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Inflatable Casing Packers - ICP
Inflatable Production & Service Packers - IPP
Who is Iso-Tech Isolation Technologies?
Funded by Intervale Capital in September, 2014 to manufacture the most reliable Inflatable Casing Packers in the world
40,000 square foot manufacturing plant located at 4607 World Houston Parkway, Houston, TX
Management has over 120 years of combined Inflatable Packer experience
Committed to the highest standards of qualifying and testing of inflatable packers
Why Isolation?• The running of concentric casing requires
ZERO gas/oil migration into annuli• In many cases, this is enforced by local
governance and ordinance• This has been magnified by a recent
GOM incident• Additionally, reservoir characteristics
pose challenges with OWC/GOC and large permeability differences that allow unwanted flow into wellbore
Isolation Solutions• Historically, the method for providing
isolation has been cement• While cement is a good isolation medium, it is
susceptible to voids and non-conformances• Often bad cement jobs result in workover and
secondary squeeze operations• Cement used alone in highly
deviated/horizontal wells leads to fluid swapping and high-side channels
• Inflatable Casing Packers
Inflatable Casing Packer - ICP
• Built on a joint of casing and run as an integral part of casing string
• After inflation, it provides immediate zonal isolation
• May be set inside open hole or cased hole• Setting hole range is largest of ANY
packer type• Can be manufactured on casing sizes
ranging from 2-3/8” to 20”
IsoTech ICP Design Advantages
• Patented lock ring: Superior method of securing outer subs to mandrel and holds more load in the event the ICP hits a ledge during run-in; has been tested to twice the anticipated load. Example: 5-1/2” tested to 375K lbs with no movement
• High-flow valve system: Heat-treated and coated with a special abrasion-resistant coating to substantially reduce erosion effects of heavy mud or cement through valve system. ie: flow test of 3 bbls of 16# cement at .25 bbl/min with ZERO erosion
• High-strength valve system: after functioning, successfully tested to 12,500 psi from ID of casing simulating frac pressure
• Valve system rating: FULL casing rating
Design Advantages
• Improved end sleeves: designed to take max inflation pressure without deforming thus increasing the element’s differential capability
• Element stability: As rubber cures, it flows into a shallow square groove pattern that has been machined into mandrel. This prevents rubber from bunching up if packer encounters a tight spot running in hole
Grooved pattern in Mandrel
ICP Dimensions
Differential Pressure Capabilities
Supporting Cement in Vertical Wells
Problem: During drilling, a lost circulation zone cannot sustain a column of cement
Solution: An ICP is run in conjunction with a Stage Tool
- Once inflated, the ICP will act as the support for the cement above when the lower zone can’t sustain the pressure
- Packer provides immediate isolation while the cement cures
Gas Migration Prevention Problem: Shallow gas zones can have
adverse effects on cement during curing, causing a “honeycombing” of the column and allowing gas flow to surface
Solution: Using an ICP as a barrier to isolate the gas flow so that the cement may cure uncorrupted
- Position the ICP just above the gas zone- Perform primary cementing through the
shoe- Bump top solid plug and inflate the ICP
Supporting Cement
Isolating water contact
Isolating producing zones
Preventing gas migration
Providing segregation within horizontal zones
Isolating the build section from a horizontal producing zone
Isolating build section from a low-pressure
horizontal zone
Plugging and abandoning
Valve System OperationRun in hole
Valve Sequence
Valve Sequence
Valve Sequence
Cement Inflation - 1
Cement Inflation - 2
Cement Inflation - 3
Cement Inflation - Full
Questions for engineers• Have you been doing any squeeze
work?• Are you getting full returns on your 1st
stage cement jobs?• Are you experiencing high water
production in your conventional wells?• Do you have any casing pressure
issues at surface?
Inflatable Production & Service Packers - IPP
Why an IPP? Injection Production Packers (IPP’s) can be
run into to completed or open-hole wellbores to perform testing, stimulation and / or temporary abatement
Due to the nature of the slim design, IPP’s can be run into wells with restrictions in the completion such as; safety valves, wellheads, nipples, etc,…
The various setting / bleeding options allows for reliable performance in even the most challenging conditions
No pipe movement needed to set packer Full ID with no restrictions through tool
AlternativesCompression-type Packers
Hole setting ID ranges are usually very small
Not ideal for run-in with restrictions Small elements can fail when tensile
loading is experienced Not recommended for open-hole
Wireline / Tubing-conveyed Bridge Plugs Not capable to setting in highly deviated
wells Limited options when referring to
stimulation below the packer
Inflatable Production & Service Packer
IPP’s are reinforced inflatable elements Once inflated, provide immediate zonal
isolation Can be set inside casing and open hole Can be set multiple times during the same
run Stimulation and treating below the packer
without hindering seal
Casing Integrity Testing
Problem: There has been various instances of casing failure in a given field and finding the leak is top priority
Solution: Running an Multi-Set IPP on drillpipe to pressure test the casing in sections to determine the leak location The IPP is inflated using workstring pressure to
provide a point of isolation in the casing Pressure can then be applied above or below the
packer to test integrity Can be run with a J-Circulating Valve which can be
actuated to communicate flow from tubing to annulus
Isolating below Casing Patch or Damaged Casing
Problem: An Operator is facing issues with damaged / corroded casing above his producing section and would like to bypass casing patched areas
Solution: The reduced OD of the IPP allows it to be drifted through the damaged section and past the casing patches until it can be set inside good casing Set IPP below the damaged sections Production can continue through the workstring
without needing to kill the well
Open Hole Bridge Plug
Problem: If a lower section is starting to produce water or production has become financially unviable it should be shut-off
Solution: Running an IPP with a hydraulic or mechanical disconnect to leave plug in the well Set IPP above desired shut-off zone Disconnect from the packer using either a
hydraulic or mechanical disconnect Optionally pump cement on top of packer for
a permanent plug
Bridge Plug in section-milled casing in P&A Operation
Position IPP in larger casing in milled section Drop ball, inflate packer, close tubing test
valve Dump cement
Scab Liner with Production Packer
Problem: After a period of time the open hole production has see unwanted flow coming from the heal of the well
Solution: Running an IPP and mechanical packer with a section of tubing connecting the two IPP is set below the heal (in the horizontal
zone) Mechanical packer is set inside the casing Solid tubing between both packers with
prevent any flow from the heal
THANKS!