Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. In one embodiment, a fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. In one embodiment, the diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve.

Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system

A valve assembly for regulating fluid flow in a horizontal wellbore. A housing can be coupled to a production tubular. A chamber is defined within the housing and can be in fluid communication through a flow channel with an inner annulus formed adjacent the wellbore. A piston and a biasing member can be disposed within the chamber, where the biasing member biases the piston into a first position. A flowpath is defined within the housing and communicable with both the production tubular and the inner annulus. The flowpath can include one or more nozzles disposed therein, and the piston can be configured to move between the first position allowing fluid flow through the flowpath to the production tubular and a second position preventing fluid flow to the production tubular.

Autonomous inflow control device and methods for using same

Disclosed herein is a device for controlling flow within, e.g., a production well or an injection well. The device consists of a movable flow passage and a stationary variable choke or valve that is sensitive to flow parameters and automatically adjusts itself to provide a predetermined flow rate through the device.

Flow control systems and methods

A system for variably resisting flow of a fluid composition can include a flow passage and a set of one or more branch passages which intersect the flow passage, whereby a proportion of the fluid composition diverted from the passage to the set of branch passages varies based on at least one of a) viscosity of the fluid composition, and b) velocity of the fluid composition in the flow passage. Another variable flow resistance system can include a flow path selection device that selects which of multiple flow paths a majority of fluid flows through from the device, based on a ratio of desired fluid to undesired fluid in the fluid composition. Yet another variable flow resistance system can include a flow chamber, with a majority of the fluid composition entering the chamber in a direction which changes based on a ratio of desired fluid to undesired fluid in the fluid composition.

Flow path control based on fluid characteristics to thereby variably resist flow in a subterranean well

A variable flow resistance system for use in a subterranean well can include a flow chamber having an outlet and at least one structure which resists a change in a direction of flow of a fluid composition toward the outlet. The fluid composition may enter the chamber in the direction of flow which changes based on a ratio of desired fluid to undesired fluid in the fluid composition. Another variable flow resistance system can include a flow chamber through which a fluid composition flows, the chamber having an inlet, an outlet, and a structure which impedes a change from circular flow about the outlet to radial flow toward the outlet.

Variable flow resistance system with circulation inducing structure therein to variably resist flow in a subterranean well

Autonomous Valve, A Game Changer Of Inflow Control In Horizontal Wells.

A method for flow control and a self-adjusting valve or flow control device, in particular useful in a production pipe for producing oil and/or gas from a well in an oil and/or gas reservoir, which production pipe includes a lower drainage pipe preferably being divided into at least two sections each including one or more inflow control devices which communicates the geological production formation with the flow space of the drainage pipe. The fluid flows through an inlet (10) and further through a flow path of the control device (2) passing by a movable disc (9) or movable device which is designed to move relative to the opening of the inlet and thereby reduce or increase the flow-through area (A2) by exploiting the Bernoulli effect and stagnation pressure created over the disc (9), whereby the control device, depending on the composition of the fluid and its properties, automatically adjusts the flow of the fluid based on a pre-estimated flow design.

Method for flow control and autonomous valve or flow control device

A smart well concept with autonomous inflow control valve (AICV) is presented. AICV utilized the best from smart wells (ICV) and inflow control devices (ICD). The technology is presented, discussed and compared against other conventional inflow control technologies, id est (i.e.) passive ICD. The flow characteristics are presented and implemented in reservoir model simulations. Significant increased production and recovery are shown for the application in a thin oil rim with gas cap and heterogeneous reservoir. The AICVs are autonomous, i.e. self-regulating and do not required any external control or force. This makes them simple and robust, and a large number of control valves can be mounted in the well, i.e. one in each screen. When water and/or gas breakthrough occur the valves in the breakthrough zone will autonomously shut-off. This provides the operator with a significantly more efficient production and increased recovery. The AICV technology also enables opportunities to drill longer wells and achieve maximum reservoir contact of each well. In addition, the AICV removes the risk, cost and requirement for separation, transportation and handling of unwanted fluid. Introduction Traditionally, oil reservoirs were accessed by drilling vertical wells. This is simple and straight-forward technique, but with limited reservoir contact per well. Therefore, in order to access more reservoir contact, techniques and devices have been developed to drill horizontal wells, i.e. turning the well from vertical to horizontal oriented [1]. Multi-lateral wells have been installed by several oil companies to maximize the reservoir contact. A major challenge in oil production is to maximize the oil recovery of the reservoir. Today, only a limited part of the oil in a given reservoir is actually recovered and produced before the field is shut down. There are strong incentives for developing new technology in order to increase oil production and recovery. Two factors are of particular importance in order to increase production and recovery from a reservoir: • Obtaining maximum reservoir contact • Preventing negative effects of gas and/or water breakthrough Good reservoir contact may be achieved by drilling long horizontal and/or multi-lateral wells. The pressure drop inside the well is caused by the fluid friction within the pipe, and is proportional to flow rate, fluid density, diameter and length of the well. Hence, longer wells give increased pressure drop, and increased pressure difference between the toe and heel section of the well. This creates non-uniform oil production along the well and results in an early breakthrough in the heel section, as indicated in Figure 1. Permeability differences or heterogeneities along the well may also result in early breakthrough [2] in some parts of the well. The negative effects of breakthrough may be delayed by ICD, [3]. Well completion with ICDs consists of a large number of ICDs disposed at regular intervals along its entire length. The ICDs causes a flow restriction of the fluid flowing from the reservoir and into the well, and will make the inflow profile more uniform. The ICDs are ports having a fixed flow area. The result is a significant increase in the recovery compared with wells without ICDs [3].

Smart Well With Autonomous Inflow Control Valve Technology

The Next Generation Inflow Control, the Next Step to Increase Oil Recovery on the Norwegian Continental Shelf

A method for flow control and a self-adjusting valve or flow control device, in particular useful in a production pipe for producing oil and/or gas from a well in an oil and/or gas reservoir, which production pipe includes a lower drainage pipe prefer-ably being divided into at least two sections each including one or more inflow control devices which communicates the geological production formation with the flow space of the drainage pipe. The fluid flows through an inlet (10') and further through a flow path of the control device (2) passing by a non-disc shaped movable body (9') which is designed to move relative to the opening of the inlet and thereby reduce or increase the flow-through area (A2) by exploiting the Bernoulli effect and stagnation pressure created over the body (9'), whereby the control device, depending on the composition of the fluid and its properties, automatically adjusts the flow of the fluid based on a pre-estimated flow design.

Haavard Aakre

Papers

Autonomous Valve, A Game Changer Of Inflow Control In Horizontal Wells.

Method for flow control and autonomous valve or flow control device

Smart Well With Autonomous Inflow Control Valve Technology

The Next Generation Inflow Control, the Next Step to Increase Oil Recovery on the Norwegian Continental Shelf

Improved method for flow control and autonomous valve or flow control device