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Coiled Tubing
Basics & Applications
Presented By:
Nguyen Tan Khoa
Lead Well Operations Engineer
KNOC Vietnam
Ho Chi Minh City
Nov 14, 2015
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Contents
Part 1: Coiled Tubing Basics
• Why Coiled Tubing?
• Fabrication
• Coiled Tubing Equipment
• BHA
• String Characteristics & Selection
• Safety Considerations & Failure Modes
• Job Modeling
• String Life Management
2
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Contents
Part 2: Coiled Tubing Applications
• Circulating, Cleanouts & N2
Lifting
• Milling, Fishing• Logging & Perforating
• Fluid / Chemical Placement
• Down-hole Camera
• Gravel Packs & Sand Control
• Hydra-Jet Technology
• Fracturing
• Moving & Setting
• Tractors
• Tapered OD Coil
• E-Coil
• Coiled Tubing Drilling
• CT Boat Operations
• Capillary Coil
3
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Why Coiled Tubing?
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• What are the options, when .. – Fish (object) in the well
– Hard scale deposits in the casing
– You need fluid placed into 1 zone, but not all – Logging into a horizontal well
• You will need something to reach in the well… – To grab objects
– To transport sensors
– To pump & circulate fluids
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Part 1: CT Basics: Why Coiled Tubing?
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Electric Line – Wire Line
• A metal wire, or electric cable, inserted into the wellbore.• Carries tools to perform work.
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Part 1: CT Basics: Why Coiled Tubing?
Pro
• Lightweight, fast, small.
• Can deploy sensors, set
plugs, and move objectsinto the well. (Highly
versatile)
• “Light touch” - can perform
sensitive operations.• Can work under-balanced =
the well is live and flowing.
Con
• Cable is gravity fed into the
well
– Steep deviations andhorizontal wells can be un-
reachable.
– Cannot set-down much
weight on bottom.
• Cable is weak (low pullstrength)
• Cannot circulate fluids.
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Electric Line – Wire Line
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• Drilling rig
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Part 1: CT Basics: Why Coiled Tubing?
Pro
• The most powerful option.
• Can deploy heavy-duty tools
into the furthest parts ofany well.
• Can circulate fluids.
Con
• Well must be dead.
• Expensive (!)
• Large (!)
• Slow
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Drilling Rig
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Part 1: CT Basics: Why Coiled Tubing?
Hydraulic Work Over
• Like a small drilling rig, uses joints of pipe.• Can work under pressure (well is live).
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Part 1: CT Basics: Why Coiled Tubing?
Pro
• Can pump fluid.
• Can set-down & pick-up
high weights.• Can deploy tools, sensors,
plugs, etc into the well.
• Stiff, can reach deviated &horizontal sections of the
well.• Can work under-balanced =
the well is live and flowing.
Con
• Large footprint on theplatform. (A lot ofequipment)
• More expensive than E-Lineand Coiled Tubing
• Heavy weights on theplatform structure.
• Uses joints of pipe, like adrilling rig = slowoperations.
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Hydraulic Work Over
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Part 1: CT Basics: Why Coiled Tubing?
Coiled Tubing
• A continuous metal tube,inserted into the wellbore.
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Part 1: CT Basics: Why Coiled Tubing?
Pro
• Can pump fluid.
• Can set-down & pick-up highweights.
• Carries tools, sensors, plugs,etc into the well.
• Stiff, can reach deviated &horizontal sections of the well.
• Continuous tubing = fast
• Can work under-balanced =the well is live and flowing.
Con
• Large footprint on the
platform. (A lot of
equipment)• More expensive than E-Line
• Coiled tubing reel is heavy
to pick up.
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Coiled Tubing
IN SUMMARY …. Coiled Tubing offers a good
balance between size, cost, weight, & efficiency.
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Part 1: CT Basics: Why Coiled Tubing?
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Maybe that’s why it’s so popular around the world …
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Fabrication of Coiled Tubing
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Part 1: CT Basics: Fabrication of Coiled Tubing
Some images courtesy Quality Tubing
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Part 1: CT Basics: Fabrication of Coiled Tubing
Raw material is suppliedin a roll of standard
mass.
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• Steel is
rolled
into
sheets.
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• Sheets are
pressed to
an exact
thickness
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• 40,000 lb
rolls.
• Each roll is a
specific
thickness of
steel plate.
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• Rolls are
cut down
into
“slits”.
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• The slits are
transported
to another
factory.
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• Slits are
prepared
for the
nextprocess.
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Part 1: CT Basics: Fabrication of Coiled Tubing
Bias welds:
- Distribute the
weight- Distribute the
Fatigue
- Can only be madebefore the metalis rolled to a tube.
End of Strip A
Start of Strip B
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Part 1: CT Basics: Fabrication of Coiled Tubing
Factory Butt Weld(aka “Orbital Butt Weld”)
Factory Bias Weld
- All factory welds- Strongest
- Resist Fatigue
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Fabrication of Coiled Tubing
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• Making
a Bias
Weld
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Part 1: CT Basics: Strip welded at 45 deg
•Computer
assisted welding.
•Results
recorded.
•Approved weld
procedure
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Part 1: CT Basics: Fabrication of Coiled Tubing
Conventional Step- Tapered String Design
.109”
Wall
.118”
.125”.134
”
b f l d b
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• Continuous rolling can form a linear taper.
• This design will reduce metal fatigue.
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P 1 CT B i F b i i f C il d T bi
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• The spool
has become
larger after
many stripsare joined
together.
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P 1 CT B i F b i i f C il d T bi
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Part 1: CT Basics: Fabrication of Coiled Tubing
Coiled Tubing Milling Process
Accumulator
Tube
Forming
HFI
ERW
Seam
Anneal
Air
Cool
Water
Bath
Sizing
Rolls
Eddy Current
NDE
Air Cool
Water
Bath
Full Body
Stress Relief
Take-up
Spool
O.D & I.D.(FF)
Scarfing
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• Knife cuts off material that is extruded from the welding process
• Any impurities on edge of strip are pushed out of the weld
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• Spool
rotates at
mill speed
• Tubing laidproperly
on spool.
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Part 1: CT Basics: QTI Product Size Range
3.500 in
2.875 in
2.625 in.
2.375 in
2.000 in
1.750 in
1.500 in
1.250 in
1.000 in
0.750 in
0.625 in Wall Thickness: .087” to .203”
Hydrotest/ Drift
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Hydrotest/ Drift
• Test for 15 minto 80% Int.Yieldfor CT & CLP.
• Gauge Ball runto Drift ID
• Alternativepressures andtimes available
Laboratory Testing
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Laboratory Testing
• Each end of each string is testedfor physical properties.
• Inside sections taken from prior
data
• Full sections pulled• Microhardness in body,
in HAZ, & at seam.
Tensile Test OD Measurement
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Tensile Test - OD Measurement
• True OD on tensile
samples
measured
• Used to compute
metal cross-
sectional area
Microhardness Testing
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Microhardness Testing
• Knoop hardnesstesting conducted
axially in weld, HAZ
(heat affected zone)
and body.
• Convert to HRB/C
(Hardness Rockwell
B/C).
Tensile Testing
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Measures strength and elongation (ductility)
Tensile Testing
Flaring Tests
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Flaring Tests
• Flaring testsexpand
pipe wall
and weld.
• Meet API
5LCP
Flash Free Tubing
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Flash Free Tubing
INTERNAL WELD FLASH REMOVAL Internal weld bead is cut from tube
wall during milling, and then pumped-
out of finished, spooled tubing.
1.50” OD and larger
Non-tapered strings only.
ADVANTAGES
Clearance for internal running tools
(swab cups, plungers)
Transfer to Customer Reel
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Transfer to Customer Reel
• From stock toCoiled Tubing
Unit
Coiled Tubing Failures
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Coiled Tubing Failures
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• Did you Know?
– A CT String from the factory usually contains 6 or more sections (and 5or more welds).
– Purchasing a string requires 6 months for delivery, with a cost ofapprox. $100,000 USD.
– One String is good for about 30-40 Runs in the well. (Highly dependenton the company, the fluids being pumped, the application beingapplied).
– The old coils can be sold as scrap metal. However, they are more
commonly purchased by oil companies for use as velocity strings, andbough by locals who use the tubing for a variety of things such asfence-posts, furniture making, etc.
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Coiled Tubing Equipment
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• Reel (or Drum)
– Holds the CT
– Hydraulically powered,
for spooling purposes
only. – Does NOT pull/push CT
in/out of the well.
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Reel Plumbing
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g
Broken Reels !
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• Level-Wind (or,
Horses-Head)
– Helps guide the CT
onto the reel
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• Gooseneck (or, Guide-Arch)
– Sits on top of the Injector
– Guides and bends CT, as the
CT moves between the Reel,
and the Injector
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• Injector
– Grips the CT with metalblocks, which are attached tochains.
– Pulls and pushes the CT
in/out of the well. – Most units pull between
35,000 lb – 135,000 lb
– Push (snubbing) is usually ½
of pull capacity. – Hydraulically powered.
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• Injector Chains
– Move the coiledtubing
– Two sets of chains
– Are rotated by theinjector, to move
the coil in/out of
the well.
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• Injector Blocks
– Make contact
with the coil.
– Two shapes –
round or “V”
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• Linear Beam Cylinders
– Chains are squeezedtogether by hydrauliccylinders.
– These squeeze the coil until
there is enough friction toprevent slipping on theblocks.
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Weight Indicators
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Hydraulic weight indicator.
Used on 38K Injectors and smaller.
Weight Indicators (cont.)
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Electronic Load Pins
(two used)
Used on all injectors
60K and above.
Tubing Guide
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(95K)
Electronic Depth Head – Below Chains
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• Stripper
– The Key component to CT operations! – Located below the Injector
– It wraps and holds a sealing material around the CT string
– It allows CT to move in/out of the pressurized wellbore and,
prevents wellbore pressure from escaping.
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• Stripper
– Common design: A door opens to expose the rubber
sealing material inside. This allows it to be changed
during the job.
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Sidedoor Stripper Elastomer
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• Lubricator (or, Riser)
– Sections of large, hollow pipe,below the stripper.
– Connect to the BOPs.
– Function as a place to keep thetool-string before and after the job (since, the toolstring cannotpass up through the injector andaround the goose-neck).
– Thus, allows the tool-string to be
completely removed from thewell with the wellhead closed.
– Needs to be as long as the tool-string being used for the job.
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• Quad BOP’s
– Well control for emergencysituations. Function exactlythe same as on a Drilling rig.
– Typical configuration shown(top to bottom).
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Blind
Shear
Slip
Pipe / Tubing
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• Dual-Combi BOP’s
– Save space vs Quad BOPs
– Typical configuration
shown (top to bottom).
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Blind + Shear
Slip + Pipe
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• Control House
– Cabin for personnel to operate all CT controls
– Data storage, display, recording.
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• Provide Real-time Operator Information – Measured parameters - weight, speed, depth pressure
– Calculated parameters - stresses, collapse, tubing life
utilization
• Determine Tubing Status – Tubing life management
– Real time effects
• Provide Job Records
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• Power Pack
– Diesel engine supplies Hydraulic energy to operate
the BOPs, Injector, and Reel (connected through
hydraulic hoses).
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• Injector Stand / Lift Frame
– Usually includes hydraulicup/down movement to adjustthe injector height.
– Supports the Injector, when acrane is not available for theduration of the job.
– Most land jobs cannot use aninjector stand due to lack of
suitable foundation (the groundis too soft and un-even).
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• Offshore Lift Frame – Can be used inside a drilling rig
derrick – Can be heave-compensated for
floating applications.
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• High Pressure Fluid Pump
– Diesel engine, drives a Positive-DisplacementPump
– Capable of extremely high pressures (15k psi)
– Fluid rates up to 10 BPM is common.
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• N2 Converter
– Converts liquid N2 to gas form by applying heat. – Pumps gaseous N2 at specified pressure and rate
(up to 300,000 scf/hr and 15,000 psi is common)
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• N2 Tanks
– 2,000 gal liquid N2 is
common
– Cannot store long time –they are well insulated but
heat does get in, N2
vaporizes every Part.
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• Batch Mixer
Large mixing tanks(typically 50 - 100
BBL) with paddles
inside to mix
chemicals, fluids.
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• Acid Tank
– Safely transport rawHCl or other acids.
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• Fluid Holding Tanks – 100-200 BBL is
common
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• Generator
with Lights
• Sand Trap
– Prevent
returned sand
from entering
production
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• Treating Iron basket
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• Air Compressor
(used to start thediesel engines)
Also brought to location, but Not shown:
• Chemical Totes
• Downhole-tool basket
• Hoses basket
In Summary, CT Jobs Require a Lot of Equipment and Preparation
Part 1: CT Basics: BHA
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BHA (Bottom-Hole Assembly)
87Some images courtesy Gaggie Tool Corporation
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• BHA (Bottom Hole Assembly)
– The Coiled tubing is often just a means of conveyance,to carry tools into the well.
– The tool-string attached to the end of the coil is called
the BHA.
• Nearly all BHA’s have 1 thing in common: the MHA.
– The Motor-Head Assembly (MHA), is the first part of the
tool-string. It joins the coiled tubing with the tool-string.It also provides some basic safety functions.
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• Coil Connectora. Attaches to the coiled
tubing with rolls/dimples,
or grapples.
b. Provides a threaded
connection for the
remaining tools.
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• MHA
1. Double Flapper Check Valve
a. Allows pressure and fluid to flow out of the
coil, but not in.
b. This is a critical safety tool in the event that
CT develops a leak or break on surface. Inthat case, only the DFCV will be preventing
wellbore pressure escape.
c. Spring actuated flappers automatically close
when flow is stopped
d. Balls can be pumped through the flappers
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• MHA
2. Hydraulic Disconnecta. Sometimes the tools being run in thewell can get stuck. By offering ameans to remove the BHA, it can beleft behind while the CT string isrecovered to surface.
b. Can be activated by dropping a ball(which lands in the tool and shearssome connecting pins).
c. Lower body has internal fishing neck
d. Circulation above ball after
disconnecte. Pressure-balanced to preventaccidental release
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• MHA
3. Circulating Suba. If the tool being used gets blocked (and fluidcan no longer be circulated), it’s important toregain the ability to circulate.
b. This tool has openings on the side of the
tool, allowing fluid to be circulated throughit, instead of the BHA below.
c. Can be activated by dropping a ball
d. Gives a circulation path above motors orother tools
e. Saves excessive motor wearf. Higher circulation rates than available with
drilling motors
Rupture Disc Sub
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• MHA
4. Rupture Disc Suba. Provides a method of establishing
circulation in a bull - plugged
situation or in emergencies
b. Available in a wide range of burstpressures
c. Generally run as a component of
the BHA in CT drilling applications
Motorhead Assembly
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Double Flapper
Check Valve
Hydraulic
Disconnect
Ball DropCirculating
Valve
Rupture
Disc Sub
• Can be constructed using the
previously mentioned tools,
or
• Can be purchased as a single, morecompact assembly
• Below the MHA, more tools can be
added for increased functionality.
Part 1: CT Basics: String Characteristics & Selection
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String Characteristics & Selection
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• Length:
– Long enough to reach the deepest zone +contingency
– Weight issues if it’s too long?
• Diameter:1.00” - 1.250” - 1.500” - 1.750” - 2.000” – 2.375” –
2.875” – 3.500”
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Higher fluid rates
(better for cleanout)
Higher pull strength
1” Smallest 3.5” Largest
Smaller Coil Larger Coil
Higher fatigue life
(more runs)
Higher collapse resistance
(for high pressure wells)
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• Grade of steel – 70, 80, 90, 100, 110, 125 (newly developed)
– Higher numbers = harder, stronger.• Allows higher pull weights. OR same pull weights w/ smaller coil.
– Quality Tubing company – “QT-700, QT-800”..etc
– Number translates into tensional strength:• 80 grade steel has tensile strength of 80 k psi
• 90 grade steel has tensile strength of 90 k psi• etc
QT-800
80,000 lb to yield
1”
1 “
? lb to yield
Depends on:-Diameter
-Thickness
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Part 1: CT Basics: Safety Considerations & Failure Modes
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Axial failure,
too much tension.
Notice the necking.
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Collapse,
too much external pressure.
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Burst,
too much internalpressure.
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All of these can lead to damaged equipment, job failure, wellcontrol issues, and loss of lives with injury.
These incidents occur when:
- The job is not modeled properly.- The job recommendations / program are not taken
seriously (not followed).
- Job parameters change and modeling is not updated.
Job Modeling is the safety-net to prevent these failures.
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Job Modeling
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• Coiled tubing has many failure mechanisms and manyforces are at play. – Tension, compression, internal & external pressure, torque,
bending, helical & sinusoidal buckling, fatigue, ovality
• The forces interact with each other - synergy betweenthem.
• Only the computer can account for all forces andinterpret their effects.
(no tables or handbooks should be used )
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What is Fatigue?
• Cumulative structural damage to a material, from repeated cyclic loading.
• It’s an invisible phenomenon (lab cannot test a sample and conclude the
degree of material fatigue).
• Highly predictable (with the right model).
• It’s tracked only by computer.
– Accurate record keeping is imperative.
• Only occurs when the pipe is being bent, while moving in/out of the hole
(stationary pumping does not accumulate fatigue).
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How many bends does each location in the
coil make, while making one complete trip inand out of the well?
Ans: 6
1. (RIH) Unbending off the reel
2. (RIH) Bending onto the guide arch.
3. (RIH) Unbending off the guide arch.
4. (POOH) Bending onto the guide arch.
5. (POOH) Unbending off the guide arch.
6. (POOH) Bending onto the reel.
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• A Special Note on Fatigue:
• Fatigue is a complex calculation affected by: – CT Diameter
– CT Material
– CT Wall Thickness
– Pressure in the CT while it is being bent
– Radius of bending at the reel, guide arch
– Tension in the coil while bending
– Fluid contacting the coil while bending (H2S, Acid, CO2)
– Stress risers (cuts, step wall changes) – Previous fatigue history
112
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• Forces (and fatigue) are modeled real-time in the
Control Cab
114
Operators watch
fatigue progressand get instant
feedback on
fatigue tracking
0 2000 4000 6000 8000 10000 12000 14000
Length from Reel End (ft)
0
10
20
30
40
50
60
70
80
90
F a t i g u e ( % )
Calculated Fatigue Base Fatigue
Run (Default Run_1) - Fatigue
Project Name: CTU simulation classHALLIBURTON
INSITEforWell Intervention v4.1.0
18-May-10 21:34
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-20000 -10000 0 10000 20000 30000 40000
Surface Weight (lbf)
0
2500
5000
7500
10000
12500
D e p t h ( f t )
Lockup 1 Trip In 1
Trip Out 1 Yield 1
Run (Class Example) - Weight [Trip In/Out]
Project Name: CTU simulation classHALLIBURTON
INSITEfor Well Intervention v4.1.0
18-May-10 23:41
Lockup Yield
POOH WeightRIH Weight
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When RIH withcoil at 7500’
deep, what is
the expected
surface
weight?
Ans: ~ 5,000 lb-20000 -10000 0 10000 20000 30000 40000
Surface Weight (lbf)
0
2500
5000
7500
10000
12500
D e p t h ( f t )
Lockup 1 Trip In 1
Trip Out 1 Yield 1
Run (Class Example) - Weight [Trip In/Out]
Project Name: CTU simulation classHALLIBURTON
INSITEfor Well Intervention v4.1.0
18-May-10 23:41
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Notice, thetapered
section is
reflected in
the yieldlimit.
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Surface Weight (lbf)
0
2500
5000
7500
10000
12500
D e p t h ( f t )
Lockup 1 Trip In 1
Trip Out 1 Yield 1
Run (Class Example) - Weight [Trip In/Out]
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INSITEfor Well Intervention v4.1.0
18-May-10 23:41
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1000 lb set-down
on surface
0 lb set-down on
bottom
200 lb200 lb
200 lb
200 lb200 lb
Because there is no axial force
pushing the bottom tip of the string,
it stops. It cannot RIH further.
= LOCKUP
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122
What is lockup?
Lockup occurs when the coil
stiffness is no longer
sufficient to overcome
mechanical friction, and no
axial force is beingtransferred down hole.
It can only occur while RIH.
Think of a wet noodle.
-20000 -10000 0 10000 20000 30000 40000
Surface Weight (lbf)
0
2500
5000
7500
10000
12500
D e p t h ( f t )
Lockup 1 Trip In 1
Trip Out 1 Yield 1
Run (Class Example) - Weight [Trip In/Out]
Project Name: CTU simulation classHALLIBURTON
INSITEfor Well Intervention v4.1.0
18-May-10 23:41
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• When lockup is reached, pushing harder on surface will not
get the bottom tip of the coil any further in the hole.• Pushing more may sinusoidally or helically buckle the coil.
Sinusoidal Helical
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• Modeling also accounts for … – Stretch
– Weight on Bit
– Fluid Densities and Loss – Expected pumping pressures
– Fluid Velocities
124
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• The Coiled tubing string is fragile• Service companies will need to interrupt the
job and manage their string life.
– Fatigue – Corrosion
126
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- This coil is only 30% used.
- A single fatigue spike from
milling caused this fatigue
spike to 80%.
- The coil cannot be used
anymore.
- Welding – not a positive
option.
- This is why fatiguemanagement on the job is
critical.
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Length from Reel End (ft)
0
10
20
30
40
50
60
70
80
90
100
F a t i g u e ( % )
1
Fatigue, String Diagram - 100306/MAWC13/69POT21, Derated Zones
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• The welder must be flown in from abroad, as
there are only 4 or 5 people in the world who
meet the standards for welding CT.
• A Manual butt-weld requires approx 1month of planning, 2 Parts in the yard,and approx $20,000 USD to install.
• The manual butt-weld will only extendthe coil life by a maximum of 15%.
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• Part 2
129
Contents
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Part 1: Coiled Tubing Basics
• Why Coiled Tubing?
• Fabrication
• Coiled Tubing Equipment
• BHA
• String Characteristics & Selection
• Safety Considerations & Failure Modes
• Job Modeling• String Life Management
130
Contents
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Part 2: Coiled Tubing Applications
• Circulating, Cleanouts & N2
Lifting
• Milling, Fishing
• Logging & Perforating
• Fluid / Chemical Placement
• Down-hole Camera
• Gravel Packs & Sand Control• Hydra-Jet Technology
• Fracturing
• Moving & Setting
• Tractors
• E-Coil
• Fluid Pulsing Communication
• Acoustic Communication
• Coiled Tubing Drilling
• CT Boat Operations
• CT + HWO Combination
• Capillary Coil
131
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Circulating, Cleanouts & N2 Lifting
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• How can you solve these problems? You wantto:
– Inject cement directly into the 3rd set of perfs fromthe top of the well (but 10 sets of perfs are open
…) – Wash acid onto an obstruction in the well.
– Remove produced sand from the top of a bridgeplug, so that you may remove it.
• Will bull-heading cement, acid, or water,achieve these results?
133
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• Coiled Tubing’s specialty: to circulate fluiddown the coil, and up the annulus.
– Fluid can be water, gel, acid, N2, solvent, … (etc)
– Fluids are not usually reverse-circulated (downannulus & up CT) because of safety concerns.
• Cleanouts (removing sand, debris, etc), and
N2 Lifting, are the most common jobs forcoiled tubing.
134
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• Fluid Types: – Brine water (to protect open formation from
water/clay damage)
– Sea or Fresh water, (if clays are not present) – “Gel” (guar-based additive + water)
– Acid (to remove scale from the wellbore)
– Solvents (to remove waxes, parrafins, etc) – N2 gas (inert, easy to transport, inexpensive)
135
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• Wash Nozzles
– Most cleanouts and circulatingtreatments only require a simple
wash nozzle on the bottom of the
coiled tubing string.
136
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The idea of a cleanout is simple but requires detailed
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The idea of a cleanout is simple, but requires detailedpre-job engineering.
• Confirm the maximum fluid rate possible
(pressure dependent).
0 500 1000 1500 2000 2500 3000 3500 4000 4500
Pressure (psi)
-2500
0
2500
5000
7500
10000
12500
D e p t h ( f t )
Case (1.0 bpm, 1.50 inch coil, FR-48) - CTPressure Case (1.0 bpm, 1.50 inch coil, FR-48) - Annulus Pressure
Case (1.0 bpm, 1.25 inch coil, FR-48) - CTPressure Case (1.0 bpm, 1.25 inch coil, FR-48) - Annulus Pressure
All Cases - Pressures
Project Name: CTU simulation class
HALLIBURTONINSITEforWell Intervention v4.1.0
26-May-10 15:40
1.50” 1.25”
1.0 BPM
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Part 2: Applications: Circulating, Cleanouts & N2 Lifting
• What velocity is needed to carry solids?
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• Depends on the solids, the fluids, and wellbore deviation.
For a Vertical Well:
Fluid Velocity UP
Settling Velocity DOWN
(Particle Density,
Shape, &
Fluid Viscosity)
Resulting
Upward
Motion of
particle
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•
How can you get a better cleanout in avertical well?
• Answer:
– Increase fluid velocity (up)
– Decrease particle settling velocity (down)
• More viscous fluid
• Heavier fluid
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• How about in a Deviated well..• Does anything change?
141
Part 2: Applications: Circulating, Cleanouts & N2 Lifting
For a Deviated or Horizontal Well:
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• In well deviations > 30 degrees, fluid velocity is more important
than settling velocity.• Maintaining Turbulence is critical.
Just a few
inches
LAMINAR FLOW
Part 2: Applications: Circulating, Cleanouts & N2 Lifting
For a Deviated or Horizontal Well:
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• In well deviations > 30 degrees, fluid velocity is more important
than settling velocity.• Maintaining Turbulence is critical.
Just a few
inches
TURBULENT FLOW
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• If maintaining turbulence is critical in a deviated wellborecleanout, which fluid is best to remove solids from the well –
straight water, or viscous gel?
• Ans: Straight water will maintain turbulence (and cleanoutefficiency) in a deviated wellbore. Gel pills will remain in the
laminar regime, causing solids to settle, thus decreasing
cleaning efficiency.
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Wiper Trips through thedeviated section may be
necessary.
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• While removing sand/etc from the wellbore, any suspendedsolids act to increase the weight of the annular fluid.
• This changes the hydrostatic weight of the fluid in the
annulus, and must be accounted for to prevent losses to theformation.
– ECD = Equivalent Circulating Density, ppg
• ECD can be controlled by RIH slowly while cleaning solids with
coiled tubing.
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Sea Water
8.6 ppg
Reservoir
4,000 psi
Hydrostatic
@ perfs
3,500 psi
All cleanouts are under-balanced
(Otherwise the fluid + solids would gointo the formation!)
Confirmed by receiving returns at surface.
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Sea Water +
Too Much Sand
ECD = 11.0 ppg
Reservoir
4,000 psi
Hydrostatic @
perfs
4,500 psi
Over-Balanced Condition
No Returns at surface(No solids being removed)
Surface pressure < Header Pressure
Chance of getting coil stuck
“N2 Lifting” – Removing fluid from the wellbore
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N2 Lifting Removing fluid from the wellbore
149
• Only need to remove enough fluid to get under-balance.• Calculate the height of fluid you need to remove + 20%
• If N2 is jetted below open perfs, it may go into formation. – That’s why N2 lifts require coil is above the top perf.
N2 Cleanouts – Mixing N2 + Fluid to clean debris
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N2 Cleanouts Mixing N2 + Fluid to clean debris
150
• N2 can be used to lighten the fluid (reduce hydrostatic)• Best cleanouts are using “foam” = 60-95% quality
0 10 20 30 40 50 60 70 80 90
N2 Quality (%)
-2500
0
2500
5000
7500
10000
12500
D e p t h ( f t )
CT N2 Quality Annulus N2 Quality
Case (Default Case_1) - N2 Qualities
Project Name: CTU simulation classHALLIBURTON
INSITEforWell Intervention v4.1.0
26-May-10 21:24
•400 psi WHP
•400 scfm N2
•0.40 bpm sea water
85 Q on surface
60 Q at bottom
This is an acceptable foam.
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• Let the model calculate the optimum cleanout
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• Let the model calculate the optimum cleanout
or N2 lift.• It will balance the competing forces of:
– Particle size, density
– Fluid viscosity
– Formation pressure
– Hydraulic Friction
– Pump rates
– RIH/POOH speeds
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• Milling and Fishing are also amongst the mostcommon and useful applications of Coiled
Tubing.
• Extremely wide variety of tools and functions
is available in the market. Only some of the
basics will be covered here.
153
Part 2: Applications: Milling & Fishing
• Rotation is performed with a down-hole, Positive
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154
Displacement Motor - similar to those used in Drilling.
POWER
SECTION
FLEX
SHAFT
BEARING
SECTION
DRIVE SECTION
BIT
SUBROTOR / STATOR
Fluid rates through Coiled tubing can commonly provide 1-3BPM (depending on the size of the CT), to power the down-
hole motor.
• Common reasons to use CT milling:
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Common reasons to use CT milling:
– Remove hardened scale and other deposits on thetubulars.
– Drill out plugs and debris from the well.
– Reaming collapsed or deformed tubing.
• PDM’s can also be used for: – Rotating fishing tools (spears, grabs, fishing necks,
etc)
– Jet nozzles (for cleanout, cutting, etc) – Cutting casing and tubing
155
• Various styles of bits are available for each
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• Various styles of bits are available for each
application.
156
WATERMELON TAPERED
FLAT
BOTTOM
MILLBLADED JUNKPDC
MILL
Concerns during the job:
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g j
• The greatest concern while milling or fishing with coiledtubing is fatigue management . – Milling & fishing both usually require many small movements
of the coil, at the target depth. (Recovering from a stalledmotor, catching the fish, adjusting the milling rate, etc).
– Each pick-up and set-down on bit will create fatigue in the CTsection at the gooseneck.
– Excessive CT movements at the same depth, will build acumulative fatigue spike in the CT section at surface.
– Fatigue spikes will cause the CT string to reach the end of itslife, and interrupt the job, usually with costly delays.
157
Part 2: Applications: Milling & Fishing
70
80
u e ( % )
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• Torque: – Under high torque loads, PDM’s will usually stall
before the torque limit of the CT string is reached (and
therefore, watching torque is not often a concern). – Instead, preventing a stall is important to prolong the
life of the PDM.
158
0 2000 4000 6000 8000 10000 12000
Length from Reel End (ft)
0
10
20
30
40
50
60 F a t i g u
1
Brief overview of tools used in fishing & milling:
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g g
JAR
159
WEIGHT
BAR
BI-DI INTENSIFIERBI-DI JAR
- The JAR provides instant
release of stored energy
to the Fish
- The Weight Bar addsmass
- The Intensifier protects
the CT string from this
energy, and also,
concentrates the energy
onto the fish.
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Impact Hammer
160
-Flow activated impact hammer
-Up to 800 impacts / minute
-Selection of impact bits available.
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Overshot
161
-Holds onto a fish with grapples, or a
fishing neck profile.
-Releases by pumping, cutting, or dis-
assembly (at surface).-Some designs can pump into the fish.
S-150
S-10 & S-
20KELO
SOCKET
GUIDE HOOK
WALLPACK-
OFF
Part 2: Applications: Milling & Fishing
WIRE
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Spears
162
CRANK
SPEAR
WIRE
SPEAR
2 OR 3
PRONG
SPEAR
WIRE
PUSHER
-Grab onto cable
and wire.
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Part 2: Applications: Logging & Perforating
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Logging & Perforating
164Some images courtesy Halliburton & SLB
• Wide variety of PL (production logging) tools
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• Wide variety of PL (production logging) tools
available – similar to Eline/Wireline selection
165
• Video– V02 – Cobra PerforatingPart 2: Applications: Logging & Perforating
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166
• Logging and Perforating with CT because:
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Logging and Perforating with CT because:
– CT can reach into deviated and horizontal sections
of the well better than Eline/Wireline
– Ability to perform CT jobs on the same well
without rigging up/down between CT and Eline
167
• Array logging tools
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Array logging tools
– Useful in deviations &horizontal
– True fluid profile
168
Part 2: Applications: Fluid / Chemical Placement
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Fluid / Chemical Placement
169
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• Benefits of Targeted Placement: – Precise placement, only where needed.
– Avoid contamination of expensive treatmentfluids.
– Reduce exposure of completion tubulars tochemicals and pressures.
– Smaller treatment volumes.
• How to do it?
171
• Video – V03 – Straddle Packer Injection
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172
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• Perf Balls
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– Ball OD should be ¼” larger than perf OD
– Bio-degradable balls available
– Temperature dependent
174
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• Foam Diverter
– 65% -80% Foam quality• Vgas / ( Vgas + V liq)
– Foam will Increase the apparent viscosity, providediversion of fluid to next section
– Increasing gas saturation, can provide resistance
to liquid in terms of relative permeability
175
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Part 2: Applications: Fluid / Chemical Placement
Pulsonix, Continued..
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– Fluid bursts generatepulsating pressure waveswithin the wellbore andformation fluids, thus aidingin placement of treatment
fluids through acousticstreaming.
– Pressure waves can breakup many types of near-wellbore damage through
cyclic loading. – Pressure waves push the
fluid deeper into formation.
177
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Down-hole Camera
178Some images courtesy TecWell
• Downhole cameras
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– Can be run on‘communicating coil’
– Generates down and side-views
– Often, not very clear,unless in dry gas or clearfluid wells.
– In the right circumstance,
better than LIB (orguessing!)
179
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Part 2: Applications: Gravel Packs & Sand Control
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Gravel Packs & Sand Control
181Some images courtesy Halliburton
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Part 2: Applications: Gravel Packs & Sand Control
• These are the screens.
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183
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185
Part 2: Applications: Hydra-Jet Technology
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Hydra-Jet Technology
186Some images courtesy Schlumberger & Halliburton
• Hydra-Jet Technology:
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y gy
– Strong jets of fluid, mixed with abrasive (sand),
pumped against the tubulars.
– Creates holes in the tubulars, in about 5 minutes,with 1,500-4,000 psi differential pressure.
– Jet size ~ ¼”
– Perforation size ~ 1”
– Perforation depth 3”-10” is common.
187
Part 2: Applications: Hydra-Jet TechnologyHydra-Jet Perforating
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Part 2: Applications: Hydra-Jet Technology
Schematic of Jet Stream in a Hydra-jetted Perforation Tunnel
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Jet Stream Divergence and Full Returns
10
Part 2: Applications: Hydra-Jet Technology
Hydra-Jetting Perforations
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• Eroded Perf Tunnels
• Reduced Near-Wellbore
Fracture Entry Issues
• High Concentration ofProppant at the
Perforations
• Slots can be created
• NWB Damage and Rock
Stress Greatly Reduced.
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• Hydra-Jet Technology, for cutting Casing
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• Jetting Tool + Rotating tool + 100-mesh sand = cuts Casing.
• Slices control lines/varying thicknesses/etc more effectively than
explosive & chemical cuts
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Fracturing
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• Fracturing treatments are generally bullheaded down the well.
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• Why use coiled tubing for fracturing?
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– Faster than a traditional bullhead frac.
– Save time and money.
– Isolate the zone, Perforate, Fracture, and Cleanup… all in a single run.
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• Video – V06 - Hydra-jetting with coil• Video – V07 – Hydra-jetting, sand plugs,
cleanout.
• Video – V08 – Hydra-jetting, sand plugs, cleanout.
• Video – V09 - TIME SAVED with CT frac
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Further benefits of using CT for fracturing..
http://c/Users/ntkhoa/Documents/Videos/V06%20-%20SurgiFrac_C.mpghttp://c/Users/ntkhoa/Documents/Videos/V07%20-%20CobraMax.mpghttp://c/Users/ntkhoa/Documents/Videos/V07%20-%20CobraMax.mpghttp://c/Users/ntkhoa/Documents/Videos/V07%20-%20CobraMax.mpghttp://c/Users/ntkhoa/Documents/Videos/V08%20-%20CobraMaxAP_03.exehttp://c/Users/ntkhoa/Documents/Videos/V08%20-%20CobraMaxAP_03.exehttp://c/Users/ntkhoa/Documents/Videos/V08%20-%20CobraMaxAP_03.exehttp://c/Users/ntkhoa/Documents/Videos/V09%20-%20CobraFracFS.exehttp://c/Users/ntkhoa/Documents/Videos/V09%20-%20CobraFracFS.exehttp://c/Users/ntkhoa/Documents/Videos/V08%20-%20CobraMaxAP_03.exehttp://c/Users/ntkhoa/Documents/Videos/V07%20-%20CobraMax.mpghttp://c/Users/ntkhoa/Documents/Videos/V06%20-%20SurgiFrac_C.mpg
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– Better control over the frac job. – Place many small zones.
• Operators used to have to try andcover many small zones with 1 frac.
• Now, they can target each oneindividually.
– Horizontal & Vertical wells.
– No Isolation Needed• Un-cemented wells = ok
– Perforating is low cost.
– Better quality perforations.
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Side
View
Hydraulic Fracture
D
Lf
KOP
Pzy
HM
AXHM
AX
HMI
N
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Moving & Setting
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• Because CT can usually reach to
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Because CT can usually reach to
all parts of the well, (andpush/pull once it gets there), it’s
also used to:
– Shift sliding sleeves (open/closezones). Hydraulic or manual
operation.
– Set plugs, junk catchers, sensors,
and tools in the well.
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• Video – V10 – Stim-sleeve movement
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http://c/Users/ntkhoa/Documents/Videos/V10%20-%20DeltaStimSleeve.exehttp://c/Users/ntkhoa/Documents/Videos/V10%20-%20DeltaStimSleeve.exe
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• A “Tractor” is an electrical or fluid powered tool,
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which can be put on the end of Coiled Tubing,and helps Pull or Push the end of the coil.
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• Sometimes CT doesn’t have the stiffness to
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Sometimes CT doesn t have the stiffness to
reach the furthest parts of a well.
• Tractor can assist, generally pulling ~ 2-10,000
lb (varies widely with configuration and size)
• Also helps CT move sliding sleeves and
operate other down-hole hardware.
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• An alternative design: – Video – V11 – crawler action
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http://c/Users/ntkhoa/Documents/Videos/V11%20-%20Crawler_Action.wmvhttp://c/Users/ntkhoa/Documents/Videos/V11%20-%20Crawler_Action.wmv
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E-Coil
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• One method to communicate with the bottom
of the CT string: E-coil
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of the CT string: E coil
• An electrical cable is injected into the CT string
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• E-line Cable InjectorReturned Fluid
to Storage Tank
Wireline Pressure
Control Head
“Stuffing Box”
PumpedFluid
Wireline
Spool
Cable
Injector
Coiled Tubing
Reel
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•
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• Slack management needs to be watched
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CTD (Coiled Tubing Drilling)
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Some images courtesy X-Treme Coil Drilling,
NOV, Schlumberger, and Baker Hughes
• Coiled Tubing Drilling and Finishing
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– CT cannot rotate, but a wide range of motors and mills exist formilling and drilling
– Underbalanced: CT’s built-in pressure control system, reducesformation damage (no losses to formation).
– Faster trip times, shorter rig-up time, than drilling rig
– Common application of CTD
• Re-Entry drilling• Wellbore extensions
• Sidetracks
• Economically access new/bypassed payzones
• Slim-hole exploration wells213
– Underbalanced “finishing” also gaining acceptance
• Well is drilled using conventional methods, and casing is run.Th CT i d t d ill ( d b l d) th h th i
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Then CT is used to drill (underbalanced) through the reservoirsection.
• CT is better suited to deal with the formation pressure andproduced hydrocarbons.
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CT Boat Operations
218Some images courtesy Schlumberger, Halliburton
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• CT Boat Operations
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– When the platform is too small – Or the crane capacity too light (20 MT crane =
minimum)
• Faster operations for many platforms
– No rig up/down on each platform
• Injector and Reel usually on the platform
– Pumps, power pack, fluids, etc, on the boat
• “Catenary Operations” = reel is on the boat
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• Catenary Operations
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– Reel Control house
– Main-Gooseneck
– Deck-Gooseneck
– Video Monitoring
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• Catenary Operations
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• Emergency CT Disconnect System
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CT and HWO (Jointed Pipe)
Combination
224Some images courtesy Halliburton
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Micro-Coil / Capillary Coil
225Some images courtesy BJ Services
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Micro-Coil (Capillary Coil)
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• Miniature CT unit – similar to wireline• 5/8” CT is common
• When size & weight are a priority, this unitcan save money vs full-sized CT
• Useful for low-rate fluid injection, orspotting small amounts of fluid – Scale inhibitors
– Foaming agents
– Parrafin solvents
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•
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Pro
• Lightweight
Con
• Very low pumping rates (2-4
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• Small and easy to transport
• Fast rigup / rigdown
gpm)• Low pickup / setdown
capability
• Low torq resistance (cannotuse a rotating motor)
• Easy to get stuck (in waxes,sludge, etc) and very littleover-pull available to getfree.
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• Conclusions
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– CT can be scaled up & down, but it remains an
extremely versatile Well Intervention technology
• Work under pressure• High tech, low-tech, large and small
• Overlaps abilities of HWO, Eline, Wireline, Drilling Rig
– Many new technologies are being developed to
further increase the functionality of CT
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Thank you for your time !
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Future questions, comments, and more information:
Nguyen Tan Khoa , Lead Well Operations Engineer