Abstract: A retrievable flow control device comprising a housing configured to sealably couple with a completion component. The housing may comprise a first port and a second port establishing a fluid pathway. The fluid pathway may regulate a fluid flow as the fluid flow passes through the fluid pathway. The housing may further comprise a coupling mechanism configured to releasably couple with a corresponding feature of the wellbore completion. The downhole flow control device may be configured to be retrievable independently of the completion component. The flow control device may comprise a check valve in the fluid pathway in order to substantially constrain the fluid flow to a single direction. In some cases, the flow control device may be configured to couple with a side pocket. In other cases, a concentric flow control device may be configured to couple with a screen base pipe, tubing, or stinger.

Abstract: A method includes providing a slurry comprising a carrier fluid and a solids mixture, and injecting said slurry in a wellbore wherein the solids mixture comprises at least two volume-averaged particle size distribution (PSD) modes, wherein a first PSD mode comprises solids having a volume-average median size at least three times larger than the volume-average median size of a second PSD mode such that a packed volume fraction (PVF) of the solids mixture exceeds 0.75.

Abstract: A completion system for use in a well includes a first completion section and a second section. The first completion section has a sand control assembly to prevent passage of particulates, a first inductive coupler portion, and a sensor positioned proximate to the sand control assembly that is electrically coupled to the first inductive coupler portion. The second section is deployable after installation of the first completion section. It includes a second inductive coupler portion to communicate with the first inductive coupler portion, to enable communication between the first completion section's sensor and another component coupled to the second section.

Abstract: A well system may be provided comprising a first primary inductive coupler configured to be communicably coupled to a surface device and a first secondary inductive coupler. The first secondary inductive coupler may be further configured to be communicably coupled to one or more completion components provided in a first portion of the well. In addition, the well system may comprise a second primary inductive coupler configured to be communicably coupled to the surface device and a second secondary induction coupler. The second secondary inductive coupler may be further configured to be communicably coupled to one or more completion components provided in a second portion of the well. The flow through at least one of the first and second portions of the well may be adjusted via at least one of the one or more completion components. A method for completing a well comprising inductive couplers may also be provided.

Abstract: Apparatus and methods for completing, treating, and/or producing a wellbore are provided. The apparatus can include a tubular body defining an inner bore, one or more injection inflow control devices, and one or more production inflow control devices. The one or more injection inflow control devices can include one or more first check valves in fluid communication with the inner bore, with each first check valve being configured to allow fluid to flow therethrough from the inner bore to a region of the wellbore, and to substantially block a reverse fluid flow therethrough. The one or more production inflow control devices can include one or more second check valves coupled to the tubular body, each second check valve being configured to allow fluid to flow therethrough from the wellbore to the inner bore and to substantially block a reverse fluid flow therethrough.

Abstract: The invention discloses a tool for use in a wellbore, comprising: a tubular elongated member; openings on the tubular member able to be close with a valve or a sleeve; swellable packers positioned between said opening on the tubular member; and a control unit; the control unit operating the valve or sleeve for fracturing a subterranean formation in a wellbore, in the stages: a. fracturing the subterranean formation through a first stage at predefined first locations; and b. fracturing the subterranean formation through a second stage at second location(s) wherein each location from the second location(s) is localized between the predefined first locations.

Abstract: A technique is provided to facilitate use of a service tool at a downhole location. The service tool has different operational configurations that can be selected and used without moving the service string.

Abstract: An apparatus that is usable with a well includes a first equipment section that includes a first inductive coupler and a second equipment section that includes a second inductive coupler. The second equipment section is adapted to be run downhole into the well after the first equipment section is run downhole into the well to engage the first equipment section. A mechanism of the apparatus indicates when the first inductive coupler is substantially aligned with the second inductive coupler.

Abstract: A retrievable flow control device comprising a housing configured to sealably couple with a completion component. The housing may comprise a first port and a second port establishing a fluid pathway. The fluid pathway may regulate a fluid flow as the fluid flow passes through the fluid pathway. The housing may further comprise a coupling mechanism configured to releasably couple with a corresponding feature of the wellbore completion. The downhole flow control device may be configured to be retrievable independently of the completion component. The flow control device may comprise a check valve in the fluid pathway in order to substantially constrain the fluid flow to a single direction. In some cases, the flow control device may be configured to couple with a side pocket. In other cases, a concentric flow control device may be configured to couple with a screen base pipe, tubing, or stinger.

Abstract: An integrated power distribution system utilizes a subsea power distribution hub that receives high voltage electricity through an umbilical from a host surface facility. The subsea power distribution hub steps down the high voltage electricity and distributes the appropriate electrical power supply to multiple components of a subsea production system (e.g., in-well pumps, subsea booster pumps, subsea processing units, subsea valves, and subsea sensors) via jumpers. The integrated subsea power distribution system can be utilize to supply electrical power to all of the required process components of the subsea production system from the in-well completion to the surface host facility.

Abstract: The method for subsea well intervention includes creating a lubricator section within the production tubing of the well. The lubricator section can then be flushed of hydrocarbons facilitating further well intervention from the open water. An intervention device that facilitates flushing production tubing that has equipment, such as electric submersible pumps, is deployed in the wellhead, for example in the valve tree.

Abstract: A control and instrumentation system utilizes a subsea data hub to establish closed loop of between subsea production system components and a surface located controller. The control and instrumentation system can be utilize to operational control all of the required process components of the subsea production system from the surface located controller.

Abstract: A technique facilitates use of a through tubing completion system run in a lateral borehole. The through tubing completion may comprise production tubing coupled to a flow control valve and one or more sensors measuring at least one characteristic of the lateral borehole. The through tubing completion also comprises a connection system which facilitates the transfer of signals between the through tubing completion extending into the lateral borehole and a surface location or other location.

Abstract: An integral polished bore assembly for use in a wellbore. The assembly includes a barrel having a polished bore; at least one no-go member positioned within the barrel; an elongated locator member having a sealing head and an end, the end extending out of the barrel; and a radial port formed through the barrel.

Abstract: A hydrostatic set module configured with a wireless trigger mechanism to allow wireless activation thereof from an oilfield surface. The trigger mechanism includes a charge for exposing the module to wellbore pressures and allowing it to behave as an intensifier for actuation of a downhole device such as a production packer. The mechanism also includes a sensor for detection of the wireless communications along with a processor for analysis thereof and to direct spending of the charge. Pressure pulse or other wireless communication forms that are suitable for the downhole environment may be transmitted from surface in a variety of different signature patterns for responsive analysis by the trigger mechanism.

Abstract: A technique that is usable with a well includes running a screen assembly and a service tool as a unit into a well and using the service tool in connection with a sand control operation. The use of the service tool in connection with the sand control operation includes operating at least one valve of the screen assembly. The technique includes withdrawing the service tool from the well after the sand control operation and running a completion into the well to operate the valve(s) of the screen after the withdrawal.

Abstract: A system for use in a wellbore is disclosed. The system may include a tube, a swell packer surrounding a portion of the tube, a first pair of plates coupled to an outer surface of the tube and positioned at a first end of the swell packer, each of the first pair of plates having a plurality of slots extending inwardly from an outer edge of the plate, the regions between slots defining petals, wherein at least one of the slots of one of the first pair of plates overlaps with at least one of the petals of the second of the first pair of plates, and a second pair of plates coupled to the outer surface of the tube and positioned at a second end of the swell packer, each of the second pair of plates having a plurality of slots extending inwardly from an outer edge of the plate, the regions between slots defining petals wherein at least one of the slots of one of the second pair of plates overlaps with at least one of the petals of the second of the second pair of plates.

Abstract: A well system may be provided comprising a first primary inductive coupler configured to be communicably coupled to a surface device and a first secondary inductive coupler. The first secondary inductive coupler may be further configured to be communicably coupled to one or more completion components provided in a first portion of the well. In addition, the well system may comprise a second primary inductive coupler configured to be communicably coupled to the surface device and a second secondary induction coupler. The second secondary inductive coupler may be further configured to be communicably coupled to one or more completion components provided in a second portion of the well. The flow through at least one of the first and second portions of the well may be adjusted via at least one of the one or more completion components. A method for completing a well comprising inductive couplers may also be provided.

Abstract: A chemical injection system directed at lower completions. The system includes a tubular stinger that is anchored within a upper region of a well but traverses into the lower completion. Thus, a platform is provided for a chemical injection line running from surface to the lower completion. As a result, chemical injection may be directed right at a sand screen and other scale prone features of lower completions.

Abstract: An intelligent completion system includes a production tubing configured for production from multiple zones in a wellbore; at least one flow control valve disposed on the production tubing for each of the multiple zones, wherein the at least one flow control valve regulates flow of a wellbore fluid into the production tubing; a chemical injection mandrel disposed on the production tubing adjacent the at least one flow control valve in the each of the multiple zones, wherein the chemical injection mandrel is connected to at least one chemical injection line for injecting one or more chemicals into the wellbore; and a control mechanism connected to the at least one flow control valve and the chemical injection mandrel such that the injection mandrel and the at least one flow control valve are operated in a coordinated manner.