An indexing valve system includes a tubular having an inner surface portion defining a passage portion, a first plurality of indexing components provided on the inner surface and a second plurality of indexing components provided on the inner surface portion. A valve sleeve is arranged in the passage portion. The valve sleeve includes a first plurality of indexing elements that selectively engage with the first plurality of indexing components, a second plurality of indexing elements that selectively engage with the second plurality of indexing components, and an inner surface section defining a passage section. The inner surface section includes a plurality of indexing step members. An insert extends into the passage section. The insert includes an outer surface supporting an indexer that selectively engages with the plurality of indexing step members to shift the valve sleeve between the first plurality of indexing components and the second plurality of indexing components.

Downhole flow control valves include a valve assembly, driven gear, drive gear, and motor. The valve assembly includes an outer sleeve and inner sleeve. The outer sleeve has openings and a fixed guide. The inner sleeve is disposed within the outer sleeve and includes an outer surface and an axially abutting surface defining a stair-stepped pathway. The fixed guide abuts against the axially abutting surface. The abutment of the fixed guide against the axially abutting surface of the inner sleeve causes the inner sleeve to translate axially between an open position and a closed position relative to the outer sleeve when rotated through operation of the motor, drive gear and driven gear. Systems for controlling fluid flow from lateral branches of a multilateral wellbore include at least a plurality of the downhole flow control valves and a downhole electrical power source for generating electrical power to operate the motor.

A method includes taking at least one image of a plurality of returned cuttings from a well using a fluorescent imaging camera, analyzing the at least one image with an imaging processing system to obtain detection data including a calculated percentage of a first emitted fluorescent light to formation cuttings, sending the detection data to an analysis and control program to correlate the returned cuttings with a depth in the well, and automatically controlling at least one drilling parameter for drilling the well based on the detection data.

An adaptive fluid switch for regulating the production rate of a fluid. The adaptive fluid switch includes a fluid control valve having a self-impinging valve element with at least one dissolvable plug configured to initially block fluid flow therethrough. After dissolution of the dissolvable plug and when the fluid produced through the adaptive fluid switch has a viscosity greater than a first predetermined level, the fluid follows a low resistance flow path in the self-impinging valve element but when the fluid has a viscosity less than a second predetermined level, the fluid follows a high resistance flow path in the self-impinging valve element, thereby regulating the production rate of the fluid responsive to changes in the viscosity of the fluid.

A downhole, interventionless system and method of controlling fluid flow from a tubular string into isolated zones of a wellbore annulus utilizing fluidic devices having different flow restriction characteristics. In an embodiment, the system includes multiple fluidic devices positioned on a work string in fluidically isolated zones of a wellbore. Each fluidic device is configured with a different flow restriction characteristic that results in a different flow rate response when a working fluid having a particular initial fluidic property is introduced into the fluidic devices. By altering the initial fluidic property of the working fluid, the flow rate from the work string into the corresponding isolated zone may be adjusted and optimally controlled without the need for additional manipulation of the fluidic devices.

A completion assembly to aid in fluid control in a multi-lateral wellbore includes a plurality of sand screen assemblies, each sand screen assembly having a wireless adjustable electronic flow control node disposed along a sand screen base pipe to control fluid flow between the sand screen assembly and the wellbore annulus. Each electronic flow control node includes a valve that can be adjusted by an electric actuator powered by a power harvesting mechanism disposed in a flow path of the completion assembly. A wireless transmitter receives a control signal to control the electric actuator, opening or closing the valve to control flow in the lateral wellbore. A wired controller in the main wellbore is disposed for transmitting wireless signals across a junction assembly in the wellbore to the sand screen assembly electronic flow control nodes.

Systems and methods include a computer-implemented method for performing an advanced control policy for a group of wells. Choke settings are applied to one or more control elements of each well in a group of wells. Rig control settings are applied to the group of wells. The rig control settings define, for each rule in a set of rules: a rule count limiting a number of times a rule is to be executed in a simulation run and a rule frequency identifying a time frequency by which the rule is to be executed during the simulation run. Settings are received for targets and constraints for the group of wells. The simulation run is executed for the group of wells using the choking settings, the rig control settings, and the settings for of the targets and constraints for the group of wells.

A resource exploration and recovery system includes a first system and a second system extending into a wellbore. The second system includes a completion having a casing defining a wellbore internal diameter. A chemical injection tubing extends from the first system into the completion. The chemical injection tubing includes a terminal end portion. A chemical introduction system is arranged at the first system and is fluidically connected to the chemical injection tubing. The chemical introduction system is operable to deliver a chemical into the chemical injection tubing. A chemical injector assembly is mounted to the terminal end portion. The chemical injection system includes an anchor and a chemical injector valve.

An apparatus can include a choke with a flow restrictor member having at least two positions, a flow coefficient Cv of the choke with the flow restrictor member in one position being less than with the flow restrictor member in the other position, and an operational device that displaces the flow restrictor member at a variable actuation rate, the actuation rate with the flow restrictor member in one position being less than with the flow restrictor in the other position. A method can include displacing a flow restrictor member, thereby decreasing a flow coefficient Cv of a choke, and decreasing a rate of change of the flow coefficient Cv in response to decreasing the flow coefficient Cv. A drilling system can include a choke with a flow restrictor member, and a continuously variable transmission which causes an actuation rate to vary based on a position of the flow restrictor member.

Apparatus, systems and methods for occupying at least part of a cavity within an item of equipment includes at least one removable insert configured to occupy at least part of the cavity without impeding movement in the cavity of any movable internal components of the equipment during normal operation thereof. Each insert may be configured to be spaced away from at least one among the cavity wall, one or more internal components of the equipment and any other inserts in the cavity and allow the flow of fluid around at least part of the insert in the cavity.