The present invention addresses to a remote divergence method for inhibiting or removing scaling in wells equipped with intelligent completion (IC), including sealing failures, in which a mixture of viscous gel and solid material in different granulometries is used (7) and spheres soluble in water (8) and in oil (6), aiming at maintaining the production of wells equipped with intelligent completion, as well as reducing costs in relation to operations commonly performed with rigs.

The present invention addresses to a remote divergence method for inhibiting or removing scaling in wells equipped with intelligent completion (IC), including sealing failures, in which a mixture of viscous gel and solid material in different granulometries is used (7) and spheres soluble in water (8) and in oil (6), aiming at maintaining the production of wells equipped with intelligent completion, as well as reducing costs in relation to operations commonly performed with rigs.

A seal section of a submersible well pump assembly has an expandable and contractible bag surrounded by a pressure equalizing chamber. A motor lubricant communication path communicates motor lubricant the bag interior. A well fluid port admits well fluid into the pressure equalizing chamber. A gas vent passage leads from the pressure equalizing chamber to the exterior of the enclosure. At least one membrane in the gas vent passage allows gas contained in the well fluid in the pressure equalizing chamber to vent. The membrane blocks liquid from flowing through the gas vent passage into and out of the pressure equalizing chamber.

Provided are embodiments for hydrocarbon reservoir development that include the following: identifying proposed well locations within a reservoir boundary, for each location, developing a well plan by: (a) identifying layers of the reservoir located below the proposed location; (b) iteratively assessing the layers (from deepest to shallowest) to identify a deepest “suitable” layer that is not dry, congested, or unsuitable for gas production; and (c) performing the following for the identified layer and the location: (i) determining a borehole configuration for the location; (ii) determining a completion type for the location; and (iii) determining a stimulation treatment for the location, where a well plan for the location (e.g., for use in developing the reservoir) is generated that specifies some or all of a well location, the target layer, a borehole configuration, a completion type, and a stimulation treatment that corresponds to those determined for the proposed well location.

Example systems and methods are described that operate to open screen joints using mechanically-generated perforations for beginning fluid production. In an example system, a screen joint is deployed in a production tubing within a wellbore. The screen joint includes a screen element and a blank housing that are coupled to an exterior surface of a non]perforated base pipe. Further, the screen joint includes a locator profile positioned along an interior surface of the non]perforated base pipe. A perforator is deployed within the screen joint that includes a mechanical perforator and a locator for engaging with the locator profile to position the mechanical perforator under the blank housing.

Methods of stimulating a hydrocarbon well are disclosed herein. The hydrocarbon well includes a wellbore that extends within a subterranean formation and a tubular that extends within the wellbore and defines a tubular conduit. The methods include retaining a sealing structure within the tubular conduit and, during the retaining, stimulating a zone of the subterranean formation. Subsequent to the stimulating, the methods include fluidly isolating the zone of the subterranean formation from the uphole region by at least partially sealing the plurality of perforations. Subsequent to the fluidly isolating, the methods include moving the sealing structure in a downhole direction within the tubular conduit. The methods also include repeating the retaining, the stimulating, the fluidly isolating, and the moving a plurality of times to stimulate a plurality of corresponding zones of the subterranean formation.

A wellbore isolation system is disclosed. The wellbore isolation system includes a junction positioned at an intersection of a first wellbore and a second wellbore, and a deflector disposed in the junction such that a path into the first leg of the junction is obstructed and engaged with the first leg of the junction to form a fluid and pressure tight seal. The junction includes a first leg extending downhole into the first wellbore, and a second leg extending downhole into the second wellbore. The deflector includes a channel extending axially through the deflector, and a degradable plug disposed in the channel and engaged with the channel to prevent fluid flow through the channel.

A wellbore isolation system is disclosed. The wellbore isolation system includes a junction positioned at an intersection of a first wellbore and a second wellbore, and a deflector disposed in the junction such that a path into the first leg of the junction is obstructed and engaged with the first leg of the junction to form a fluid and pressure tight seal. The junction includes a first leg extending downhole into the first wellbore, and a second leg extending downhole into the second wellbore. The deflector includes a channel extending axially through the deflector, and a degradable plug disposed in the channel and engaged with the channel to prevent fluid flow through the channel.

The present disclosure provides a gullet mandrel for fluid flow optimization in a wellbore. The gullet mandrel may be coupled to a downhole valve, such that a tubing string in a wellbore will have a plurality of valves coupled to a plurality of mandrels. Each gullet mandrel may have a valve recess and one or more gullets (or grooves) located in an exterior portion of the mandrel body. The gullets may have a wide variety of configurations, and may be formed in a portion, a majority, or substantially all of the mandrel. The gullets may direct movement of fluid exterior to the tubing string and help force fluid into a laminar or linear flow pattern and prevent the formation of slug flows and/or lessen the problems encountered by slug flows. The disclosed gullet mandrel may be used in any fluid injection or production operation, such as gas-lift operations.

A valve is for closing fluid communication between a horizontal or deviated well and a production string when a content of a first or a second undesired fluid in the fluid flow exceeds a predetermined level. The valve has a primary flow channel, and a piston arrangement movable within the valve between an inactive position allowing fluid flow through the primary channel and an active position preventing fluid flow through the primary channel. The piston arrangement further has a secondary flow channel and a bypass flow channel and inflow control elements exposed to the fluid flow upstream of the flow barrier and having different density and movable within independent paths in response to a density of fluid.