April 2021 | Case study: A leading onshore operator in the Middle East required a solution to sy rates across the formation of interest. A 2.36” OD Multi-Set Acid Stimulation System(ST60) configured with a 3.50” OD DuraGRIP™ bi-directional packer element was supplied to a third-party oilfield service provider. The ST60 system functioned as designed, allowing the operation to be carried out without complielectively isolate a formation across a perforated 4.5-inch liner in a vertical injection well. Zonal isolation was required to effectively acidize and increase porosity and optimize injectivitcations or safety incidents. Operational expenses were considerably reduced given that selective zonal stimulation across the desired interval through rigless conveyance drastically reduced treatment-fluid volumetric requirements, overall pumping time, and environmental foot print in comparison to rig-based, workstring-conveyed stimulation methods.
February 2020 | Case study: A leading offshore operator required to plug an open-hole section to establish a kickoff point as part of a sidetrack drilling operation in a deep-water well in Western Australia. The original plan was to set a balanced cement plug on top of a high-viscosity pill across the 17-1/2" open-hole section. This approach failed to provide the stability needed for sidetrack drilling as no hard
cement was found at setting depth during a subsequent run
December 2019 | Case study: A major petrochemical company in the Texas Gulf Coast required to decommission a salt cavern well as a preventive measure due to safety concerns associated with upward fluid encroachment across various formations. An IPI 11” OD Permanent Inflatable Bridge Plug (PIBP) was deployed on coiled tubing and successfully set at the required setting depth, allowing the operator to complete the well-abandonment plan in compliance with local decommissioning regulations.
December 2019 | Case study: A leading offshore operator in the Gulf of Mexico (GoM) was required to perform remedial work in a previously abandoned well due to the presence of bubbles on surface caused by gas migration within the wellbore. Two inflatable bridge-plugs were set as planned without operational or safety incidents, allowing the operator to efficiently perform stringent bubble testing activities over the course of two days to ensure compliance with local environmental regulations.
August 2019 | Case Study: A leading onshore operator required the installation of an insert progressing cavity pump (I-PCP) in 3-1/2” completion tubing to bring a suspended well into production. The project took place in a major Middle East oil field. Although the production tubing did have a pump seating nipple (PSN), it was not utilized due to concerns of corrosion (caused by chemical attack) and lack of positive axial anchoring for flush by operations. Another challenge presented by the wells within the region was the constant presence of solids and high viscosity fluids which continued to affect I-PCP performance, requiring frequent well intervention and flush-by services.
July 2019 | Case Study: A leading offshore operator in South East Asia required a solution to control water-cut production in an offshore well. Multiple zones required effective zonal isolation within the 5-1/2” liner to selectively squeeze water shut-off (WSO) chemicals after passing through a 2.8” ID restriction. With IPI’s solution, Water production and crossflow within the desired formation intervals were successfully shut-off, allowing the operator to improve water-cut production to desired levels. The job was successfully executed in a safe and timely manner without operational issues, which generated substantial savings in operational costs while minimizing offshore platform non-productive time. 
May 2018 | Case Study: InflataLOK™ is the world’s first inflatable packer based, nippleless, insert-PCP anchor system. The system seals and anchors an insert progressive cavity pump using inflatable packer technology in conjunction with a hydraulically-actuated anchoring slip mechanism. It is designed for rigless deployment requiring only hydraulic pressure to set an insert PCP at any depth within the production tubing.
