:
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • Mechanical / Wellbore Geometry Sticking Causes LEDGES & DOGLEGS
      • Run Packed Hole Assemblies
      • Ream on Trips Through Problem Zones
      • Limber BHAs
      • Hard - Soft Interbedded Formation
      Prevention
    • Mechanical / Wellbore Geometry Sticking Causes SHOE JOINT BACKS OFF
      • Do Not Overdisplace Cement
      • Thread Lock Bottom 3 Joints of Casing
      • Drill Out Carefully
      Prevention
    • 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
    • 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
    • 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
    • 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
    • Trend Analysis
      • Plot Property -vs- Depth or Time and Analyze
        • Drag on each Connection
        • Torque -vs- Depth
        • PWD -vs- Time
        • Soap Box
    • Pressure While Drilling
    • Pressure While Drilling
    • Pressure While Drilling
    • Drag on Trip
    • Recovery Our Best Preventive Efforts Have FAILED WE’RE STUCK !! What Do We Do Now?
    • Identifying the Problem: “Why are we stuck?”
      • Stuck Pipe Handbook Flowcharts
    • Problem Diagnosis
      • Computer Intelligent System on Network at Cambridge Facility
      • Charts in Front of Sedco Forex Handbook
    • Solving the Problem: “What do we do now?”
      • First Actions
    • 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
    • Solids Induced Stuck Pipe
      • Do not commence jarring
      • Increase standpipe pressure to 1500 psi
      • Work pipe
      • Commence secondary procedures
      Continued First Actions
    • 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
    • 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
    • Locating the Problem: “Where are we stuck?
      • Pipe Stretch Measurements
    • 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)
    • Locating the Problem: “Where are we stuck?
      • Pipe Stretch Measurements
      • “Free Point” Tool
        • Review Stuck Pipe Handbook Procedures
    • Stuck Here Pull On DP Measure Stretch Here Measure Stretch Here Free Point Tool
    • Solids Induced Stuck Pipe
      • Jarring
      • Back off and wash over
      Secondary Procedures
    • 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
    • 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
    • Differential Sticking
      • Reduce Hydrostatic
        • Cut Mud Weight
        • “U Tube” - Kick it free
        • Caution - Well May Come In
      • Back Off and Wash Over
      Secondary Procedures
    • Mechanical Sticking
      • Jar in opposite direction of last pipe movement
      • Back Off and Wash Over
      Secondary Procedures
    • 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
    • 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
    • Drilling Jars - Benefits
      • Jar stuck pipe immediately
      • Minimize fishing / sidetrack potential
      • Minimize surface loads (safety)
      • Something to do while waiting on tools
    • 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
    • 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
    • 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
    • Hydraulic Jars
      • Oil reservoir w/ orifice & bypass valve
      • Oil bleeds slowly until piston reaches bypass valve
      • Hydraulic delay
    • 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
    • Hydraulic Jars - Disadvantages
      • May jar unexpectedly
      • Tripping more time consuming
      • Longer jar cycle
      • More expensive
      • Availability
    • 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
    • Reasons Jars Fail to Fire (cont.)
      • Jar firing not felt at surface
      • Torque trapped in mechanical jar
      • No patience
    • Accelerators - Functions
      • Compensate for short string
      • Compensate for hole drag slowing contraction
      • Act as a reflector to jar shock wave
      • Intensify jar blow
    • 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
    • Placement - Vertical Holes
      • Above buckling point at maximum WOB
      • Two DC’s above jars
      • No stabilizers above jars
      • Accelerators needed in shallow hole sections
    • Placement - Deviated Holes
      • Do not run jars buckled
      • Avoid tension / compression neutral point
      • Calculate measured weight reading required
      • Account for hole drag
    • 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
    • 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
    • Fishing - Spears
      • Catches ID of pipe
      • Consider stop ring
      • Risk back off of wash pipe
      • Rope spears
    • 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
    • Fishing - Junk
      • Magnets
      • Junk Baskets
      • “Confusion Blocks”
      • Mills
        • Pilot, Tapered, Concave, Flat-Bottom, Section, Fluted, Watermelon
    • Fishing - Milling
      • Pilot
      • Tapered
      • Concave
      • Flat-Bottom
      • Section
      • Fluted
      • Watermelon
    • 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
    • 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.
    • 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
    • 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