Swellpacker™ System Delivers Step Change in Zonal Isolation for Intelligent Well Completions RedTech™ PAPER Part of the RedTech Learning Series November 2007 HALLIBURTON EASYWELL
Swellpacker™ System Delivers
Step Change in Zonal Isolation
for Intelligent Well Completions
RedTe ch™ PAPERPart of the RedTech Learning Series
Novembe r 2 0 0 7
HALLIBURTON
EASYWELL
An independent Operator offshore California successfully deployed oil-swelling elastomer
technology (Halliburton’s Swellpacker™ isolation system) during intelligent well completions,
accomplishing zonal isolation in three wells after conventional cementing and perforating
techniques failed. By successfully applying intelligent well completion and swelling packer
technologies together, the Operator lowered development costs and optimized production rates
while complying with the United States Minerals Management Service (MMS) that regulates all
offshore California drilling and completion operations in federal waters. The Operator was able to
further benefit from the combination of these advanced technologies as they deliver significantly
greater safety than conventional completion systems.
Business Challenge
A California independent Operator’s offshore field was too small to support a dedicated platform.
Thus, an extended-reach drilling campaign was initiated to produce the field from an existing
platform, drilling more than 16,000 ft through the highly fractured, highly faulted formation. A
predrilling study foresaw extensive production risk and uncertainties including vulnerability for
rapidly initiating water production. The intelligent well completions require the use of a large 7-in
liner for production (resulting here in a diminished area for annulus and cementing sheath).
Achieving zonal isolation is critical to minimize early water production in high-departure and
high-angle wells but conventional completion
techniques previously employed in neighboring
fields proved unsuccessful. A step change toward
achieving zonal isolation was needed.
Halliburton SolutionHalliburton addressed these challenges
successfully with Easywell Swellpacker technology
after the technical review and approval of the U.S.
MMS. Oil-swelling elastomer packers (Swellpacker
isolation system) can reliably deliver zonal
isolation even in openhole completions. An
intelligent openhole completion was chosen due
to the complexity of the reservoir characteristics
and the need to manage water production without
the need for well intervention.
EASYWELL
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HAL20372
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Operator ResultsDiscovered in 1982 by Chevron, the Rocky Point field (6
miles northwest of Point Conception, California and now
under the ownership of an independent Operator) totals
8,585 acres and is smaller than the adjacent Point Arguello
field, making it difficult to support the expense to construct
and install a dedicated platform. Extended-reach technology
was therefore chosen to develop the field from the existing
Platform Hidalgo, drilling more than 16,000 ft through the
highly fractured, highly faulted and complex reservoir.
In May 2003, before the drilling project, a front-end
engineering and design study foresaw, on the basis of
available data, a high degree of risk and uncertainty in the
overall recovery rate attainable, pressure support available,
time to first water breakthrough, speed of water cut
development and total economic impact. The study’s
recommendations therefore focused on minimizing total
costs for the life of the well while maximizing early and
ultimate recovery and minimizing the potential for early
water breakthrough in this strong-water-drive reservoir.
Completions for the Rocky Point field were initially
expected to be performed similarly to those for the Point
Arguello field. For that reason, the original completion
design had been to cement a 5½-in liner in an 8½-in hole,
since several nearby operators had used this design.
However, a larger 7-in liner was specified to allow for the
intelligent completion valves. As a result, the Operator
ordered additional modeling and a fit-for-purpose cement
to accommodate the reduced area for annulus and cement
sheath imposed by the 7-in liner in the 8½-in hole. Fit-for-
purpose rig equipment included one 750-ton alternating-
current top drive, three 1,600-hp mud pumps, one 1,800-
bbl capacity drilling fluid system, one 500-kPa setback and a
racking capacity of 22,000 ft of 5½-in drillpipe.
The completion methods first considered for the Rocky
Point wells were (1) a conventional cemented and
perforated liner combined with swell packer technology or
(2) a slotted and predrilled liner. Historically, wells in the
region have been successfully completed using slotted liners,
however, this technique may not achieve zonal isolation
since slotted liner lengths can exceed 3,000 ft and cementing
to shut off water production is a debatable technique.
Therefore a conventional cemented and perforated liner was
initially selected for well completion, though without a
Swellpacker isolation system because of the Operator’s
limited experience with swelling elastomer technology.
All three extended-reach wells were conventionally
cemented to seal the annulus. The first cement job went as
designed. Drillpipe-conveyed perforating of more than
1,250 ft with five ½-in holes per foot was completed
without incident, resulting in a successful triple-zone
intelligent completion. The second well was also cemented,
however, a remedial squeeze was needed to provide zonal
isolation. Drillpipe-conveyed perforating of more than 870
ft with five ½-in holes per foot was then completed without
incident. The third well was cemented though a retainer had
to be set and squeeze cement proved necessary when
cement logs indicated poor cement bonding behind the 7-in
liner. Drillpipe-conveyed perforating of more than 565 ft
with five ½-in holes per foot was then completed without
incident.
Given the poor primary cementing history of the first three
wells, team members agreed to try running a 7-in predrilled
liner with Swellpacker isolation systems strategically placed
between the producing intervals.
In preparation, laboratory testing performed by Halliburton
verified packer swelling times and differential pressure
ratings. Figure 1 shows the results of the laboratory testing,
which allowed for a less complicated cementing operation
design using a 9-5/8-in swell packer to seal the 13-3/8-in by
9-5/8-in casing annulus, beginning with a field test in the
first well near 5,400 ft MD (3,500 ft TVD). Testing indicated
the Swellpacker isolation system would reach a 12.25-in ID
within 11–12 days with a tailored slow-set design.
Additional setting time (30 days total) was included in the
Swellpacker isolation system design to assure the Operator
of sufficient time for cementing the entire well. After 30
days, the casing annulus was tested to 1,500 psi for 30 min.
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Figure 1—Swell testing charts.A second Swellpacker system identical to the first but
designed to set in 12 days was installed in the second well
near 5,400 ft MD (3,500 ft TVD) and tested to 1,500 psi for
30 min. Two successful tests raised the Operator’s
confidence in the Swellpacker system and demonstrated
that a second production phase using a predrilled liner with
Swellpacker isolation systems for zonal isolation had merit.
Four zones were ultimately completed in each of the three
wells with the aid of three premium Swellpacker isolation
systems. Intelligent well completions were successfully
installed in severe reservoir conditions with highly acidic
concentrations of hydrogen sulfide.
In summary, the Operator found problems with zonal
isolation during conventional cementing operations in
three wells. Swellpacker technology was tested and deployed
with the production string enabling successful zonal
isolation of the 95/8-in casing as well as the 7-in
production liner. Swellpacker technology has demonstrated
its usefulness to simplify the well completion process and to
reduce development costs.
Operator BenefitsA key benefit of Swellpacker technology is its ease of
deployment. With no moving parts, downhole activation or
surface equipment required, the Swellpacker isolation
system acts simply as part of the completion or casing
string and can be deployed in a single trip. In addition,
Swellpacker systems don’t require service technicians.
By deploying the Swellpacker isolation system during
intelligent well completions, the Operator accomplished
zonal isolation in three wells after conventional cementing
and perforating techniques were unsatisfactory. In addition,
the Operator lowered development costs and optimized
production rates. Furthermore, these advanced completion
technologies used in combination offer greater reliability
and safety than conventional completion systems because
downhole flow control valves and monitoring equipment
minimize platform personnel’s exposure to high-pressure
wellhead components when making adjustments for well
optimization.
Intelligent well completion deployment
Figure 1
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The joint use of Swellpacker technology and intelligent well
completion technologies delivered the following direct
benefits for the Operator:
Zonal isolation. Zonal isolation was successfully achieved,
minimizing early water production after deploying
Swellpacker isolation systems that had been proven to
sustain 1,500 psi in differential pressure for 30 min.
Flow control. A total of 18 retrievable flow control valves
and 18 permanent downhole quartz gauge systems were
installed, with no failures. As a result, each successfully
isolated zone received a dedicated valve and permanent
gauge that read annular conditions in the reservoir.
Intelligent well technology thereby enabled a reduction in
intervention and delivered the full promise of reservoir and
production management, monitoring and control, remotely
and in real time.
• The use of intelligent valves has allowed dry oil
production from the upper and middle interval and water
shutoff from the lowermost interval. Shutting in the lower
valve resulted in immediate, uncharacteristic and
permanent water shutoff.
• Swellpacker isolation systems helped deliver additional
production by completing three zones with intelligent
completion equipment as opposed to the original plan of
four mixed zones using conventional completions.
• The use of remotely operated downhole valves has
enhanced safety by eliminating hazards typically
associated with conventional well intervention operations.
• Downhole information received during well stimulation
treatments enabled the Operator to gain, for the first
time, a close understanding of the effects of stimulation to
each producing zone in real time. This understanding has
made changes in stimulation procedures as well as
sandface completions possible.
Efficiency. This advanced completion lowered development
costs and optimized production rates from hydrocarbon
reserves.
• Problems with isolation of traditional cementation
operations are typical in similar well sections. Swellpacker
technology nevertheless proved itself to be a reliable
solution.
• Intelligent completions techniques are not only justified
by the strict drilling regulations for offshore California
but they yield more efficient reservoir drainage and
reduce intervention costs owing to undesirable water
production.
• Savings of about 36% can be realized with the use of
Swellpacker technology and predrilled liners compared to
conventional cemented and perforated liners. The savings
are even greater if remedial squeeze operations are
considered.
• Intelligent well completions can reduce water production
as well as control the reservoir remotely.
In summary, these three wells are considered a technological
success, proving that the use of Swellpacker technology
together with intelligent well completion design is a reliable
and economical solution for zonal isolation, downhole
monitoring and flow control.
Swellpacker TechnologyThe Swellpacker isolation system employs standard oilfield
tubulars with a rubber layer chemically bonded along the
length of the packer element. The rubber element swells
upon exposure to hydrocarbons to form an effective annular
seal through a process known as diffusion, which occurs as
hydrocarbon molecules are absorbed by the rubber
molecules and cause them to stretch. The oil enters the
rubber, which swells the packer and ensures that it will
remain swollen, unlike water swelling systems which can
shrink due to the effect of the osmosis process being
reversible. Mere trace amounts of hydrocarbons are
sufficient to initiate the absorption process.
The wellbore fluid’s viscosity and temperature are key
variables in determining the time required for the swell
packer to absorb hydrocarbon and ultimately to set.
Swelling of the packer is consistent along its length.
Although hydrocarbons will not degrade the rubber, they
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will alter its mechanical properties, such as hardness and
tensile strength, depending on the rubber’s volume increase.
Swellpacker elements are chemically bonded to a tubing or
casing joint with element lengths tailored to accommodate
the desired differential pressure. Slip-on sleeve designs are
also available, normally in 12-in and 3-ft lengths, but for
low-pressure applications.
Thousands of Swellpacker systems have been run in
numerous wells worldwide for a variety of applications,
including zonal isolation across the reservoir as a substitute
for cement and providing backup should the liner
cementation prove unsuccessful.
This Halliburton white paper is a summary of IADC/SPE
105443 “Are Swelling Elastomer Technology, Preperforated
Liner, and Intelligent Well Technology Suitable Alternatives
to Conventional Completion Architecture?” by Gary P.
Hertfelder and Kurt Koerner, Plains Exploration and
Production Company; Allen Wilkins, Easywell; and Lilian
Izquierdo, Schlumberger, paper presented at the 2007
IADC/SPE Drilling Conference, Amsterdam, The
Netherlands, 20–22 February.