Schlumberger Technology Corporation

Dowell, a Division of Schlumberger Technology Corporation

Laurent E Muller

Klaus B Huber

A Glen Edwards

Joe C Hromas

Bruce W Boyle

Edward G Smith, Jr

Gary L Rytlewski

Steven L Anyan

Steven W Henderson

Bennie Gill

Larry Grigar

Ervin Randermann

Anthony P Vovers

Rolf Ludolf

James M Upchurch, Deceased

Nathan E Addicks

Well surface equipment is provided to seal around the outer surface of portions of tool sections as the tool sections are assembled or disconnected in a portion of the well surface equipment. The portion of the well surface equipment is isolated from wellhead pressure to enhance well operator control during assembly or disassembly of a tool string. Also, if a fluid path is opened up due to activation of the tool string (such as initiation of a detonating cord that is placed in the fluid path), a barrier mechanism is actuated to block fluid communication through this fluid path so that a portion of the well surface equipment can remain isolated from wellhead pressure to enable convenient retrieval and disconnection of tool sections.

Apparatus and method for inserting and retrieving a tool string through well surface equipment

A connector having a stinger and a receiver. The receiver is cocked by applying counter-acting torques to separate sections of the receiver. The counteracting torques compress a spring member. In the cocked position, the stinger is inserted into the receiver. When the counter-acting torques are released, the spring decompresses and locks the stinger in the receiver.

Connector and connection method

A completions insertion and retrieval under pressure (CIRP) apparatus utilizes a snaplock connector to assemble uphole a tool string of any desired length prior to lowering the tool string into a wellbore for performing wellbore operations in the wellbore. The tool string could comprise a perforating gun string including a plurality of perforating guns interleaved with a corresponding plurality of snaplock connectors. The CIRP apparatus includes a winch housing connected to a lubricator, the lubricator being connected to a valve, the valve being connected to a connection apparatus, such as a deployment BOP or a snaplock operator, the connection apparatus being connected to a work string which extends into the wellbore. When the valve is opened and the lubricator is pressurized, a second wellbore tool, which includes a third section of a snaplock connector, is disposed in the lubricator and a first wellbore tool, which includes a first and second section of a snaplock connector, is being held by the connection apparatus. The second wellbore tool is lowered by the winch through the lubricator into contact with the first wellbore tool, and the third section is connected to the second section of the snaplock connector. The connection apparatus releases its hold on the first wellbore apparatus, the winch lowers the second wellbore apparatus into the connection apparatus, and the connection apparatus holds the second wellbore apparatus until a third wellbore apparatus is connected to the second wellbore apparatus thereby creating a tool string. As a result, the tool string of any desired length can be build uphole before lowering the the tool string downhole for performing wellbore operations during one trip into the wellbore.

Completions insertion and retrieval under pressure (CIRP) apparatus

An apparatus for sequentially performing multiple downhole functions in a well has tubing arranged to transmit pressure conditions from the surface of the well, upper and lower hydraulically activated firing heads suspended within the well on the lower end of the tubing, and a hydraulically responsive movable member between the tubing and the firing heads. Each firing head is configured to detonate an associated tool in response to an associated elevated tubing pressure condition. The movable member transmits a first elevated pressure condition to activate one of the firing heads, and moves in response to a subsequent elevated pressure condition to activate the other firing head. In one embodiment, the movable member has a through passage for transmitting the first elevated pressure condition, the passage being subsequently blocked by a ball dropped through the tubing to move the member in response to the second elevated tubing pressure condition. In a second embodiment, the movable element is a free floating piston, with a stem which moves in response to the second elevated pressure condition. In other embodiments more than two firing heads are employed. Methods of sequentially performing multiple downhole functions in a well by such an apparatus are also disclosed.

Tubing-conveyer multiple firing head system

A downhole valve is disclosed for use in a tubing-conveyed string of tools in a well bore, constructed to be actuated to open under pressure forces by dropping a drop bar from the well surface through the tubing. The valve, deployed in the well in a closed condition, has a frangible member arranged to be broken by the drop bar to enable the valve to open. The valve opens under well pressure forces when well pressure exceeds tubing pressure, and opens under tubing pressure forces when tubing pressure exceeds or substantially equals well pressure. The valve is particularly useful when opened in conjunction with the detonation of a perforating gun for overbalanced or underbalanced well perforation. Methods of operating a string of tools including the valve are also disclosed.

Downhole tubing conveyed valve

Well completion apparatus for use under pressure and method of using same

A cable is injected into a length of coiled tubing disposed on a reel by an apparatus and method which includes attaching a small diameter pipe to the end of the coiled tubing, feeding the cable into the opposite end of the pipe through a seal and pumping a liquid into the annular space defined by the cable and the pipe at sufficient pressure and flow rate so that fluid drag on the cable overcomes the frictional force of the cable passing through the seal to inject the cable through the entire length of the coiled tubing. This method avoids the prior expensive practice of deploying coiled tubing in a straight line, either horizontally or vertically in order to feed cable through the tubing.

Method for placing cable within coiled tubing

Means for placing cable within coiled tubing

A locking apparatus which includes a rupture disc, prevents a packer from setting while being lowered into a wellbore. When the rupture disc ruptures, the packer can then set. The locking apparatus includes a locking sleeve for holding a locking dog into a locking recess in a mandrel. A drag block is locked to the mandrel as long as the locking dog is held into the locking recess of the mandrel. A packer connected to the mandrel is prevented from setting as long as the drag block is locked to the mandrel. Pressure in an annulus around the locking sleeve increases until it exceeds a predetermined threshold pressure value. When the annulus pressure exceeds the threshold pressure value, a rupture disc in the locking sleeve ruptures thereby allowing the annulus pressure to enter a chamber and move the locking sleeve away from the locking dog. When the locking sleeve moves away from the locking dog, any subsequent longitudinal movement of the mandrel moves the locking dog out of its locking recess. When the locking dog moves out of its locking recess, a sleevlet, connected to the locking dog, moves in the same direction as the locking dog thereby filling the locking recess originally occupied by the locking dog. When the sleevlet fills the locking recess, it is ratcheted in place thereby permanently filling the locking recess. When the locking recess is permanently filled, the lock is permanently removed. Therefore, the mandrel is free to move longitudinally relative to the drag block. As a result, the packer can be either set or unset simply by moving the mandrel longitudinally in the wellbore.

Locking apparatus for locking a packer setting apparatus and preventing

A new pump or injection apparatus is adapted to be connected between a pipe and a valve and is adapted to either pump well fluids from a wellbore or inject fluids into a formation traversed by the wellbore. The valve includes a full bore passage and a surrounding inlet flow channel. The new pump or injection apparatus includes an apparatus responsive to a movement of the pipe in a longitudinal direction for closing the full bore passage of the valve and opening the surrounding inlet flow channel; when the full bore passage is closed and inlet flow channel is opened, a first section rotates circumferentially in response to a circumferential rotation of the pipe; a second section reciprocates back and forth in a longitudinal direction in response to the circumferential rotation of the first section; and a third section either receives the well fluids uphole wellbore and subsequently pushes the received well fluids uphole or injects fluids in the formation traversed by the wellbore in response to the reciprocation of the second section. The full bore passage of the valve optionally enables other tools, such as drill stem test tools suspending by wireline, to pass through the pump apparatus.

Pump apparatus for pumping well fluids from a wellbore having low

A novel hydraulic set packer is set independently of the setting of two other straddle packers, the straddle packers being set by other than hydraulic means, such as by inflation or compression. If the straddle packers are set by inflation, a novel inflate deflate valve is associated with both straddle packers for providing an additional method to deflate the inflatably set straddle packer. If the straddle packers are compression set, it may be necessary to allow a top staddle packer to set only after the bottom straddle packer is already set, that is, the top straddle packer is not permitted to set when the straddle packer assembly is being pushed into a deviated/horizontal borehole or through a restriction in the borehole. Accordingly, a novel hydraulic ratchet, disposed above a bottom straddle packer on a tubing but below the top straddle packer on the tubing, will enable the top straddle packer to set only after the bottom straddle packer is already set.

Hydraulically set packer useful with independently set straddle packers

In the representative embodiment of the new and improved well bore apparatus disclosed herein, a test valve is arranged to be coupled in a pipe string for positioning in a well bore. When the test valve is arranged to be selectively operated by changes in the well annulus pressure, the apparatus of the present invention includes a first normally-open pressure reference valve that may be operated to trap well annulus pressure in a chamber on the tool body to provide a reference pressure that permits the operation of the pressure-controlled test valve. The apparatus of the invention may include a second normally-open valve which is coupled to the first valve and is operated for controlling communication through a bypass passage between the interior and exterior of the tool body. An annulus pressure responsive actuator piston coupled to the first and second valves is operated by opening a rupture disc to communicate the well annulus pressure to the actuator piston. A relief valve is included in the apparatus and arranged to prevent development of excessive squeeze or suction pressures below the packer by being opened when the fluid pressure in the tool body is less than the well annulus pressure by at least a first predetermined differential or when the fluid pressure in the tool body is greater than the well annulus bore pressure by at least a second predetermined differential.

Growing community of inventors

Stafford, TX, United States of America

Laurent E Muller