Abstract: A gas mitigation system for controlling the amount of gas that reaches a submersible pumping system deployed in a wellbore includes a well zone isolation device disposed in the wellbore between the submersible pumping system and a gas collecting region. The gas mitigation system further includes a back pressure control module and a gas vent line extending from the gas collecting region through the well zone isolation device to the back pressure control module. A liquid intake line extends from the well zone isolation device to an area of the wellbore upstream from the gas collecting region.

Abstract: A downhole tool for cyclically generating cyclical pressure waves in drilling fluids of sufficient magnitude to vibrate a drill string or coiled tubing to reduce friction between drill string or coiled tubing and a wall of an uncased or cased wellbore. A passageway through which drilling fluid flows through the tool is constricted to increase pressure of the drilling fluid while it continues to flow through the tool. A bypass around the constriction is cyclically opened by a rotary valve to increase the flow area through the tool for the drilling fluid while at the same time an axially shifting valve, shifted by a pair of rotating cams, opens to allow drilling fluid to vent to an annulus formed by the drill string or coiled tubing and a wall of the wellbore.

Abstract: A drilling choke including a choke body defining an internal region, an inlet passage, and an outlet passage, a seat extending within the outlet passage, a nose extending within the internal region and defining a recessed region, a plug extending within the recessed region, and a stem connected to the plug and extending axially therethrough, the stem defining an internal passage. The plug can be engaged with the seat to at least partially restrict fluid flow from the inlet passage to the outlet passage via the internal region. The stem and the plug are together axially moveable in opposing directions relative to the seat to thereby control a backpressure of the fluid flow. In some embodiments, the recessed region of the nose is in fluid communication with the outlet passage of the choke body via the internal passage of the stem to thereby pressure balance the plug.

Abstract: A replaceable gas lift valve system. In this system, the device is inserted into the production tubing (or gas producing zone) at a desired level. This allows gas to be pumped down the space between the casing and production tubing (or flowed from the zone). Although the tool is placed in the production tubing, space is provided to allow almost normal production through the tool. Once in place, the device has a metering valve that allows the appropriate amount of gas of other fluid to enter the production tubing to provide lift for the oil. If the device fails, it can be quickly extracted and a replacement device quickly installed. Once installed, the replacement device allows resumed production. The recovered device can be dismantled, repaired and staged for another quick replacement where needed.

Abstract: The multistage pulsating airlift pump includes a lowermost air injector stage and at least air injector stage above the lowermost stage installed in a lift pipe. Each stage includes a multifunction timer. The stages above the lowermost stage have sensors along the lift pipe communicating with the respective timers of those stages. The timers are adjusted to provide time delays in accordance with a number of parameters, e.g., the height of the pipe, pressure head, etc. When a sensor detects a rising gas slug, the sensor sends a signal to its timer to start an elapsed delay time. When the delay time has elapsed, the timer opens a control valve to send another volume of gas into the injector in the pipe. The sequentially spaced series of gas slugs rising in the pipe provide constant lifting for the liquid to a much greater height than using a single-stage airlift pump.

Abstract: The present invention relates to a system, apparatus, and method provided to selectively produce petroleum fluid from multiple production zones well. The apparatus comprises a casing running downwardly into the well and a tubing string running in the casing. The upper and lower sealing mechanisms are provided for sealing the annular space between the casing and the tubing string, therefore, dividing the well into upper and lower production zones. Moreover, the invention comprises a bypass gaslift system provided with a tubular member, tubing string, connecting means and side pocket mandrels for injecting lifting gas into the multiple production zones well. The system and apparatus according to this invention can selectively operate to simultaneously or separately produce petroleum fluid from vertical apart multiple zones well.

Abstract: A system and method for systematically and economically recovering formation liquids from the bottom of a petroleum well are disclosed. In a preferred embodiment, the system and method are passive in that they utilize the existing formation pressure of the well to remove fluid build-up across the perforations of the well bore in a manner that is completely free from surface control. The system is comprised of strategically placed carrier subs with installed pressure regulating devices. These carrier subs are regularly spaced below the production packer, along the tail pipe section of the production tubing string and facing the perforated intervals of the well bore. The pressure of the trapped formation gas above the accumulating formation liquid is insufficient to remove all of the formation liquid within the entire length of the tubing string 13.

Abstract: Gas turbine driven oil lifting device for increasing the quantity of oil obtained over a specified time (e.g. barrels per day) and the percentage of total amount obtained from oil-bearing geological deposits. The device is installed in a technical column (1) and consists of sections (12) and (18), separated by a bypass packer (11), on which a gas turbine (9) is fixed by a coupling (14) and a tubing (17) with a plurality of valves (four preferred: (3), (4), (6), and (8)) that are fixed to the gas turbine (9) by a coupling (15). Above the gas turbine (9) is a check valve (16) that is installed within the tubing (17). Parallel with the tubing (17) is a supply tube (2) of the gas turbine that is fixed by at least one coupling. The bottom end of the supply tube (2) is connected to an opening (20) at an upper head (34) of the gas turbine (9) by a flexible hose (7). The device may operate continually and periodically.

Abstract: An actuating device (1) for carrying out mechanical work by means of a slave piston rod (5) in a hydraulically-operated slave cylinder (2), where the actuating device (1) is made up of a hydraulic pump (3) integrated with a slave cylinder (2) and where the hydraulic pump (3) is driven by a linear electric motor. which consists of a pump piston (7) which is used as rotor in the linear motor at the same time as the pump piston (7) functions as a pumping piston in the hydraulic pump (3) to build up a hydraulic pressure in the slave cylinder (2).

Abstract: In accordance with an illustrative embodiment of the present invention, a side pocket mandrel includes a tubular main body having an internal bore, a seating section w4elded to one end of said main body and having a main bore and a laterally offset seating bore opening to the exterior thereof, the axis of said seating bore being inclined at a small angle toward the axis of said main bore, said seating bore having a polish section at the outer end thereof and a latch shoulder adjacent the inner end of said polish section, and a gas flow opening communicating said seating bore with said main bore at a location inwardly of said polish section. A tubular member having an orienting sleeve therein is welded to said seating section in alignment with said main bore, and a swage nipple is welded to the opposite end of said main body. All of said welds are transverse to provide a high strength and compact mandrel assembly.

Abstract: A system and method for producing earth formation fluids such as crude oil using a lighter oil to force the crude oil to the surface and thereafter removing the lighter oil by gas lift techniques. The well system includes spaced packers defining a production chamber in the well bore, a production tubing extending through the packers having check valves and ports for well fluids to flow into the chamber from below the packer while isolating the chamber from the pressure of production fluids in the production tubing. Power fluid tubing extends through the upper packer into the production chamber including spaced gas lift valves and gas flow means from the lowermost gas lift valve into the production chamber. Surface equipment is provided for pumping power fluid into the power fluid tubing string, introducing lift gas into the power fluid tubing string above the upper packer, and separating returned power fluid and lift gas.

Abstract: One or more balanced gas lift valves mounted on an oil production tube deep in a well are responsive to a remote valve control transmitter at the surface for controlling the ejection of a fluid, as a gas for example, into the production tube of oil for decreasing the specific gravity for lifting the oil and for increased production of the oil. This electronic remote controlled gas lift has fluid vent means therein for equalizing the fluid pressure on all sides and both ends thereof for reducing resistance to movement for thus requiring minimum energy for operation thereof, and for providing a highly efficient gas lift system for lifting oil in the well.

Abstract: A method for lifting oil from the bottom of a well comprises, (1) injecting a fluid of less specific gravity into the well with a fluid flow control valve, and (2) equalizing the fluid pressure on all sides thereof for making the fluid flow control valve balanced and frictionless as the fluid of less specific gravity is ejected thus requiring a minimum of energy for operation thereof for providing a highly efficient lifting of the oil in the well.

Abstract: A valve for downhole use allows flow of mud or completion fluids but closes when subjected to produced hydrocarbons. The flow through the valve is through an annular passage that features a sleeve preferably made of rubber. The passage remains open during completion operations, but when hydrocarbons are produced the rubber swells and the passage is closed off. Applications include completions involving long horizontal runs and small inside diameter laterals where access to a sliding sleeve with coiled tubing or a wireline run tool is not practical.