Swell T
echn
ology
Swell TechnologySwell Technology is based on the swelling properties of
elastomers. The swelling process creates effective seals in
both open and cased hole applications.
Halliburton currently has three types of swelling elastomer
systems. The first system uses elastomers that swell when
exposed to hydrocarbon. This happens through a process
known as diffusion and occurs as hydrocarbon molecules are
absorbed by the rubber molecules, causing them to stretch.
The packer swells as the hydrocarbon enters the rubber and
is trapped in the crosslinked rubber matrix due to the natural
affinity of polymer molecules and hydrocarbon. This process
is not reversible. Mere trace amounts of hydrocarbons are
sufficient to initiate the absorption process.
The second system uses elastomers that swell upon
exposure to water. The swelling process for this system is
based on the principle of osmosis. Water will enter the
rubber matrix and swell the rubber element. Since osmosis
is dependent on the salinity levels of the elastomer and the
surrounding fluids, changes in the downhole conditions
can reverse the swelling process.
The third system features a hybrid swelling polymer, which
combines the capabilities of both oil swelling and water
swelling polymers into a single compound. The fluids enter
the rubber element via the same mechanisms as described
above and has the ability to swell whether the well contains
an oil-based or water-based fluid system.
Swell Technology products are made by bonding the
elastomer systems onto oilfield tubulars, and metal end rings
are installed on each end of the rubber element. The end
rings assist in increasing the differential pressure capability
and guide the packer when being run into the hole. Packers
can be tailor made for specialized applications, the element
can be mounted on any size of basepipe, and the element OD
and length can be adapted to suit the required purpose. The
Swell Technology system portfolio also includes a range of
slip-on pipe tools.
These products have no moving parts and require no
inflation to seal, removing the inherent risks of mechanical
and inflatable tools. Customers simply make up or slip on
Swell Technology products to their pipes where isolation
points are needed to optimize the well.
HA
L22
167
Swell Technology 4-1
Features and Benefits• Sealing
– Swelling of the elastomer is not instantaneous. It is
caused by the diffusion/absorption of liquid
hydrocarbon or water, or both, into the elastomer. The
time taken to achieve a complete pressure seal is
dependent upon oil viscosity, element thickness, and
temperature and salinity. The swelling time is
engineered to ensure that the system can successfully be
run to depth. The addition of slow swelling rubber
layers and/or diffusion barriers can delay the onset of
the swelling process as per individual well requirements.
This enables running with tight clearances even in
situations where the packer is exposed to swelling fluids
while being run into the hole.
– The hardness of the set element is low, ensuring
effective sealing in irregular wellbore shapes such as
poor hole geometry and corroded casing.
– Set in permeable formation, a long packer element (5 to
9 m) seals more efficiently as it reduces bypass through
the formation.
– The self-healing element will re-heal if damaged while
running in hole or due to formation changes during
production. If hole conditions are rough and the packer
gets a cut, packer functionality is still maintained due to
the expansion capability. If the seal should lose its effect
due to formation erosion around the packer element or
thermal shrinkage of the element, the Swellpacker®
systems will restart swelling to seal off any leak path.
• Rig Time
– An alternative to cementing, perforating, and cleanout
operations when running pre-perforated assemblies or
sand screens.
– No setting or manipulation operations are necessary.
• Openhole
– Swell Technology systems can transition from cased
hole to openhole operations, reducing cost and
formation damage.
– The system enables sand control with zonal isolation
plus the isolation of shales.
• Robustness
– The chemical bonding of the rubber to the basepipe is
stronger than the element itself, so it cannot be torn
from the basepipe under normal conditions.
– The packers retain the strengths of the basepipe and can
be rotated and jarred to bottom.
– The packer is damage-tolerant. If hole conditions are
rough and the packer gets a cut, packer functionality is
still maintained due to its expansion capability.
– Swellpacker® isolation systems can be delivered with any
element length depending on the basepipe length.
– End rings located on either end of the swelling
elastomer are an important component that assist in
increasing the differential pressure capability and guide
and protect the packer when run into the hole.
Depending on the application and metallurgy
requirements, the end ring design can be anchored to
the basepipe using set screws, a crimping process,
or welding.
– Temperature ratings up to 390°F (200°C).
• Risk Profile
– No mechanical interaction of downhole tools.
– No risk of damaging element by inflation.
– High reliability of equipment.
– Helps reduce rig time.
– No need for specialized personnel to run on rig.
4-2 Swell Technology
Swellpacker® Isolation System
The Swellpacker® isolation system is based on the swelling
properties of rubber in hydrocarbons or water, or in both.
It swells up to 200%, sealing the annulus around the pipe to
achieve effective zonal isolation. Once deployed, the rubber
retains its flexibility, allowing the Swellpacker isolation
system to adapt to shifts in the formation over time,
retaining the integrity of the seal. Its self-healing properties
make this a truly innovative technology for all zonal
isolation applications. It is a bonded-to-pipe product that
can be delivered with any element length depending on the
basepipe length. Since the rubber is bonded to the
basepipe, it is extremely robust and can hold significant
differential pressures.
The Swellpacker system can be used in cased or openhole
environments. In some openhole applications, operators
may be able to avoid cementing and perforating altogether,
reducing the expense associated with these operations. By
reducing well construction costs, saving rig time, and
isolating producing zones, the Swellpacker system helps
enable previously unachievable levels of oilfield
performance.
Cementing Support
For well integrity issues, the Swellpacker isolation system
can also be used to complement the primary cement job.
The system provides comprehensive long-term zonal
isolation, increasing the productive life of the well and
minimizing the potential for an expensive workover
operation. This combination of proven technologies
provides an effective means to address both micro-annulus
concerns and incomplete cement sheath issues.
Swelling Delay Systems
To ensure that the oil or water contained within the well
fluid does not affect the packer while it is run into the hole,
Halliburton has engineered several systems that can delay
the swelling process. These systems enable control of the
elastomer swelling process as the setting time can be
tailored according to the customer’s needs, mitigating the
risk of premature setting while optimizing the operating
envelope. The swelling delay systems include polymers
with built-in slower swelling properties and a variety of
applied diffusion barriers. Customizing a design with
either of these options, or using in combination, allows for
creation of a well-specific engineered product.
End Ring Design
End rings assist in increasing the differential pressure
capability and guide the packer when run into the hole.
Depending on the application and metallurgy
requirements, the design can be anchored using set screws,
a crimping process, or welding.
The Halliburton K2 end ring protects the rubber element
while running in hole and further eliminates element
extrusion once the packer is set. One of the benefits of this
unique end ring is the ability to shorten tool length, while
maintaining differential pressure. It also increases absolute
differential pressure performance of the tools with testing
performed to 15,000 psi across the packer.
HA
L32
568
Swellpacker®
Isolation System
HA
L32
569
K2
End Ring
Swell Technology 4-3
Swellpacker® Cable System
The Swellpacker® system can be delivered with a unique
cable feed-through option that enables the passage of single
or multiple control lines and flatpacks for downhole
monitoring, chemical injection, and SmartWell®
completions without the need to cut the cables or lines. This
removes the requirement for cable splices, control line cuts,
and cable stripping, greatly reducing the risk of failure. It
provides an annular seal in cased and open hole, and a seal
around the control lines or flatpacks capable of holding
differential pressure. Installation of the cables through the
Swellpacker system is performed on the rig floor at the time
of running the completion and requires no extra rig time.
InstallationTo install the systems, simply perform standard pre-job
checks, then run in hole as part of the reservoir completion
string or liner system. At that point, either produce the well
to begin the swelling process, allow the current well fluid to
swell the packer systems prior to operations, or circulate
down the designed swelling fluid. The simplicity of the
operation means that specialized installation personnel are
not required.
For the cable design, Halliburton provides the installation
tool that fits easily on the rotary cable and installs the
control cable or flatpack through the packer.
Applications• Open and cased hole isolations
• Stimulation placement
• Open and cased hole straddles
• SmartWell completion systems
• Monitoring and chemical injection
• Water control
• Multilaterals
• Stand-alone screen sand control
• Compartmentalization for screen/ICD completions
• Gravel pack isolation
• Well construction
Features• Manufactured on any oilfield tubular
• Suitable for cased and open holes
• Robust construction
• No moving parts
• Spliceless cable feed-through option
• Self-healing, interventionless technology
• Can be run in most all fluid environments
• Multiple polymers available to provide oil swelling, water
swelling, and hybrid swelling solutions
• Engineered swelling delay system
Benefits• No specialist operator required for installation
• Casing integrity is maintained
• Perfect seal for irregular borehole geometry
• Alternative solution to cementing and perforating in
certain applications
• Complements cement to resolve well integrity issues
• Helps reduce operational risk
• Isolates producing zones more effectively
• Helps reduce well costs and rig time
• Cable feature increases system reliability by eliminating
cable splicing and enables openhole SmartWell
completions
HA
L32
625
Swellpacker®
Cable System
4-4 Swell Technology
Bonded-to-Pipe Tools
OperatingCondition Oil Swelling (OS) Water Swelling (WS) Hybrid Swelling (HS) Comments
Run in Hole Fluid:Oil-Based Mud
Design to suitapplications All fluid systems Design to suit applications Contact Halliburton for
engineered delay system
Run in Hole Fluid:Water-Based Mud All fluid systems Design to suit applications Design to suit applications Contact Halliburton for
engineered delay system
Temperature Range 30 - 390°F (0 - 200°C) 30 - 390°F (0 - 200°C) OS: 30 - 390°F (0 - 200°C)WS: 265 - 390°F (130 - 200°C) —
Reservoir Fluid:Liquid Hydrocarbon
Wide range of crude oil tested; swelling rate is a function of
fluid viscosity
Does not swell in hydrocarbons
Wide range of crude oil tested. Swelling rate is a function of
fluid viscosity
Contact Halliburton fordesign and simulations
Reservoir Fluid:Oil with High
Water Cut
Swells in traces ofhydrocarbon fluid
All fluid systems; swelling depends on temperature
and salinity
Swells in traces of hydrocarbon fluid; water
swelling depends on temperature and salinity
Contact Halliburton for design and simulations
Reservoir Fluid:Water Does not swell Wide range of fresh and saline
water testedWide range of fresh and saline
water testedSalinity and temperature
affect swell time
Reservoir Fluid:Gas Condensate
Swells in traces ofhydrocarbon fluid
Requires contact with water-based fluid for permanent seal
Swells in traces ofhydrocarbon fluid
Contact Halliburton for design and simulations
DifferentialPressure Capability
Up to 15,000 psi(1032 bar)
Up to 10,000 psi(690 bar)
Up to 10,000 psi(690 bar)
Contact Halliburton forapplication-specific pressure ratings
Time to Set Varies based on designs and well conditionsCan be engineered for swelling delays of 1-20 days
Contact Halliburton forapplication-specific simulations
Chemical Resistance Common oilfield chemicals Contact Halliburton forapplication-specific questions
Element Length Application and basepipe dependent Contact Halliburton forlength requirement
BasepipeTensile/Burst/
Collapse/MetallurgyCustomer supplied or Halliburton purchased to match specifications Can be built on any oilfield tubulars
Swell Technology 4-5
Swellpacker® Slip-On Isolation System
The Swellpacker® slip-on isolation
system is another option for effective
zonal isolation. This unique slip-on
packer retains a full length internal
seal against the pipe. Once deployed,
the rubber retains its flexibility,
allowing the Swellpacker system to
adapt to formation shifts over time to
maintain seal integrity. Its self-healing
properties make it a truly innovative
technology for all zonal
isolation applications.
The Swellpacker slip-on isolation
system does not require basepipe
to be supplied up front in the
manufacturing process and is installed
at the service location or rig site by
sliding over the pin end of the casing
or tubing joint. This allows storing
and stocking of the tools, simplifying
logistics, and reducing cost
significantly.
The system can be used in cased or
openhole environments. In some
openhole applications, operators may
be able to avoid cementing and
perforating altogether, reducing the
expense associated with these
operations.
Cementing Support
For well integrity issues, the
Swellpacker slip-on system can also be
used to complement the primary
cement job. The system provides
comprehensive long-term zonal
isolation, increasing the productive
life of the well and minimizing
potential for an expensive workover
operation. This combination of
proven technologies provides an
effective means to address both micro-
annulus concerns and incomplete
cement sheath issues.
Slip-On Convenience
Traditionally, swellable packers
achieved high differential pressure
ratings based on the area in contact
with the casing wall or borehole.
Element length is a key parameter for
the contact area. The resulting
differential pressure, and therefore the
shorter slip-on designs, traditionally
had lower pressure holding
capabilities.
Halliburton has developed shorter
slip-on tools that can handle the
higher differential ratings previously
only achievable through a longer
bonded-to-pipe product. One of those
designs, the Swellpacker HPE (high
performance element) slip-on
isolation system incorporates the K2
end ring to protect the rubber element
while running in hole and support the
rubber during and after the swelling
process. In addition, the next
generation of the Lite family, the
Swellpacker Lite II slip-on isolation
system, has been redesigned to create
a step change in slip-on tool capability.
Swelling Delay Systems
To ensure the oil or water contained
within the well fluid does not affect the
packer while it is run into the hole,
Halliburton has engineered several
systems that delay the swelling process.
These enable control of the elastomer
swelling process as the setting time
can be tailored according to the
customer’s needs, mitigating
premature setting risk while
optimizing the operating envelope.
The systems include polymers with
built-in slower swelling properties and
a variety of applied diffusion barriers.
Customizing a design with either of
these options, or using them in
combination, allows for creation of a
well-specific engineered product.
ApplicationsSwellpacker slip-on isolation systems
can be key components in gravel packs
for isolation and stand-alone screen
completions to reduce fines migration.
In reservoirs prone to sand
production, the slip-on tool helps
enable increased productivity and
reduced well construction costs since
it can be installed without specialized
operating personnel. In completions
using inflow control devices, slip-on
tools are used to create shorter
compartments for improved reservoir
management.
Swellpacker® Slip-On
Isolation System
HAL32578
4-6 Swell Technology
For many reservoirs using inflow control technology, the
Constrictor® slip-on isolation system can be an ideal device
due to its simple design and reliable performance.
One of the main applications for slip-on systems is with
hydraulic stimulation operations. Halliburton horizontal
completions provide operators with new options for
completing horizontal multi-zone wellbores and enable
highly accurate fracture placement with little to no
intervention. The service allows operators to selectively
access, isolate, and stimulate multiple payzones in a single
wellbore with the option to close off one or more zones at a
future date. This makes multi-zone stimulation possible in a
shorter time interval, leading to reduced overall well
completion costs.
InstallationSlide the slip-on system onto the basepipe, securing in place
with Halliburton end rings. Run in hole with assembly. The
tool simplicity means installation does not require specialist
attention and can be fitted by personnel at the rig site.
Features• Suitable for cased and open holes
• Install on any non-upset basepipe
• Robust construction
• No moving parts
• Self-healing, interventionless technology
• Can be run in most all fluid environments
• Multiple polymers available to provide oil swelling, water
swelling, and hybrid swelling solutions
• Engineered swelling delay system
Benefits• No specialist operator required for installation
• Casing integrity is maintained
• Simplified logistics
• Permits last minute adjustments to placement
• Perfect seal for irregular borehole geometry
• Protect sand screens from plugging
• Alternative solution to cementing and perforating
• Helps reduce operational risk
• Isolates producing zones more effectively
• Helps reduce well costs and rig time
HAL32576
Constrictor® Slip-On
Isolation System
Slip-On ToolsOperating Condition Oil Swelling (OS) Water Swelling (WS) Hybrid Swelling (HS) Comments
Run in Hole Fluid:Oil-Based Mud Design to suit applications Does not swell in
hydrocarbons Design to suit applications Contact Halliburton for engineered delay system
Run in Hole Fluid:Water-Based Mud All fluid systems Design to suit applications Design to suit applications Contact Halliburton for
engineered delay system
Temperature Range 30 - 390°F (0 - 200°C) 30 - 390°F (0 - 200°C) OS: 30 - 390°F (0 - 200°C)WS: 265 - 390°F (130 - 200°C) —
Reservoir Fluid:Liquid Hydrocarbon
Wide range of crude oil tested; swelling rate is a function of
fluid viscosity
Does not swell in hydrocarbons
Wide range of crude oil tested; swelling rate is a function of
fluid viscosity
Contact Halliburton for design and simulations
Reservoir Fluid:Oil with High
Water Cut
Swells in traces of hydrocarbon fluid
All fluid systems; swelling depends on
temperature and salinity
Swells in traces of hydrocarbon fluid; water
swelling depends on temperature and salinity
Contact Halliburton for design and simulations
Reservoir Fluid:Water Does not swell Wide range of fresh and
saline water testedWide range of fresh and
saline water testedSalinity and temperature
affect swell timeReservoir Fluid:Gas Condensate
Swells in traces of hydrocarbon fluid
Requires contact with water-based fluid for permanent seal
Swells in traces of hydrocarbon fluid
Contact Halliburton for design and simulations
Differential Pressure Capability
Up to 5,000 psi(345 bar)
Up to 1,000 psi(70 bar)
Up to 5,000 psi(345 bar)
Contact Halliburton forapplication-specific pressure ratings
Time to Set Varies based on designs and well conditionsCan be engineered for swelling delays of 1-20 days.
Contact Halliburton for application-specific simulations
Chemical Resistance Common oilfield chemicals Contact Halliburton for application-specific questions
Element Length Standard lengths are 0.3 m, 0.5 m, and 1 m Custom lengths available on request
Swell Technology 4-7
SwellSim® Software
The Swellpacker® simulator, SwellSim® software program, is
used for selecting the most suitable design to meet specific
customer requirements.
Extensive testing on the expansion properties of
Swell Technology systems has led to the development of the
SwellSim software which can help predict the expansion
ratio, differential pressure capability, time to first seal, and
time to operational seal for a given basepipe OD, rubber
element OD, and rubber element length in a given hole
size.
SwellSim software helps enable Halliburton to provide an
engineered recommendation to our customers that delivers
a custom-designed and reliable solution. For our
customers, this helps allow the utmost confidence that the
selected product will meet their expectations.
Based on actual test data, SwellSim software provides the
user with the ability to look at a variety of designs (bonded
to pipe, slip-on, cable bypass, etc.) and polymer types (oil,
water, and hybrid swelling) in the proposed well
environment. Inputting the well fluid characteristics and
temperature allows the user to design and optimize the
delay mechanism if necessary and tailor designs for
special applications.
Benefits• Engineered recommendations
• Helps predict time to first seal
• Helps predict time to operational differential pressure
• Helps predict time to maximum differential pressure
• Helps allow for hole size variation
• Helps predict delay recommendation
• Helps identify potential failure modes
• Helps reduce downhole risks
• Helps reduce rig time
SwellSim Software Legend
• Expansion ratio – volume increase of packer element due
to absorption of hydrocarbon
• Time to first seal – when packer OD engages hole ID
• Time to operational differential pressure – when packer
reaches customer-specified differential pressure
• Time to maximum differential pressure – when packer
reaches maximum differential pressure capability
4-8 Swell Technology
SwellSim® Software Output
A differential pressure profile curve and a swell profile (time to seal and time to fully set vs. hole size) curve are automatically
generated by the simulator. See the examples below for curves extracted from the simulator.
DIFFERENTIALPRESSURE PROFILE
0
100
200
300
400
500
600
700
800
8.60 8.80 9.00 9.20 9.40 9.60 9.80 10.00 10.20 10.40
Hol e ID ( in)
Differen
tial
Pressure
(bar)
0
1450
2900
4350
5800
7250
8700
10150
11600
Differen
tial
Pressure
(psi)
5.5 in x 8.15 in x 9 m
ESWELL PROFILE
0
5
10
15
20
25
30
35
40
45
50
8.15 8.24 8.32 8.41 8.49 8.58 8.66 8.75 8.83 8.92 9.00 9.09 9.17
Hole ID (in)
Time(days)
0
5
10
15
20
25
30
35
40
45
50
Time(days)
Time to Fully Set: 5.5 in x 8.15 in x 9 m
Time to Seal: 5.5 in x 8.15 in x 9 m
Swell Technology 4-9
Well Construction
With the challenges presented by depleted or even over-
pressured reservoirs, it is becoming more difficult to achieve
optimal zonal isolation using conventional methods.
Complicated wellbore geometry has pushed the limits of
technology in perfecting competent annular pressure
confinement and isolation of multiple zones.
Wells are being designed with more casing points to isolate
depleted reservoirs before drilling ahead to higher pressure
areas. The increased number of casing points dictate smaller
annular volumes between casing and open hole or casing and
casing. The smaller annular volumes make it more difficult
to provide sufficient zonal isolation or sustained casing
pressure prevention using current methods.
More casing points can also lead to larger annular volumes in
under-reamed openhole sections.
With the move into deeper water and more severe
environments, operators are requiring service companies to
adapt to these ever changing conditions. The advent of
swellable technology has presented a competent solution to
many of the challenges that have been encountered.
Swellpacker® isolation systems, along with swellable
elastomers in cement, are products that will change and
adapt along with downhole conditions.
Swellpacker® systems above top of cement
Swellpacker isolation systems on liner tiebacks
Liner Hanger
Swellpacker isolation systems below liner hangers
Swellpacker systems at shoe joints
Swellpacker systems on shoe joint forFormation Integrity Test
Swellpacker isolationsystems in production zones
with cement
HA
L33
105
4-10 Swell Technology
Swellpacker® Systems Above Top of Cement
Swellpacker® isolation systems used above top of cement
(TOC) will prevent pressure migration to surface (sustained
casing pressure) from lower reservoirs without
compromising the competency of the original cement job.
The systems will help prevent sustained casing pressure if
during the life of the well cement becomes de-bonded from
the casing which could create channels for the pressure to
migrate from the formation. Swellpacker TOC systems work
independently from other operations regardless of
conditions as long as a swell fuel is present.
Swellpacker Systems at Shoe Joints
Swellpacker systems used on the shoe joints will create a
competent pressure seal and allow for a Formation Integrity
Test (FIT) regardless of the tail cement condition.
Swellpacker shoe joint systems are designed to swell in the
drilling fluid. If there is insufficient mud cleanout in the shoe
joint area, the contaminated fluid fuels the packer, prompting
the system to swell. A formation integrity test can then be
conducted to facilitate drilling ahead. If competent tail
cementation is achieved, the Swellpacker shoe joint system
does not activate.
Swellpacker Systems Below Liner Hangers
Liner hanger Swellpacker systems help provide a positive seal
to isolate the openhole section from the surface. The
Swellpacker systems are installed on a liner below a liner
hanger inside the parent casing. The liner hanger Swellpacker
system can be designed to swell either before the liner hanger
is set, or after the liner hanger pack-off is energized. Using
the liner hanger Swellpacker system can eliminate the need
for liner top squeeze jobs, resulting in a substantial savings of
time and money. The system can be employed with or
without cement.
Swellpacker® OBM System
Liner
Low-Pressure Zone
Open Hole
Swellpacker® System
at Shoe Joints
Swellpacker® Isolation System
Below Liner Hangers
Swellpacker® System
Above Top of Cement
HA
L33
102
HA
L33
100
HA
L33
104
Swell Technology 4-11
Swellpacker® Systems in Production Zones with Cement
Swellpacker® systems when combined with primary
cementing operations can provide comprehensive long-
term zonal isolation, increasing the productive life of the
well and minimizing the potential for an expensive
workover operation.
Incorporating Swellpacker systems in production zones with
cement can also provide a reactive downhole means to
address the micro-annulus that occurs when set cement
debonds from the casing. The Swellpacker system will
remain dormant while encased in the cement sheath. Once
the micro-annulus opens up and liquids or gas attempt to
flow through, the packer will swell to close the flow path. The
swellable rubber will conform to almost any irregular
geometry in the casing or cement.
Swellpacker Systems on Liner Tiebacks
Using Swellpacker systems on liner tiebacks provides
pressure holding capability and also creates an enormous
anchoring force for the liner tieback string—eliminating the
need for cement to anchor the tieback string. Swellpacker
systems are installed above the seal assembly and the tieback
string is run in the hole to the tieback receptacle. After the
seal assembly is pressure tested, it is then raised, and fuel for
the swellable element is circulated to the proper place (if not
in place already). The seal assembly is lowered back into the
tieback receptacle, allowing the Swellpacker system to swell.
Implementing Swellpacker systems frees up time and helps
reduce cost because there is no cement, float equipment, or
cement plugs to drill out before completing the well.
Swellpacker Systems on Scab Liners
Scab liners are placed in the well to simply provide a casing
conduit from the lower liner to the upper tieback casing
string. Cementing a scab liner in place is time consuming
and can be risky. Using Swellpacker systems on scab liners
helps reduce the risk of performing a competent cementing
job in relative small annuli. Swellpacker systems will provide
high-pressure sealing capabilities.
Swellpacker® Isolation System
in Production Zones with Cement
Swellpacker® Isolation System
on Liner Tiebacks
HA
L33
101
HA
L33
103
4-12 Swell Technology
Testing Facilities
Since the first introduction of the Swellpacker® system in
2001, much has changed. Swell Technology systems have
been accepted by a large number of operators worldwide.
The growing complexity of well designs in harsher
environments has increased the need for more diverse
Swell Technology products and more rigorous testing on
tools that are going to be commercialized.
In order to support the research and development efforts
required for product development, Halliburton has invested
in laboratory facilities in Norway and the United States.
Research and Development Lab -Stavanger, Norway
The main facility for Swell Technology research and
development opened in August 2008 and is located near
Stavanger, Norway. The 8,000 ft² laboratory has tripled the
capacity of Halliburton’s ability to design, test, and qualify
new swellable technology products.
At this center, Halliburton has the opportunity to consolidate
key personnel—product management, global technical
support teams, and research—and enhance collaborative
efforts with the customer during the design, testing, and
qualifying stage.
All standard tests, qualification testing, and customer/
project-specific tests can be performed at this facility,
including swell speed testing at customer-specified
conditions, full-scale differential pressure performance
under both static and dynamic fracturing conditions,
scaled (reduced size) packer testing, gravel pack testing,
and friction testing.
For customer-specific tests, the procedures are agreed upon
between Halliburton and the customer before the test unit is
built and the test is executed. These procedures contain the
specifics of the test, timeline, reporting, and the testing
budget. This facility is set up with digital logging and
recording systems to accommodate the customer’s need to
evaluate the technology. Remote witnessing of the testing is
available upon request.
Swell Technology
Research and Development Lab
HA
L31
941
Swell Technology 4-13
Swell pressure testing is performed at an early stage in
elastomer compound development. The objective is to
verify swelling and internal pressure building in the
elastomer, which indicates the differential pressure
performance on full-scale tools.
The swell speed test cell determines tool swelling speed at a
specific downhole temperature. The fluid used can either be
a sample supplied by the customer or a standard base oil. The
primary advantage of this “donut testing” is to help
determine the correct geometry, since the shape of the
sample tested has a significant impact on the test outcome.
All test results are subsequently used to update the SwellSim®
simulation software.
Differential pressure testing is conducted in large autoclaves
for full-scale tools only. Maximum pressure test pressure is
15,000 psi.
The final test conducted on Swell Technology tools before
commercialization is the run-in-hole simulation or
ruggedness test. In this test, full-scale tools are run through a
milled window. The main objective is to test the robustness
of the tools (both element and end ring) in a dry
environment (no lubrication of any fluid).
HA
L31
901
Differential
Pressure Testing Area
Swell Speed
Test Cell
HA
L33
081
Swell Pressure
Testing Cell
HA
L31
905
4-14 Swell Technology
Support Lab - Carrollton, TX, United States
Halliburton's engineering test facility in Carrollton, Texas,
has the capability to run full-scale swell speed testing and
differential pressure testing. At the main facility, testing can
be carried out up to 600°F (315°C) and up to 20,000 psi
(1375 bar).
The center's engineering test facilities also provide
engineering analysis and support, high-temperature/high-
pressure testing, and tool pre-qualification to API and
ISO requirements.
The center includes two working test wells with rig
accessories, slickline, and E-line operations as well as flow
testing capabilities which allow Halliburton to simulate
actual well environments before running new tools in a
customer's well.H
AL
1770
2
Carrollton Test Facilities
Swell Technology 4-15
4-16 Swell Technology