2. 2
Our success is based upon our ability to
provide solutions which overcome the
industry’s challenges, your challenges.
Success which has led to growth; year on
year on year on ….
2009 2010 2011 2012 2013 2014
Accumulated activity per year
ACCUMULATED ACTIVITIES PER YEAR
3. 3
LET’S
TRANSFORM THE
INDUSTRY, SHALL
WE?
Lower risk 4
Higher returns 5
Do more with less 6
We do this for a living 8
Overcome the challenges 15
NOW IS THE TIME
You need the vision and the technology to improve returns,
reduce risks and increase sustainability. And with fluctuating
oil prices, there is even more pressure to reduce your cost
basis and evaluate the way you work without increasing your
exposure.
At Welltec®
, we believe it’s possible to improve the way the
industry operates by offering a change in mindset, a change in
technology. For decades we have pursued and demonstrated
this, achieving widespread growth.
Our customers have increased their recovery rates using a
fraction of the time and energy of conventional methods.
Their cash flows have been improved by faster, extended
revenue streams and significantly lower costs. And they have
exploited the full value of their reservoirs at a much lower
level of invested capital, with fast track fields developed
and maintained from fewer lease or topside locations.
EXPLORE YOUR OPTIONS
7 CONTINENTS FOR
GLOBAL COVERAGE,
59 LOCATIONS FOR LOCAL
HELP, MORE THAN 35,000
JOBS FOR UNSURPASSED
EXPERTISE
GET READY
CHANGE YOUR GAME
4. 4
The Flex-Well®
provides tangible benefits to
operating companies by considering the
reservoir, the drilling and completion process,
the field infrastructure and even PA through
its advantages. It provides the capability to
minimize reservoir uncertainty and maximize
production while reducing capex.
REDUCED UNCERTAINTY
Capitalizing on today’s extended reach drilling
technology for maximum reservoir contact
(MRC) is critical. This provides the opportuni-
ty to overcome uncertainties and to maximize
drainage, ultimately leading to fewer wells. To
surmount the challenge of producing an MRC
well, the reservoir is compartmentalized into
multiple, discrete sections through the use of
the Welltec®
Annular Barrier (WAB®
). This is
an expandable metal barrier which ensures
zonal isolation. The discrete compartments
are controlled individually over the life of the
well, minimizing reservoir uncertainty and op-
timizing production.
HIGHER PRODUCTION
Maximum production is accomplished not
just by compartmentalized control but also by
reducing skin damage during the well con-
struction phase. The Flex-Well®
completion is
enabled with technology that promotes
cementless completions, eliminating the po-
tential damage that cement could cause.
Production is further increased through the
full bore construction design and the elimina-
tion of control lines. Hence there are no re-
strictions and drawdown can be optimized for
maximum reservoir drainage. Elimination of
control lines also means wells could be rede-
signed and drilled with smaller hole sizes yet
capable to produce more.
EASIER CONSTRUCTION
The rugged construction of the WAB®
and
other completion components allows for full
rotation during completion. And the solid lin-
er functionality means it can be air filled and
floated in if necessary. This combined with a
full bore internal diameter enables full, effi-
cient circulation and mud clean-out; overall,
a driller’s dream.
LOWER CAPEX
Optimized production over the life of the well
from extended reach, MRC completions yields
more extensive reservoir drainage. Fullbore
diameters throughout with discrete, compart-
ments across the reservoir section yield more
production. Maximum production from fewer
wells draining the reservoir completely de-
creases the number of pad sites or platforms
required, significantly reducing capex.
LOWER RISK –
FLEX-WELL®
HIGHER PRODUCTION, LOWER COST,
REDUCED CAPEX – ABSOLUTELY.
5. 5
FLEX-WELL®
Fast track and build wells which produce more, drain larger areas and
won’t require interventions for years to come. The higher production and
drainage per well enables you to reduce the number of platforms or pad
sites required, significantly reducing overall CAPEX.
The Flex-Well®
completion design provides all these benefits while
simultaneously offering an approach that results in fewer people
required, less complex operations and smaller amounts
of equipment deployed for shorter amounts of time.
Simply put, higher recovery in a safer,
more sustainable way.
WITH NEW TECHNOLOGY
HIGHER RETURNS
P
I
5
6. 6
...to being capable of
doing everything on tractor...
DO MORE –
SAFETY AND SUSTAINABILITY
Higher returns and increased sustainability are
no longer contradictions.
We have pioneered lightweight technology
that can perform the same work as much
larger, more complex methods. Using smaller,
more elegant equipment and techniques we
provide precise, accurate solutions with
robotic equipment.
This approach results in fewer people and less
equipment required at the wellsite than con-
ventional practices. A smaller, simpler method
taken to extraordinary levels results in inher-
ently safer operations with significantly lower
cost, complexity and carbon footprints.
It’s our vision to implement this concept to all
we do, providing 'leaner, greener' practices to
transform the industry into one that is overall
safer and more sustainable.
This is demonstrated by the impact of our
technology as it was introduced in Norway.
It has proven to be an effective, disruptive
methodology which continues to be embraced
today on land, offshore platforms and increas-
ingly on subsea wells with Riserless Light Well
Interventions (RLWI).
From intervening
using snubbing...
...to coiled tubing
interventions...
+
7. 7
WITH LESS
PEOPLE AND EQUIPMENT
...for increased safety and
sustainability.
8 YEARS IN
ASIA PACIFIC WITH
NO LTI AND
10 YEARS IN ALASKA
WITH NO
ACCIDENTS
599
43 50
460
0
100
200
300
400
500
600
cost value creation
Field 1 Field 2
Our work over the last twenty years has repeatedly proven that
interventions can be accomplished to restore, maintain or improve
production. This results in better cash flow in the short term but also in
an overall increase in total recovery that maximizes ROI.
By changing strategy from a ‘fix it when it breaks’ to a systematic, planned
intervention approach, one of our customers has increased their earnings
by $40 billion dollars. This has been realized by increased operational
efficiency, minimized losses and overall optimized production
throughout an extended reservoir life.
Simply put, higher recovery in a safer, more sustainable way.
Mill $
HIGHER RETURNS
In the late 1990's a North Sea operator invested $50
million in one field and gained $559 million in value. In
another field the same operator invested $43 million
and received $460 million in value; all during a period
when oil was priced at $20-$40 BOE.
7
Our work over the last twenty years has repeatedly proven that
interventions can be accomplished to restore, maintain or improve
production. This results in better cash flow in the short term but also in
an overall increase in total recovery that maximizes ROI.
By changing strategy from a ‘fix it when it breaks’ to a systematic, planned
intervention approach, one of our customers has increased their earnings
by $40 billion dollars. This has been realized by increased operational
efficiency, minimized losses and overall optimized production
throughout an extended reservoir life.
Simply put, higher recovery in a safer, more sustainable way.
8. 88
REDUCE COST
THE USE OF E-LINE/E-COIL DEPLOYED TOOLS DURING ANY
FRACTURE OR STIMULATION OF A VERTICAL OR HORIZONTAL
WELLBORE WILL BE THE NEXT REVOLUTION IN THE INDUSTRY.
NEW COMPLETION TECHNIQUE REDUCES
COST ~ 30% PER WELL
Saskatchewan, Canada an operator was using a standard pro-
cedure to complete their wells, performing a mini frac, record-
ing surface data for 4-5 days, then running coiled tubing (CT)
to perform a confirmation / clean-out run prior to e-line perfo-
rating and fracturing.
Some challenges included not getting the mini-frac results soon
enough to use them effectively and a large equipment foot-
print, especially for the CT clean-out.
Welltec’s technique removed the large equipment spread while
providing more, higher quality data while simultaneously per-
forming the clean-outs. Using the Well Tractor®
in combination
with the Well Cleaner®
Reverse Circulating Bit (RCB), a CCL and
a Welltec®
Pressure Temperature (WPT) sub allowed the opera-
tor to obtain the actual bottom hole pressure and temperature
on depth while performing the clean-out run.
Additionally, accurate PBTD was determined along with the
actual position of each of the numerous frac ports. Using this
information enabled changes to be made to the frac model and
schedule for optimized efficiency with a cost reduction of ~
30% per well.
E-LINE OPTIMIZES MULTI-STAGE FRACTURING
IN THE BAKKEN SHALE PLAY
North Dakota, USA a long horizontal section required comple-
tion of 26 zones beginning at a depth of 21,740 ft.
The job was complicated by an ID restriction midway down
the well which increased the risk past the acceptable point for
pump down operations. Combined with road restrictions, strict
budget and time constraints, a Well Tractor®
deployment ap-
proach was perfect for getting this $9MM asset on-line.
One of the largest shale deposits in North America, the tight,
unconventional reservoirs of the Bakken are being exploited by
many operating companies, national as well as international.
And as with many assets in North America, cost and efficiency
are paramount to success.
A Well Tractor®
solution deployed the 'plug and perf' runs for
all 26 zones with zero lost time. This e-line solution allowed
for full control of the toolstring to negotiate the ID restriction
successfully on each run. A total of 27.8 miles (44.7 km) were
tractored during the deployment where the speed and reliability
of the Well Tractor®
were critical in aiding the operator to com-
plete the well with reduced costs and risk.
WE DO THIS
FOR A LIVING•
NEW COMPLETION TECHNIQUE REDUCES
COST ~ 30% PER WELL
Saskatchewan, Canada an operator was using a standard pro-
cedure to complete their wells, performing a mini frac, record-
ing surface data for 4-5 days, then running coiled tubing (CT)
to perform a confirmation / clean-out run prior to e-line perfo-
rating and fracturing.
Some challenges included not getting the mini-frac results soon
enough to use them effectively and a large equipment foot-
print, especially for the CT clean-out.
Welltec’s technique removed the large equipment spread while
providing more, higher quality data while simultaneously per-
forming the clean-outs. Using the Well Tractor®
in combination
with the Well Cleaner®
Reverse Circulating Bit (RCB), a CCL and
a Welltec®
Pressure Temperature (WPT) sub allowed the opera-
tor to obtain the actual bottom hole pressure and temperature
on depth while performing the clean-out run.
Additionally, accurate PBTD was determined along with the
actual position of each of the numerous frac ports. Using this
information enabled changes to be made to the frac model and
schedule for optimized efficiency with a cost reduction of ~
30% per well.
E-LINE OPTIMIZES MULTI-STAGE FRACTURING
IN THE BAKKEN SHALE PLAY
North Dakota, USA a long horizontal section required comple-
tion of 26 zones beginning at a depth of 21,740 ft.
The job was complicated by an ID restriction midway down
the well which increased the risk past the acceptable point for
pump down operations. Combined with road restrictions, strict
budget and time constraints, a Well Tractor®
deployment ap-
proach was perfect for getting this $9MM asset on-line.
One of the largest shale deposits in North America, the tight,
unconventional reservoirs of the Bakken are being exploited by
many operating companies, national as well as international.
And as with many assets in North America, cost and efficiency
are paramount to success.
A Well Tractor®
solution deployed the 'plug and perf' runs for
all 26 zones with zero lost time. This e-line solution allowed
for full control of the toolstring to negotiate the ID restriction
successfully on each run. A total of 27.8 miles (44.7 km) were
tractored during the deployment where the speed and reliability
of the Well Tractor®
were critical in aiding the operator to com-
plete the well with reduced costs and risk.
9. 9
94% TIME SAVINGS, INCREASED SAFETY
AND CASH FLOW
Offshore Mexico, subsurface safety valves (SSSV) require peri-
odic function testing to ensure reliable operation when need-
ed. Typically, they are tested and if they fail, a workover rig is
scheduled to shut in the well and replace them.
A new technique has successfully been implemented which
precludes the requirement to shut in the production or even
to mobilize a workover rig. Using the Well Cleaner®
Wishbone
Honer (WBH), the operator has been able to repair the valve
in-situ with the well flowing.
Analysis determined that often the SSSV failed to close com-
pletely due to debris which limited its ability to hold pressure
during the testing. After careful planning, a Well Tractor®
and
Well Cleaner®
WBH were mobilized and run on e-line to the
desired depth. There the WBH was activated and cleaning of
the SSSV and surrounding tubing was performed. Following
the cleaning the SSSV was successfully tested.
The entire operation was completed in only 18 hours compared
to ~ one week for the rig operation to pull the SSSV. And the
well remained on production throughout, demonstrating the
benefits that e-line interventions can provide.
FIRST DEEPWATER WELL WITH CEMENTLESS
COMPLETION USING WAB’S
Offshore Brazil, cemented liners in some deepwater wells have
proven extremely challenging to deliver effective well barrier
isolation and prevent co-mingling due to the reservoir pressures
and equivalent circulating density (ECD). This can lead to inef-
fective completions as well as build-up of surface annular pres-
sure (SAP) within the B annulus.
Applying state-of-the-art, well annular barrier technology in the
form of the Welltec®
Annular Barrier (WAB®
), the first deepwa-
ter well offshore Brazil was completed without using cement.
The WAB’s provided the zonal isolation and a standalone well
barrier.
Prior to installation the individual components were subjected
to repeated cycle testing replicating a 30 year, life of well simu-
lation. Post installation injection testing was done and pressure
monitoring recorded downhole. These results were recovered
and analyzed at surface demonstrating complete inflation and
integrity of the WAB’s.
The capability to remove cement from the lower completion
provides the operator tremendous advantages; higher produc-
tion, faster more efficient completions, reduced equipment
needs, fewer operations, increased safety and of course, re-
duced overall costs.
THIS WAS A JOB WELL PLANNED AND EXECUTED.
WHAT A GREAT PERFORMANCE BY WELLTEC®
.
TRIED
AND TRUE
– DECADES
OF DELIVERING
OUTSTANDING
SERVICE
. . . READ THE FULL STORY AT WELLTEC.COM/JPT
10. 10
HIGHER VALUE FROM MAINTAINED
PRODUCTION AND SAVINGS OF $15MM
Offshore Angola, a deepwater well was suffering from exces-
sive gas breakthrough, limiting oil production. The gas was
coning and producing from the top of an open hole gravel
pack completion, bypassing the oil it was intended to energize.
A solution arrived in the form of a 525 foot (160m) long,
straddle isolation assembly. Installation of this hardware was
accomplished in sections and necessitated precise control of
both depth and force; the former to ensure proper position
downhole and the latter to avoid seal damage whilst stabbing
and latching the individual segments, joint by joint.
The Well Tractor®
and Well Stroker®
provided the best solution
for the operator; a combination which delivers precise, accu-
rate depth and force control irrespective of distance in the well.
Multiple runs were made to ‘build’ the straddle assembly up,
piece by piece in this live well.
The job was completed safely, 30 days faster than originally
planned. This first of its kind operation in West Africa effective-
ly shut-off the gas breakthrough and increased oil production
multifold. The efficient operations resulted in more than
$15MM saved in rig costs while improving the overall efficiency
of the production asset.
PRODUCTION RESTORED, $2MM SAVED
Offshore Nigeria, a retrievable safety valve assembly failed to
seat properly in the tubing and flowed up hole with the pro-
duction to get stuck somewhere near the tubing hanger; pre-
cise position unknown.
More than 1,000 slickline jar attempts were made to free the
fish. Indicators showed that the lock mandrel fishing neck
was partially open, suggesting that its keys were jammed in
a slightly inclined position, below the lower ID of the tubing
hanger profile.
Based on the unique problem description, Welltec®
engineered
a solution. Using the Well Tractor®
and Well Miller®
plus a cus-
tom nipple milling bit in combination with the Well Stroker®
the team succeeded in milling out the safety valve which fell
to the bottom of the well as desired, restoring access and
production.
This successful milling operation enabled the operator to avoid
having to pull the entire completion string and saved more
than USD 2 million compared to the alternatives. The operator
was very pleased to be able to regain the well in a shorter time
frame and estimated that the milling solution was twice as effi-
cient as the other options.
EXCELLENT PERFORMANCE THAT
CLEARLY SHOWS DIFFERENTIATION
FROM THE ALTERNATIVES.
WE DO THIS
FOR A LIVING
LOWER CAPEX COST
••
11. 11
CEMENTLESS COMPLETION LOWERS COST
AND YIELDS HIGHER PRODUCTION
Offshore North Sea, an operator needed to deploy a liner
across an 8,000 ft horizontal section within a reservoir contain-
ing eight zones. The zones needed to be completely isolated
from one another during a high pressure, extensive acid stimu-
lation job as well as isolate a nearby, water bearing zone.
To reduce costs and maximize reservoir exposure to the acid,
cement was avoided.
Sixteen Welltec®
Annular Barriers (WAB®
) were installed in
the well, sealing off the eight selected zones. The WAB®
is an
award winning, expandable, metal annular barrier engineered
and qualified to replace cement in well construction. Its
rugged design to ISO V0 meets regulatory standards,
including NORSOK.
With the zones completely isolated, the stimulation job was
executed with up to 6,000 psi achieved between zones.
Independent temperature and pressure sensors located within
each zone confirmed the integrity of each compartment.
Eliminating the need for cement on this project lowered the
CAPEX and enabled the operator to achieve the desired, ex-
tended reach drilling program while overcoming limiting ECD
concerns. Initial and subsequent production from the well has
exceeded expected results.
1,500 LBS OF SAND REMOVED FOR
HIGHER RETURNS
Offshore North Sea, a well completed back in 2010 had begun
to produce sand. As the operator began to consider options,
they explored Welltec’s portfolio for a lower cost approach
than a workover rig or a coiled tubing unit.
Work began with a Well Cleaner®
Reverse Circulating Bit (RCB)
to drift the well and recover sand. The RCB is capable of milling
through hard packed debris and collecting it within the tool in
the same descent. After two runs, bringing back ~ 120 lbs (54
kg), it was determined that the majority of fill was loose.
The Well Cleaner®
Power Suction Tool (PST) was put into action
for the next six runs. The PST utilizes a venturi system to vacu-
um up loose debris, capturing it in bailer section and removing
it from the well. Running up to eight bailers per descent the
PST removed up to 300 lbs (136 kg) per descent. A hard restric-
tion then returned the RCB to action where it recovered anoth-
er 60 lbs (27 kg) of sand before the well was clear.
Without utilizing a rig or a coiled tubing unit the operator was
able to perform a sustainable workover on e-line, removing ~
1,500 lbs (680 kg) of sand in order to evaluate next steps for
increasing returns from this oil producer.
11
FIRST
NORSOK COMPLIANT,
CEMENTLESS,
PRIMARY WELL
BARRIER
30,000 LBS
OF COMPRESSIVE FORCE –
RECORD FOR SUCCESSFUL
TUBULAR CUT USING A NON-
EXPLOSIVE, E-LINE TOOL –
THE WELL CUTTER®
. . .READ THE FULL STORY AT WELLTEC.COM/JPT
12. 12
WELL STROKER®
XXS SAVES FOUR DAYS OF
RIG TIME AND RECOVERS STUCK TOOL
Baku, Azerbaijan, time and costs were mounting during an
operation when a 7 retrievable packer and the setting tool
got stuck at 6,486 ft (1,977 m) preventing the operator from
putting this oil producer on production.
Determined to returning the well to production as quickly as
possible, the operator called out Welltec’s new double stroker.
Capable of accurately exerting force up to 100,000 lbs, the
Well Stroker®
XXS latches the assembly, locks into place and
exerts the force directly onto the fish (or sliding sleeve or plug)
with no strain on the e-line or other parts of the toolstring.
Surface read-out allows direct measurement and control of
the force downhole.
On the first run the Well Tractor®
conveyed the Well Stroker®
XXS to the fish where it latched and applied 55,000 lbs to
release the stuck setting tool from the plug. Then the entire
assembly was pulled from the well and operations resumed to
put the well on production.
Use of Welltec’s e-line solutions enabled the operator to pre-
vent mobilization of a heavy duty coiled tubing unit, providing
a fast, effective solution and saving a minimum of four days rig
time as well as the environmental and cost differences.
WORLD’S FIRST HYDRATE PLUG REMOVAL
ON E-LINE RESTORES WELL FUNCTIONALITY
Offshore UK, North Sea, a water injection well was undergo-
ing start-up procedures when a build-up in pressure indicated
a blockage. Hydrate was suspected and multiple attempts to
inject methanol cleared the flow and wing valves but not the
subsea tree.
Pressure pulses, induced heat generation and Welltec’s clean-
out solutions were all carefully evaluated. The Well Cleaner®
RCB was put into action after three days of pressure pulsing
failed to break down the hydrate plug. In less than 20 hours of
actual operating time, 173 ft (52 m) of hydrates were removed
to a depth that allowed the operator to re-establish function-
ality to the downhole safety valve.
The significant depth of hydrate that was cleared from this
world’s first operation demonstrated the proof of concept very
well. Additionally, this work was operated from a vessel (RLWI)
rather than a rig. The ease of load out and reduced number
of people provided significant cost reductions versus rig based
alternatives.
I WISH TO THANK ALL FOR THE GREAT WORK...THE
MAIN FOCUS WAS CONTINUOUSLY ON HSE AND WELL
CONTROL, MUCH PLANNING BOTH OFFSHORE AND
ONSHORE ...VERY GOOD.
12
MAINTAIN PRODUCTION
WE DO THIS
FOR A LIVING•••
. . .READ THE FULL STORY AT WELLTEC.COM/JPT
13. 13
INCREASED SAFETY AND OPERATIONAL
EFFICIENCY DURING WELL WORKOVER
Offshore Qatar, during recent completion retrievals in Qatar
the Well Cutter®
demonstrated that it’s able to perform two
cuts in the same run, furthering operational efficiency for the
operator.
A well was producing at 92% water cut and in need of a work-
over to remediate. The Well Cutter®
was already being applied
by the operator to cut the 4.512.6 ppf tubing but doing
two cuts in one run would result in significant time and cost
savings.
The Well Cutter®
is a novel, explosive free, tubular cutting tool
run on e-line. It offers a much safer, much easier to obtain al-
ternative within the industry. Additionally, the tool has demon-
strated a unique ability to cut the tubulars regardless of wheth-
er they are in compression or tension, eliminating this element
of uncertainty and risk.
Surface testing was successfully accomplished and on the next
operation the new capabilities were put to the test. At approx-
imately 85 degrees deviation the 4.5 tubing was successful-
ly cut at 9,268 ft (2,825 m) and then at 6,950 ft (2,118 m) in
the same descent, furthering Welltec’s vision to offer increased
safety and operational efficiency for our customers.
82% INCREASED PRODUCTIVITY THROUGH
INCREASED DEPLOYMENT
Dharan, Saudi Arabia, a number of extended reach, open hole
completion wells have been drilled throughout the region in-
cluding the Manifa field. Coiled tubing (CT) is typically engaged
to provide the stimulation but if the CT can’t reach to the TD of
the well, the stimulation is not as effective.
The reach capabilities of the CT depend on its physical charac-
teristics, the completion size and wellbore geometry. Welltec’s
CT Well Tractor®
is a hydraulic driven, modular tool which
attaches to the end of the CT and pulls it further into the
wellbore.
In extended reach fields it’s important to further the reach of
the coiled tubing in order to maximize the impact of the stim-
ulation. Anything in front of the CT must be stimulated with a
less effective, bull heading technique.
Welltec’s CT Well Tractor®
has been successfully applied mul-
tiple times to substantially increase the reach of the coiled
tubing. Research has indicated that the effective stimulation
length of 15 wells studied was increased from an average of
1,727 ft (526 m) of open hole interval to an average of 3,524
ft (1,074 m); more than double. The value derived from this
increase in stimulated reservoir for the wells reviewed was an
82% boost in productivity index.
46,801 FT
TRACTORED –
RECORD FOR DIS-
TANCE IN OPEN HOLE IN
ONE RUN – 218 WELL
TRACTOR®
WE WERE VERY IMPRESSED WITH THE TECHNICAL
PERFORMANCE OF THIS SOLUTION DUE TO ITS
HIGH RECOVERY RATE AND WANT TO
CONGRATULATE THE WELLTEC®
TEAM
INVOLVED FOR PERFORMING
FLAWLESSLY WITHOUT ANY
ACCIDENT.
14. 14
90% COST REDUCTION WHILE RESTORING
INJECTION ON A LIMITED SPACE PLATFORM
Offshore India, limited crane height, space and daylight op-
erations posed challenges on a small platform to an operator
trying to restore injection on a converted producer.
A thorough risk assessment was conducted and equipment
mobilized offshore to rectify the problem. The first run revealed
that the GS profile couldn’t latch onto the lock mandrel com-
pletely. A Well Cleaner®
Power Suction Tool (PST) was then run
to remove debris which had settled on top of the lock mandrel.
The Well Cleaner®
PST uses a venturi system to create a power-
ful vacuum which agitates and mobilizes the debris, trapping it
inside bailers and removing it from the wellbore.
Once the Well Cleaner®
PST was recovered, the Well Stroker®
with GS pulling tool was run. It latched the lock mandrel and
with one stroke pulled the reluctant lock mandrel (and attached
TTSS) free. The entire assembly was removed from the well and
injection established at 22,000 bwpd.
The operation was carried out in only three days and provided
significant savings, approximately 90%, versus a barge-based,
coiled tubing operation.
WELL MILLER®
RESTORES 100MMSCFD
PRODUCTION WHILE REDUCING COSTS
Offshore Australia, an inflatable packer had released and mi-
grated uphole, passing through a flapper valve where it then
got stuck. To complicate matters further, a hold-open sleeve
dislodged during the migration and landed on top of the valve.
Conventional fishing had failed to solve the problem and the
fishing head was sheared off in the process, complicating the
retrieval. Unable to latch onto the plug, the operator looked to
Welltec®
for a milling solution to clear the well.
The Well Miller®
is a robotic machine shop designed and engi-
neered to mill through and remove malfunctioning hardware
or unwanted elements such as this one. A wide variety of cus-
tom made bits provide a milling, cutting solution to overcome
extreme challenges.
Utilizing the Well Tractor®
, Well Miller®
and Well Stroker®
, the
well was quickly cleared of the inflatable elements and oth-
er debris. Seventeen runs were conducted with zero misruns
and no HSE or quality incidents. The series of operations took
place in half of the anticipated time and without the need for
a workover rig; significantly reducing costs versus budget and
bringing the well back on-line at 100 MMSCFD after two years
of inactivity.
WHAT A GREAT PERFORMANCE BY WELLTEC®
– 17 RUNS WERE CONDUCTED WITH ZERO
MISRUNS AND NO HSE OR QUALITY INCIDENTS,
WHICH IS AN OUTSTANDING ACHIEVEMENT.
FLEXIBLE
BUSINESS MODELS
DESIGNED FOR
PERFECT
PARTNERSHIPS
15. 15
WE'VE GOT THE TECHNOLOGY
OVERCOME THE
CHALLENGES
15
At Welltec®
, we have the vision and technology to help improve
returns, reduce risks and increase sustainability. With fluctuating oil
prices, we are even better positioned to assist in reducing your cost
basis without increasing your exposure.
We develop and provide well technologies and solutions for the oil
and gas industry. Our success is based upon our ability to continuously
create truly disruptive innovations, making the industry safer and more
sustainable while achieving higher recovery. Through a unique combi-
nation of patented technology and innovative approaches, we deliver
game-changing value.
Our customers have increased their recovery rates using a fraction of
the time and energy of conventional methods. Their cash flows have
been improved by faster, extended revenue streams and significantly
lower costs. And they have exploited the full value of their reservoirs at
a much lower level of invested capital, with fast track fields developed
and maintained from fewer lease or topside locations.
Now is the time. Explore your options.
CONTACT US
WELLTEC.COM/JPT
