Bout.pptx

20 September 2022
“Confidential - For Internal Use Only. © 2007 Halliburton. All Rights Reserved.”
VersaFlex®
Expandable Liner Hangers
August 2007

Topics Discussed:
– Product Overview
– Product Development
– Service Quality

3
 Simplicity
 Liner Top Integrity
• Redundant sealing elements
• Gas tight seal
• Hydraulic set packer elements
 Deploying liner
• No slips
• No external moving parts
• High torque rating
 Improved cementing jobs
• Rotation and reciprocation
• Increased flow rates
• No place for well debris
• No tortuous fluid flow paths
Advantages of Expandable Liner Hangers

4
405 Installations
Longest Liner
4.50” x 9,967 ft
9.625” x 8,562 ft
Mud Weight Range
4.2 ppg – 19.8 ppg
Temperature
Range
100 - 386°F
Shortest Liner
35 ft
Installation History through Q207
Deepest TOL: 19,876 ft
Deepest Liner Shoe Set
24,235 ft

5
Compare the procedures for installation
• Conventional Hanger
1. Drop ball (pump down)
2. Set hanger (pressure)
3. Check hanger set (set down weight)
4. Release setting tool (torque)
5. Check if RT is released (pick up)
6. Blow ball seat (pressure)
7. Pump cement job (rotate)
8. Expose packer dogs (pick up)
9. Set the packer (set down weight)
10.Pull pack off (pick up)
• Expandable Hanger
1. Pump cement job (rotate & recipro.)
2. Set hanger-packer (pressure)
3. Check hanger set (over pull)
4. Release RT (slack off)
Flapper Activated

6
The strength of VersaFlex® liner hanger:
• Single bi-directional bonded seal
– Multiple redundant bi-directional
bonded seals
• Liner cement not required in lap for
pressure integrity
• Independent of mechanical hold-downs
• Replaces slips as in conventional
equipment
• Bonded elastomer holds up to rigorous
circulation
• Multiple installations worldwide without a
seal failure
Superior Annular Seal

7
Superior Annular Seal

8
Improved Load Capacity
Tensile
– Five- and three-element VersaFlex
hangers available
– Single 1 ft element capable of 500,000
pound tensile load
– 7-5/8” x 9-5/8” rated to 750,000 pound
hanging capacity
– Practical limit is liner thread connection
Compression
– 7/7-5/8” x 9-5/8” rated to 500,000 pounds
– Not limited by liner thread connection

9
VersaFlex Expandable Liner Hanger
• Production Liner - 240
• Drilling Liner - 89
• Conventional Screen
• Expandable Screen
• Large Monobore
• Permanent Packer
• Scab Liner
• Casing Patch
• Slotted Liner
• Combined Cemented and
Slotted Liner / Screen
• Pinpoint Completion
• Multiple Stage Cementing
• Swell Packers
• ESIPC – Combined Stage Tool
and Inflatable Packer
• Hole Conditions
– Reaming
– Drill-In
– Washing
– Lost Circulation
– Extended Reach
– Underbalanced
Applications Proven Flexibility

10
Open Hole Completion Project (SAW)
• Swell Packers for Isolation
• New Designed Hanger Body
– Less expensive
– Shorter – all tools 3 elements
– Reduced setting pressure and operating envelope
– 7 x 9-5/8 47-53.5 ppf completed
– 5 x 7 26 ppf in design
– 13cr and Alloy designs
• New Design Setting Tool – for Washdown
– Expendable ball seat
– Allows for annulus test after setting
– Allows for wash pipe
– Allows for acid treatment after setting

11
Open Hole Washdown Setting Tool
• RIH position
• Land ball and expand hanger
• Extrude ball
• Release from hanger
• Release dogs and seal washpipe
• Acidize position

12
Open Hole Completion

13
PinPoint Completion
• Features and Benefits
– Improve frac cycle time
– Intervention-less stimulation of multiple zones
– Provide accurately placed treatments
– Reduce Cost
– Allows re-stimulation of individual zones.
• Speed of Completion
– No well bore entry required
– Continuous pumping
• Versatile and Robust
– Mechanical water conformance
– High rate proppant frac’s
– Cemented or open hole completions

14
PinPoint Completion
• VersaFlex® ELH, Delta Stim™ Sleeves and
Swellpackers™:

15
SuperFill™ Diverter Tool
• SuperFill Surge Reduction Benefits:
– Allows Increased Running Speed
– Reduces Surge Pressure on Weak Formations
– Reduces Costly Mud Losses
– Reduces Formation Damage
• SuperFill Diverter Features:
– Used in Subsurface or Liner applications
– Provides flow path from drill pipe ID to drill
pipe annulus above the liner
– Reduces frictional pressure loss
– Operable multiple times with reciprocation
– Permanently deactivated with Activation Plug
– Full bore ID before and after closure
– Can be run with or without Drag Blocks

16
SuperFill™ Operating Sequence

17
SuperFill Type FV Auto-Fill FE
Technical Specifications
Casing Size, inches 4-1/2 - 5-1/2 7 and larger
Phenolic Ball Size, inches 1-3/8 2-3/8
Shifting Pressure, psi 900 to 1,200
Flow Area, sq-in 1.23 3.97
Back Pressure Rating1, psi 5,000
1 – Back Pressure Rating dependent on casing size, weight, grade,
and thread.

18
SuperFill™ Type FV Operating Sequence

19
Current Portfolio
• 5” x 7” 20-35 ppf
• 5 ½” x 7” 20-29 ppf
• 5-1/2” x 7-5/8” 29.7 – 39 ppf
• 7-5/8” x 9-5/8” 36-53.5 ppf
• 7-5/8” x 9-7/8” 62.4 ppf
• 9-5/8” x 11-3/4” 60 - 65 ppf
• 9-5/8” x 11-7/8” 71.8 ppf
• 11-7/8” x 13-3/8” 61-72 ppf
• 11-7/8” x 13-5/8 88.2 ppf

20 September 2022
Product Development

21
New Products
• Present New Product Design Tasks
– High Torque Setting Tool
– Flapper Valve Upgrade
– Improved Operating Envelope for Hangers
– Low Cost Expandable Hangers
– 3-1/2” x 5-1/2” VF new tool design
– 7-5/8” x 9-5/8” 58.4 ppf VF new tool design
– 5” x 7” VF SAW design
• Open Hole Completion
– Large Hanger Sizes

22
High Torque Setting Tool
• Enhancements
– Torque enhancements
– Eliminate shear pins
– Eliminate need for the rupture disk
– Re-design emergency release
– Added feature to allow for setting the tool without
landing a plug or dropping a ball
• 7-5/8 x 9-5/8 complete
– Tools in New Iberia, Mexico, and Norway
• 5 x 7, 5-1/2 x 7-5/8
– Manufacturing prototypes

23
• Apply pressure after landing wiper plug
– Shifts ball seat up
– Flapper closes
– Flapper assembly shifts down
– Expansion initiated
Setting the Hanger (VersaFlex HT)

24
– Run liner
– Set down to position J slot
– Rotate to shear pins and operate J
– Pull up to activate flapper and position locking
dogs
– Flapper closes
– Apply pressure to open bypass and expand
– Set down to release hanger (with or without
expansion)
Contingency Setting / Release (HT)

25
Torque Ratings
Torque Ratings:
•13-3/8 x 11-7/8 – 45,000 ft-lbs
•11-7/8 x 9-5/8 – 45,000 ft-lbs
•9-5/8 x 7-5/8 – 15,000 and 37,000 ft-lbs
•7-5/8 x 5-1/2 – 15,000 and 30,000 ft-lbs
•7 x 5 – 15,000 and 30,000 ft-lbs

26
Flapper Valve Modification
• Must land plug
• Apply pressure – shifts sleeve and deploys
flapper
• Release pressure and expand
• Eliminates rupture disk
• 5x7, 5-1/2x7-5/8, 7-5/8x9-5/8

27
Flapper Valve Modification
• Can be run with setting ball
– Can utilize rupture disk
• When plug does not land
– Drop setting ball for contingency set
– Apply pressure and set

28
Improved Operating Envelope
• New Manufacturing process
• Change PBR to match BOT
• New Cone design
• SPECS should match BOT for Tie Back Operations
• Additional FEA will be performed to further improve
Operating Envelope
• Roll out will include flapper upgrades for present setting
tools
• Status
– Designs complete for 5 x 7, 5-1/2 x 7-5/8, 7-5/8 x 9-5/8
– Should prototype test 7-5/8 x 9-5/8 in 4 weeks

29
Low Cost Hangers
• Will be manufactured from new material
• Will have improved Operating Envelope when
compared to present tools
• Will use current running tools
• Will require qualification testing
• Initial estimates indicate 50% reduction in COGS
• Status
– Designs completed for 7 x 9-5/8, 5 x 7, 5-1/2 x 7-5/8
– Material ordered
– Expect to commercialize early Q107

30
Portfolio Additions
• 3-1/2 x 5-1/2”
– Concept complete
– Primary design hurdles
• Requires new design for torque rating
• Requires new downhole force multiplier to compensate for
extremely low cross section
– 75% complete
• 7-5/8 x 9-5/8” 58.4 ppf
– Expect late Q407, early Q108 commercialization

31
CRA Development Efforts
• CRA Hangers
– S13cr equivalent
• 7 x 9-5/8 released
• 5 x 7 released
– Severe sour service
• Inc 825 equivalent successfully passed corrosion testing at
300° F
• Inc 825 equivalent successfully passed expansion tests
• Designs complete for 7-5/8 x 9-5/8 and 5 x 7

20 September 2022
Service Quality

33
VersaFlex Reliability Statistics
* Reliability Data is self assessed based on internally developed criteria
Reliability at 329 Jobs
* 94%
Qualifiers
1. Setting Tool Failures
• (3 which occurred on jobs 13, 33 & 48,
none since)
2. System Component Failures
• System Component Problems
• Components are described as
Plugs, Wipers etc.
2007 YTD Q2 Reliability for
129 Jobs
* 82%
Total IRJ – 23
Qualifiers (multiple failures per job)
1. 7 Cement Equipment Failures
2. 6 Operator Error
3. 5 Rig Equipment Issues
4. 4 Assembly Issues
5. 1- Setting Tool Failures – Rupture Disk
6. 1 Hole Condition – Junk on Cone

34
Service Quality
• Cementing Equipment – 9 issues
– Foam Dart landing early – 6
– SSR Swivel Equalizer Valve failures – 2
– Floats not holding – 1
• Action
– Remove Foam Dart from Service
• Design teams working on replacement components
– New plug design to eliminate SSR Equalizer Valve
from service

35
Equalizer Valve action

36
Service Quality
• Operator Error – 7 issues
– Incorrect sized darts and plugs - 3
– OD / ID issues – 2
– Too much weight – premature release – 1
– Not aware of simultaneous rig operations - 1
• Action
– Check cementing equipment for compatibility in the
well
– Caliper all equipment prior to running in hole
– Follow installation procedures
– Be aware of any rig operations – discuss in
operations briefing

37
Service Quality
• Assembly – 5 issues
– Ball Seat shear pins installed incorrectly - 2
– Improper Torque procedure - 1
– Collet support sleeve retaining screws sheared during
installation - 1
– Sealing mandrel installed upside down - 1
• Action
– Follow BDMI during assembly
– Support bushing modification designed for collet
support sleeve
– Level tools prior to applying torque to connections

38
Bucking Unit Selection
What to be aware of if using
drilling-type units for making up
tubing/casing connections
– These units typically utilize 3 or
6 small jaws to grip the tubular
– This can result in point loading
at the jaws which increases the
risk of crimping or collapse on
thin walled tubulars such as the
VFELH.
– A non-level assembly will further
increase point loading through the
cantilever effect
Completion-type
jaw and die
arrangement
(large jaw
coverage)
Drilling-type jaw
and die
arrangement
(low jaw
coverage)

39
Service Quality
• Rig Equipment – 5 issues
– Weight indicator malfunction – 1
– Pumps not filling pipe - 1
– Torque limiter - 1
– Single joint compensator - 1
– Washout in drill string - 1
• Action
– Ensure all rig equipment is functioning properly
• Compare WIR to calculated buoyant corrected expectations
• Watch for circulation during pipe filling operations
• Advise customer of high pressure requirements

40
Service Quality
• Setting tool issues – 2
– Premature rupture disk failures – 2
• Action
– Rupture disk Quality Control issues addressed
– One failure still under investigation
• Hole Condition issues – 2
– Junk on top of cone -1
– Rubber compatibility – 1
• Action
– Request that the BOPs be jetted on last trip out of the hole
– Monitor condition of slips and tongs before, during and after the
job
– Utilize hole covers and pipe wiper rubbers while running liner

41
Service Quality – Far Pacs
• Use the correct Far PAC (Latest version on the
web)
• Fill in data input on cover page completely &
accurately
• Complete schematic properly and accurately
• Fill in job log with detail

42
Service Quality - 2007
• Developing new software package – V-Jas
– Modules
• Calculations
– Surge and swab, hydraulics, cementing
– Torque and drag in version II
• Job Log
• Well schematics
• Tool Diagrams
• Liner tally
• Case history
• Help files
– User Friendly interface
• English and Spanish
– Will replace Far Pac
– Beta testing in Q307

43
Tally

44
Surge and Swab

45
WIR

46
Job Log

47
Pre-Job Planning Activities
• Customer and Halliburton pre-planning
• Well Info (Utilize Inquiry Data Sheet) & Submit Well Survey Data
• Planning software to check torque and drag
calculations for svc. tool set-up and base
procedures
– Well Plan/ CTES “Orpheus”
– Baroid DFG
• Software to calculate liner job parameters on
location
– Far Pac
• Cement Planning
– Opti-Cem

48
VersaFlex Inquiry Sheet
VersaFlex Expandable Liner Hanger System
Inquiry Sheet
Date: Job Timing:
Account Rep: Phone #:
Company Name: Company Rep:
Lease / Well Name & #: Telephone #:
Field / Block: Fax #:
City/County: Email:
State: Country:
Rig Name: Rig Phone #:
Rig Site Contact: Rig Fax #:
Rig Type: Top Drive?
Well Plan: Well Information
(Please supply a copy of Well Schematic and Survey Data as ASCII or Excel data.)
Liner Size: Well Type: Casing Size:
Weight: OH Size: Weight:

49
Job Planning
BSP BG 9
Downhole Pressure Profiles
Minimum Hydrostatic Pressure and Maximum ECD vs. TVD
2 4 6 8 10 12 14 16 18
ECD (lb/gal)
5000
5500
6000
6500
7000
7500
8000
8500
TVD
(ft)
Pore Pressure Gradient Fracture Gradient
Minimum Hydrostatic Gradient Maximum ECD
Previous Casing Shoe
Customer: Brunei Shell Petroleum Co. Job Date: 02-May-2007 Sales Order #:
Well Description: Bugan 9 (ID 12) UWI:
H A L LIB U R T O N
OptiCem v6.0.0p1
02-May-07 02:56
BSP BG 9
Summary
ECD at 6372 ft TVD, Wellhead Pressure, Pump Rate, and Density vs. Liquid Volume
0 100 200 300 400 500 600 700
Volume In (bbl)
8
9
10
11
12
13
14
15
16
ECD
at
6372
ft
TVD,
Fluid
Density
In
(lb/gal)
0
250
500
750
1000
1250
1500
1750
2000
2250
2500
Wellhead
Pressure
(psi)
0
1
2
3
4
5
6
7
Rate
(bpm)
ECD Fluid Density
Wellhead Pressure Rate
7
6
5
4
3
Fluids Pumped
2 3 4
5 6 7
SCHL Mud Push DS TailCmt Water
BSP Mud SCHL Mud Push BSP Mud
H A LLIB U R T O N
OptiCem v6.0.0p1
02-May-07 03:00
BSP BG 9
Fluid Positions at Job End
Time = 129.39 min, Volume In = 640.19 bbl
15 10 5 0 5 10 15 20
Diameter (in)
8 10 12 1416
Density (lb/gal)
0
2500
5000
7500
10000
12500
15000
17500
Measured
Depth
(ft)
Fluids Pumped
BSP Mud
SCHL Mud Push
DS 1
Water
BSP Mud
SCHL Mud Push
BSP Mud
9714.4 (5595.8)
11082.4 (6029.6)
MD (TVD)
Casing
Annulus
Customer: Brunei Shell Petroleum Co. Job Date: 02-May-2007 Sales Order #:
Well Description: Bugan 9 (ID 12) UWI:
H A L L IB U R T O N
OptiCem v6.0.0p1
02-May-07 03:03
Effective Tension (kN)
-1000 -800 -600 -400 -200 0 200 400 600 800 1000 1200 1400
Measured
Depth
(m)
0
1000
2000
3000
4000
L E G E N D
Slide Drilling w 270KN (5 pins)
Tension Limit
Helical Buckling (Non Rotating)
Helical Buckling (Rotating)
Sinusoidal Buckling (all operations)
Slide Drilling
Rotate Off Bottom
Tripping Out
Tripping In
Slide Drilling w 213KN (4 pins)
Torque (ft-lbf)
0 5000 10000 15000 20000 25000 30000 35000
Measured
Depth
(m)
0
1000
2000
3000
4000
5000
L EG END
Torque Limit
Rotate Off Bottom
Tripping Out
Tripping In

50
Perform Basic Pre-Job Checks
HMS Procedures
• Check Equipment against call sheet
• Inspect and measure
• Review Job Packet
• Review Procedure with Company representative
• Acquire liner and drill pipe tally
– Spot check sampling of liner tally
• Prepare liner tally
• Perform Pre-Job Calculations
• Review calculations with Cementing Company and
Company rep
• Cement equipment capable of expansion

51
Training Class in Development

52
Training Class in Development
• Instructor Led Training Course for Operators
– Includes:
• Hydraulics
• Tools
• Cementing
• Best Practices
• Irregular job reviews
– First Class Q3/07

53
David Matus – Team Leader
4 Design Engineers
1 Sustaining Engineer
2 Drafters
Ron Nida
Product Manager
Houston, TX
James Williford
Global Product Champion
Houston, TX
Tance Jackson
Global Advisor
Carrollton, TX
Winston Fouts
Global Coordinator
Carrollton, TX
Ken Caskey
Technology Application Manager
Carrollton, TX
Bob Berry
Manufacturing BUM
Carrollton, TX
1 Planner
2 Procurement Specialists
2 Quality Inspectors
Global Communication Structure
VersaFlex®
Global Support Staff

20 September 2022
Questions

Bout.pptx

Recommended

Recommended

More Related Content

What's hot

What's hot (20)

Similar to Bout.pptx

Similar to Bout.pptx (20)

Recently uploaded

Recently uploaded (20)

Bout.pptx