The document discusses tools and methods for cleaning wells and removing debris to improve well completion and productivity. It notes that 30% of non-productive time can be caused by debris or improper planning. Various tools are presented that can help remove debris from blowout preventers, casing, wells and drill strings to reduce costs and risks from debris. These include jetting subs, well protectors, magnets and brushes to capture debris from different parts of the well completion process.

1. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Customer-focused, solutions-driven

2. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Identifying the Root Cause
“Past experience indicates between 30% of completion
NPT can be the direct result
of debris left in the wellbore or due to improper
planning and poor selection of Equipment”

3. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Why invest in preparation?
 More cost-effective & faster than remediation
 Tackles the problem at the root
 Introduces long term productivity enhancements
 Protects downhole technology investment
 Helps avoid ‘train wreck’ scenarios
‘You have one chance to complete a well correctly, compromise that opportunity and
you will compromise the productivity of that well for its entire life’
Venture UK
3

4. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Factors in Non-Productive Time
4
HH
MM
LL
FREQUENCY
OF
CAUSING
NPT
EFFORT TO MODIFY CURRENT
PRACTISE / EQUIPMENT
DEBRIS
PROBLEMS
SLICKLINE
EQUIPMENT
FAILURE
CT PERFORATING
SUBSEA
EQUIPMENT
PROCEDURESCONTRACTOR
PERFORMANCE
WELL-BORE
CLEANOUTS
NOT
LEARNING LESSONS
HH M L
= Areas above NPT line
require immediate attack
INTELLIGENT
TOOLS
TUBULAR
HANDLING
COMPLEX
DESIGNS
RIG EQUIPMENT
NPT
COST
$$$

5. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Challanges
5
Liner hanger integrity
Packers setting
Completion hanger setting
BOP / Riser cleaning
Perforation burrs
Bumping plugs
Completion setting
Completion run-in-hole
Wastewater / slops
Pulling completion
Offshore waste disposal

6. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Solutions
6
Riser Conditioning
Wellhead Preparation
BOP Jetting
Debris Removal
Waste Disposal
Waste Minimisation
Oily residue removal
Fluid & Chemical displacement
Debris Removal
Casing ID Preparation
Inflow integrity testing
ECD Management
Drill cutting removal

7. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Planned tool string for BOP Wash
7

8. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
STJS Short Trip Jetting Sub For BOP
Wash
8

9. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Our Goal
9
• Reduce NPT and rig time
• Successful tool setting
• One-run completion
installation
• Earlier production
• Extended well life
• Formation protection
• Waste minimisation

10. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Well Protector
10
The tool’s function:The tool’s function: Designed to capture andDesigned to capture and
remove debris while cleaning BOPs, andremove debris while cleaning BOPs, and
wellheadswellheads
How it works:How it works: The tool is run below the wellheadThe tool is run below the wellhead
(inside casing) during marine riser, BOP or(inside casing) during marine riser, BOP or
wellhead cleaning operations. Any debris thatwellhead cleaning operations. Any debris that
isn’t circulated out of the wellbore, fallsisn’t circulated out of the wellbore, falls
downhole and is captured in the tooldownhole and is captured in the tool
NotesNotes::
1.1. Should be spaced out deep enough to remainShould be spaced out deep enough to remain
in the casing during any pipe reciprocationin the casing during any pipe reciprocation
2.2. The contents of the Well Protector can beThe contents of the Well Protector can be
checked on location by opening the valvechecked on location by opening the valve
3.3. Primarily used during wear bushing retrievalPrimarily used during wear bushing retrieval
operationsoperations
Diverter CupDiverter Cup
ValveValve
ScreenScreen
Well
Protector

11. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Well Protektor
11

12. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.12
Junk from WPR after BOP Wash

13. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Junk from WPR after BOP Wash
13

14. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Debris Recovery Tools
14
Magno
Shoe
Junk
Muncher
Well
Patroller
Well
Protector
Magno
Star

15. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Magnostar
15

16. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Debris on MSTAR after BOP Wash
16

17. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
11’’ STJS
17

18. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Animasjon of STJS
18

19. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Tool categories
• Casing Cleanup Tools – Brushes & Scrapers
• Liner Top Test & Formation Protection Tools
• Circulation Tools
• Debris Recovery Tools
• BOP Cleaning Tools
• Customized Tools
19

20. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.20
Casing Cleanup Tools – Brushes & Scrapers
Razor
Back®
HD Razor
Back®
Bristle
Back®
Ridge Back
Burr Mill
Switchback ScraperRazor Back CCT
with Integral Top
Dress Mill

21. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.21
Liner Top Test & Formation Protection
Tools
Well
Commissioner

22. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Circulation Tools
22
Single Action
Bypass Sub
Ported By-
Pass Sub
Dual-Action
Bypass Sub
Multi-Function
Circulating Tool,
Clutch
Heavy Duty
Multi-Function
Circulating Tool
Well Commander

23. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Customized Tools
23
Bearing
Sub
Disengageable Mill
Assembly Pressure Shear
Sub
Well Scavenger

24. 24 CONFIDENTIAL INFORMATION ©2009 M-I L.L.C. 10.02.16
M-I SWACO
Specialized Tools
•MAGNOSHOE
•MAGNO STAR
•WELL SCAVENGER
•RAZOR BACK
•WELL COMMANDER
A closer look at some
Specialized Tools

25. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
The MAGNOSHOE

26. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.

27. 10.02.16
10.02.16
Confidential Information © 2010 M-I SWACO27
First test, workshop
46kg on M20 Nut 681kg on full plate cover

28. 10.02.16
Clamp Fishing

29. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
● Run as an integral part of the drill string during
clean-up to collect and remove ferrous metal
debris
from the well.
● Run as part of most drilling/milling/polishing
assemblies, being able to be rotated and
reciprocated
without fear of damage to casing or the tool.
MAGNOSTAR
Applications

30. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
9 5/8" MAGNOSTAR
–John Shaw Jan 10)
■ Large capacity for up to 200 lbs
(91
kgs) of ferrous material retrieval
■ High strength, rare earth
magnets
rated to 350° F (177° C)
■ Removable Magnets for body
inspection
■ Designed with Premium Hi-
Torque connections
■ No flow restriction below the
tool permitting large debris-free
access to magnets
■ Recovered debris easily
removed on location
MAGNOSTAR
Collects more debris than any other magnet on today’s market
Benefits

31. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
MAGNOSTAR – North Sea

32. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
MAGNOSTAR – North Sea

33. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
MAGNOSTAR – North Sea

34. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
MAGNOSTAR RECOVERIES - E15 (Slot 02)/OH- DWG, Baku

35. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
BP Florena N4, Colombia Dec 10
Comparative Debris
Recovery Table
BHA Model Number Field Recovery
1
9-5/8”
MAGNOSTAR
12.0 lb
1 7” MAGNOSTAR 14.8 lb
1
9-5/8”
CONVENTIONAL
MAGNET
4.42 lb
1
9-5/8”
CONVENTIONAL
MAGNET
2.52 lb
1
9-5/8”
CONVENTIONAL
MAGNET
3.51 lb

36. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
2 MAGNOSTAR string magnets after 2nd casing cutter run. 188kg
2 MAGNOSTAR string magnets after casing spear run
44kg
2 MAGNOSTAR string magnets after POOH from casing cutting run 79kg
3 MAGNOSTAR string magnets after POOH from 3rd clean outrun 310kg
3 MAGNOSTAR string magnets after POOH from 2nd cleanout run 176kg
3 MAGNOSTAR string magnets after POOH with Milling / 3 MAGNOSTAR
cleanout assembly (1st
run) 146kg
2 MAGNOSTAR string magnets after POOH from unsuccessful
attempt to run packer 117kg
2 Magnostar string magnets after dressing cement plug 120kg
Azeri Fishing Job Feb 11 -DWG Platform- E15 (Slot
02)/OH

37. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.37

38. 10.02.16
Well Scavenger* Debris Recovery Tool
M-I SWACO Specialized Tools
38
* Mark of M-I L.L.C.

39. 10.02.1639
ENGINE MODULE
Creates lower
pressure zone which
initiates and
maintains localised
reverse flow
ENGINE MODULE
Creates lower
pressure zone which
initiates and
maintains localised
reverse flow
DEBRIS SCREENING
MODULE
Captures ferrous debris
and other debris above
a certain size
DEBRIS SCREENING
MODULE
Captures ferrous debris
and other debris above
a certain size
DEBRIS CHAMBER
MODULE(S)
Captures debris in
discrete sections for
safe and efficient
handling
DEBRIS CHAMBER
MODULE(S)
Captures debris in
discrete sections for
safe and efficient
handling
BOTTOM SUB
Connects to
tailpipe and any
other accessories
below
BOTTOM SUB
Connects to
tailpipe and any
other accessories
below
Modular System Components

40. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
40

41. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.41
Casing Cleanup Tools – Brushes & Scrapers
Razor
Back®
HD Razor
Back®
Bristle
Back®
Switchback
Scraper
Razor Back CCT
with Integral Top
Dress Mill

42. 10.02.16
WELL COMMANDER
A drilling valve that is activated via steel ball, offering a
variety of options to the operator:
•Reduced pressure drop allows greatly increased pump rates to aid
cuttings-beds removal with higher fluid-flow velocities
•Coarse lost-circulation or wellbore-strengthening materials can bypass
sensitive downhole drilling tools and be easily placed in the loss zone
•Kill-weight fluid can be pumped in underbalanced or managed-pressure
drilling applications before initiating a trip
•Excellent for hole cleaning during underreaming, hole-opening, or coring
operations
•The tool can condition fluid at high flow rates in any drilling or
displacement string
•Helps fill or drain the drillstring during trips to control surge and swab
pressures and to enhance tripping operations by minimizing fluid
discharge
Often referred to as a “Drilling By-Pass Sub Valve” or
“Circulating Valve”
3 CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.

43. 10.02.16
WELL COMMANDER – Primary Applications & Rig Time
Savers
Boosting Annular Velocity
•Cuttings and debris removal for
enhanced hole cleaning, especially in
ERD wells
•Higher flow rates above BHA
restrictions
•Underreaming / milling operations
•Riser/BOP Washing
Spotting LCM
•Eliminate trips for redress or open
ended drillpipe
•Medium- and coarse-LCM compatible
Other Applications
•Displacements and
cleanouts
•Conditioning fluids
•Specialized coring
techniques
Through-bore
maintained >
Tandem run options
> Free-point access
>
Tripping Dry Pipe
•The automatic locking mechanism gives
enhanced options for improved pipe
drainage or filling, especially with small pipe
or restrictive BHAs
Bypass Ball Catcher
•Run other, smaller-drop-activated tools below the
WELL COMMANDER i.e. hole enlargement tools and
core barrels. Safe for coring operations. Does not
trap pressure.
•WELL COMMANDER not activated by smaller balls
CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.

44. 10.02.16
CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
WELL COMMANDER - Improved Technical Limits
See animation

45. 10.02.16
WELL COMMANDER - Open and close sequence
Main body
Proprietary
upper ball
seat
CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.

46. 10.02.16
Ball Catcher Technology
Bypass Ball Catcher
● All WELL COMMANDER balls are collected in the ball
catcher
● Through-bore maintained
● Access below the tool for smaller-ball-activated tools
● Option to activate tools independently
● Select wireline access below WELL COMMANDER
Note: accessibility may depend on wireline tool dimensions and
number of balls in the ball catcher
CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.

47. 10.02.16
WELL COMMANDER – ByPass Ball Catcher
9 CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.

48. 10.02.16
WELL COMMANDER – Technical Data
WELL COMMANDER (size in.) 91/2 81/4 7 5
Material AISI 4145 AISI 4145 AISI 4145 AISI 4145
OD (in.) 9.50 8.25 7.00 5.00
Min ID Lower ball seat 2,40 2.40 1.985 1.610
Length (ft) 18.2 18.1
13.7
(incl. catcher)
11.8
(incl. catcher)
Number of circulating ports (in. x in.) 5 5 5 (1.35 x 0.65) 5 (1.10 x 0.50)
Total circulating area through ports (TFA) 6.43 sq. in. 6.43 sq. in. 3.93 sq. in 2.48 sq. in.
Max circ rates (closed/open)
1344/1680
gpm
1344/1680
gpm
840/1050
gpm
672/840
gpm
Opening/closing pressure (Operating and
shut-off balls)
1,600psi (+/-20%)
And 800 max
1,600psi
(+/-20%)
And 800 max
2,000psi (+/-20%)
And 650 max
2,000psi
(+/-20%) and
430 max
Cycles (ball capacity of catcher)
7 (14) 7 (14) 7 (14) 7 (14)
O.D. Opening / Closing Ball (in.) 2.500 2.500 2.125 (2 1/8) 1.760
O.D. BHA Shut-off Ball (in.) 2.430 2.430 2.063
1.698 (shot
blasted)
Connection, Up – standard tool (in.) 7-5/8 REG Box 6-5/8 REG Box
4 1/2 IF Box
(XT57 also)
3 1/2 IF Box
(NC38)
Connection, Down (in.) 7-5/8 REG Pin 6-5/8 REG Pin
4 1/2 IF Pin
(XT57 also)
3 1/2 IF Pin
(NC38)
10 CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.

49. 10.02.16CONFIDENTIAL INFORMATION ©2009 M-I L.L.C.
Research & Development
13.3/8” Well Commissioner*
testing
MFCTC* set up for test in Type
‘D’ Bowen Jar Tester
Switchable Magno Back* Build
Test
Rig Test of Well
Scavenger*
Fit test for Riser Cleaning Tool*
Magno Star* rig test
Computational Fluid
Dynamics model on Well
Scavenger*
*Mark of M.I. L.L.C