Abstract: The invention relates to an injection apparatus for injecting a chemical additive into a fluid mixture flowing in a well-bore. The invention also relates to a corresponding injection method.

Abstract: An injection apparatus for injecting an activated fluid and an activated chemical fluid mixture into a well-bore is disclosed. Then, an injection method for injecting an activated fluid into a well-bore is also disclosed. A particular application to the oilfield industry, for example in cementing operation is encompassed. The apparatus and the method of use is fully automatic.

Abstract: A method of and an apparatus for treating a near zone and/or a far zone of a well is disclosed. The method comprises the following steps. (1) A tube that is permeable to a material is placed inside a wellbore, forming an annulus inside the wellbore. (2) A setting section surrounded by a sleeve is placed inside the tube. The sleeve is expandable and impermeable to the material. (3) The sleeve is inflated so that the sleeve is in contact with the tube, ensuring for a first zone of the tube is impermeable to the material, but leaving a second zone permeable to the material. (4) A treatment fluid is pumped to the zones that passes through the second zone still permeable to the material. (5) The near zone in the annulus and/or the far zone in the surrounding formation is treated with the treatment fluid.

Abstract: The invention provides an apparatus to be lowered in a borehole, comprising: (i) a delivery section for delivering a plugging fluid; (ii) a setting section comprising a longitudinal element and a flexible and permeable sleeve into which the plugging fluid is delivered; and (iii) a disconnect mechanism to allow the delivery section to be disconnected from the setting section, characterized in that the flexible sleeve is connected by at least one floating means to the longitudinal element.

Abstract: This invention relates to a method and to a tool to consolidate a wellbore by displacing conventional cement slurry or any other settable fluid, without any permanent casing. A bladder is inflated inside the bore to act as a mold and to form an annulus that can be filled by cement slurry or any other settable fluid. When the cement or the resin is set, the form is retrieved by straight pull; leaving a cement or resin sheath to support the formation without requiring any re-dulling. The sheath can be perforated if necessary (in the producing zone).

Abstract: It is provided a tool and its operating procedure, to protect any device while lowering into a well, and especially hydraulic devices such as sensors with expandable arms or inflatable elements such as packers. The protection is mainly important in the open hole of highly deviated or horizontal wells, for any device equipped with external seal element, delicate sensor or articulated parts. This tool features an automatic sequence controlled by a single dart or a single ball launched into the running string from the surface: when the dart or the ball lands on its seat, the pressure build-up is initially applied to a piston to extract the device from the protector without exposing it to any differential pressure, then it is automatically applied to the device itself for actuation as soon as the device is entirely pulled out of the protector.

Abstract: An injection apparatus for injecting an activated fluid into a well-bore comprises a reservoir 3, 103, 203, 303 containing an activation fluid AF. The injection apparatus further comprises: a valve arrangement 2, 102, 202, 302 adapted to be coupled to a pipe 6, 106, CS1, CS3 for receiving a first fluid F1 flow, a dosing and mixing arrangement 4, 104, 204, 304 coupled to the reservoir 3, 103, 203, 303 and to the valve arrangement 2, 102, 202, 302. The valve arrangement has a rest configuration in which the injection apparatus provides a non-activated fluid mixture F1? and an activated configuration in which the injection apparatus provides an activated fluid mixture F2. The dosing and mixing arrangement comprises an engine part 31, 131, 231, 331 mechanically coupled to a pumping part 32, 132, 232, 332. The engine part runs the pumping part and the pumping part sucks the activation fluid AF of the reservoir when the valve arrangement is in the activated configuration.

Abstract: A technique for preventing mineral, mineral salt and other deposits from impeding the motion of movable components in a submerged environment. The technique allows for a movable component in a submerged environment to move freely beneath a deformable member. As the member deforms, it fractures deposition products so they do not significantly impede the path of the movable component.

Abstract: A technique for preventing mineral, mineral salt and other deposits from impeding the motion of movable components in a submerged environment. The technique allows for a movable component in a submerged environment to move freely beneath a deformable member. As the member deforms, it fractures deposition products so they do not significantly impede the path of the movable component.

Abstract: A technique for preventing mineral, mineral salt and other deposits from impeding the motion of movable components in a submerged environment. The technique allows for a movable component in a submerged environment to move freely beneath a deformable member. As the member deforms, it fractures deposition products so they do not significantly impede the path of the movable component.

Abstract: A wet-mateable electrical connector which does not use elastomer as a primary seal is provided. The wet-mateable electrical connector includes a female connector body having an internal central cavity and a female metal sealing surface at a forward end and a female contact housing disposed within the internal central cavity. The female contact housing includes a plurality of female contacts. A sliding pin is movably disposed within the internal central cavity. The wet-mateable electrical connector further includes a male contact pin which has a front end for engagement with a front end of the sliding pin. The male contact pin includes a plurality of male contacts, each of which engages with a respective one of the female contacts so as to establish an electrical connection. The male contact pin has a male metal sealing surface which sealingly engages the female sealing surface to form a metal-to-metal seal.

Abstract: In downhole apparatus for an oil well, components (26) are installed in tubes (28) received in a space defined between an outer case (20) and an inner length of cylindrical production column (24) that is eccentric relative to the case (20). Each tube (28) is fixed at one end to an interconnection box (30) that is also received in said space, and that has electrical conductors passing therethrough. The tubes (28) are fixed to the box (30) by welding, and the ends of the tubes remote from the box are closed by plugs that are welded on.

Abstract: An actuator (14) designed to remain without maintenance down a well for a prolonged period comprises at least one sealing bellows (44) and preferably a compensation bellows (46) between the well fluid and an internal chamber (30) that is full of hydraulic fluid. The bellows (44, 46) serve to make it possible either to omit dynamic elastomer gaskets altogether or at least to protect them from the well environment. The actuator (14) e.g. of the electromechanical type, can serve in particular to control a valve (12) having an opening of adjustable size. Both bellows (44, 46) are advantageously made of stainless steel. They can be mounted end-to-end or they can be quite separate.

Abstract: A flow rate control device (18) placed at the bottom of an oil well in production comprises holes (24) formed in the production tubing (16), a closure sleeve (26) suitable for sliding over the holes (24) for controlling the flow rate, and a protective sleeve (34). The protective sleeve (34) is urged by a return spring (36) into a position in which it covers a sealing gasket (32). During closure of the device (18), the two sleeves come into edge-to-edge abutment and the closure sleeve (26) pushes the protective sleeve (34) back against the return spring (36). The sealing gasket (32) is never in direct contact with the fluid in the well. Preferably, the closure sleeve (26) is mounted on the outside of the production tubing (16).

Abstract: A flow rate control device (18) placed down an oil well in production comprises holes (24) formed in the production tubing (16), a closure sleeve (26) suitable for sliding facing the holes (24), an actuator (31) disposed eccentrically relative to the tubing (16), and an intermediate part (29). The intermediate part (29) is guided on the tubing (16) in a manner such as to withstand the tilting torque due to the eccentricity of the actuator (31). A coupling (46) that is flexible except in the direction in which the sleeve is moved connects the part (29) to the closure sleeve (26) symmetrically about the axis of the tubing (16). The resulting decoupling guarantees that the sleeve (26) is self-centering, which improves the life-span of the device (18) significantly.