Non-aqueous drilling fluids may be removed from a wellbore or tubing nor casing within the wellbore by introducing into the well a biodegradable aqueous fluid comprising banana.

Systems and methods for delivering an injection fluid into a subterranean well include an injection tool having an injection tool body with an internal cavity. A fluid chamber is located within the internal cavity. A heating chamber includes a pipe segment arranged parallel to the central axis. A one way valve provides a fluid flow path for the injection fluids to travel in a downhole direction through the one way valve, and prevents the flow of fluids through the one way valve in an uphole direction. A fiber optic cable extends to the pipe segment, the fiber optic cable operable to deliver a laser radiation to the pipe segment, heating the pipe segment. The injection tool body provides a fluid flow path from the one way valve to an outside of the injection tool.

Systems and methods for delivering an injection fluid into a subterranean well include an injection tool having an injection tool body with an internal cavity. A fluid chamber is located within the internal cavity. A heating chamber includes a pipe segment arranged parallel to the central axis. A one way valve provides a fluid flow path for the injection fluids to travel in a downhole direction through the one way valve, and prevents the flow of fluids through the one way valve in an uphole direction. A fiber optic cable extends to the pipe segment, the fiber optic cable operable to deliver a laser radiation to the pipe segment, heating the pipe segment. The injection tool body provides a fluid flow path from the one way valve to an outside of the injection tool.

A liquid phase huff and puff method of enhanced oil recovery (EOR) applied to multiple groups of existing horizontal or vertical wells in a shale or tight rock reservoir resulting in additional oil recovery. The method utilizes a pumping phase for a chosen pumped well group, and a production phases for the remaining well groups. The production phases typically last longer than the pumping phases. The method operates such that while one of the well groups is pumping, the remaining well groups are producing, A new pumped well group is chosen from the production well groups upon completion of each pumping phase, with the previous pumped well group being converted to a producing well group.

An inhibitor injection spool is provided. The spool includes a segment of pipeline configured to convey crude oil and to couple with a pipeline system conveying crude oil. The spool also includes a valve on a top side or an underside of the segment of pipeline such that an interior of the segment of pipeline is selectively accessible from an exterior of the segment of pipeline. A solid corrosion inhibitor is configured to traverse an interior of the valve and such that it is positioned within the interior of the segment of pipeline such that at least a portion of the solid corrosion inhibitor fluidly contacts the crude oil traversing the segment of pipeline. Two mesh screens are coupled to the interior of the segment of pipeline such that crude oil traversing the segment of pipeline may not bypass either the first or second mesh screens.

An inhibitor injection spool is provided. The spool includes a segment of pipeline configured to convey crude oil and to couple with a pipeline system conveying crude oil. The spool also includes a valve on a top side or an underside of the segment of pipeline such that an interior of the segment of pipeline is selectively accessible from an exterior of the segment of pipeline. A solid corrosion inhibitor is configured to traverse an interior of the valve and such that it is positioned within the interior of the segment of pipeline such that at least a portion of the solid corrosion inhibitor fluidly contacts the crude oil traversing the segment of pipeline. Two mesh screens are coupled to the interior of the segment of pipeline such that crude oil traversing the segment of pipeline may not bypass either the first or second mesh screens.

The present invention addresses to a remote and autonomous chemical treatment system for application in producing wells of offshore platforms aiming at treatments for removal and prevention of production string fouling, selective completion system, well safety equipment (DHSV, HFIV) and rock formation. The purpose of this invention is to completely replace the stimulation boat, thus allowing treatments to be carried out with resources from the routine operational contracting of the offshore production unit.

The present invention addresses to a remote and autonomous chemical treatment system for application in producing wells of offshore platforms aiming at treatments for removal and prevention of production string fouling, selective completion system, well safety equipment (DHSV, HFIV) and rock formation. The purpose of this invention is to completely replace the stimulation boat, thus allowing treatments to be carried out with resources from the routine operational contracting of the offshore production unit.

Polymer matrix particles useful for inhibiting scale formation in oil and gas wells are described. The insoluble, porous, crosslinked polymer matrix includes a polymer backbone and ionic functional groups covalently bonded to the backbone, the ionic functional groups being capable of selectively attracting and binding salt scale-forming ions when in contact with a liquid containing such ions.

Polymer matrix particles useful for inhibiting scale formation in oil and gas wells are described. The insoluble, porous, crosslinked polymer matrix includes a polymer backbone and ionic functional groups covalently bonded to the backbone, the ionic functional groups being capable of selectively attracting and binding salt scale-forming ions when in contact with a liquid containing such ions.