Hydraulic drive system, oil well and control method for downhole device

FIELD: oil well operation, particularly to supply power and communication signals to downhole device.

SUBSTANCE: oil well has borehole with pipe structure arranged inside the borehole, communication system performing transmission of time-varying signal along pipe structure, as well as hydraulic system electrically linked with pipe structure and adapted to be connected to downhole device, to receive power and to control downhole device. Communication system also has impedance device arranged around pipe structure to form conductive section in which signal interference is provided, wherein the signal is current. To operate downhole device working liquid pressure is increased with the use of current. Hydraulic drive system comprises electric drive for above signal receiving, which activates pump to increase working liquid pressure. Connected to pump is drive actuated by working liquid and connected to downhole device in its working position to operate the downhole device. Signal may include communication signal to selectively operate downhole device, particularly valve.

EFFECT: decreased electric power losses during signal transmission to downhole device.

26 cl, 6 dwg

 

The present invention relates in General to oil wells, and more specifically to oil wells having a communication system for power supply and communication signals in the downhole hydraulic system, which is operable connected to the downhole device to provide the downhole device.

There are several ways of placing electronic circuits, sensors or well controlled valves along the column tubing for oil production, but all of these known devices typically use an internal or external cable passing along the column tubing, for power supply and communication signals in the borehole. Of course, in practice, is highly undesirable and difficult to use cable along the column tubing, combined with the column tubing or located in the ring between the casing tubing and casing. The cable is difficult for workers drill holes during Assembly and run a string of tubing in the borehole. In addition, the cable is subjected to corrosion and severe wear due to the movement of the column tubing inside the borehole. The example downhole communication system using a cable disclosed in the application PCT/EP 97/01621.

<> In U.S. patent No. 4839644 described method and system for wireless two-way communication in a cased well having a string of tubing. However, this system describes the communication circuit to communicate the energy of electromagnetic radiation of THE type using a ring between the casing and tubing pipe. This inductive communication requires essentially non-conductive fluid, such as crude oil, in the ring between the casing and tubing pipe. Therefore, the invention described in U.S. patent No. 4839644 not widely used in practice as a schema for downhole two-way communication.

Another system for downhole connection with the use of the telemetry system of registration of pressure pulses in the mud column is described in U.S. patent No. 4648471 and 5887657. Although telemetry system of registration of pressure pulses in the mud column can be used successfully at low speeds, it has limited usefulness where require high speed data transfer or where it is undesirable to have a complex downhole telemetry equipment for registration of pressure pulses in the mud column. Other communication methods well described in the U.S. patentsâ„– 4468665, 4573675, 4739325, 5130706, 5467083, 5493288, 5576703, 5574374 and 583510. Similarly, several permanent downhole sensors and control systems described in U.S. patentâ„– 4972704, 5001675, 5134285, 5278758, 5662165, 5730219, 5934371 and 5941307.

In U.S. patent 5257663 disclosed a method of controlling the packer in the well, including the flow of current along the pipeline structure in a borehole from the surface, increasing the pressure of the working fluid using the specified current and control the disclosure of the packer using a working fluid with high blood pressure.

In other applications of the present applicant describes how the supply of electric power and communication signals in a variety of downhole devices in oil wells. In these methods, the applied operational tubing column as supply chain and casing as the return circuit for the supply and transmission of communication signals or alternative casing as the supply chain with dirt ground as the return circuit. In any configuration the electrical losses in the scheme of transmission vary greatly depending on the specific conditions for a particular borehole. The power supplied through the casing using a soil ground as the return circuit, are particularly susceptible to the loss of current. Leakage of electric current, in General, occurs through the cement finished in place the ground. The higher the conductivity of the cement and formation of the earth, the greater the loss of current when current flows through the casing string.

There is therefore a need for compensation for the loss of power that will be manifested in practice when using downhole wireless communication systems. Because these losses limit the amount of instantaneous electric power required for power, there is also a need for a system and method of storing energy for later use in downhole devices, especially in energy-intensive devices, such as gate valves, or other equipment, ensuring operational safety. Although one of the problems downhole energy storage can be solved by using the accumulation of electric charge, such as capacitors, or store energy chemically, for example in batteries, the limited lifetime of such devices makes them imperfect during the operation of oil wells.

The technical result of the present invention is to solve the problems existing in the compensation of energy loss along the path of the transmission and maintenance of working source of instant energy in the well.

According to the invention created a method of controlling a downhole device in an oil well having a wellbore, pipeline is the same structure, placed in the wellbore, which serves the current, time-varying, along the pipeline structure into the well to increase the pressure of the working fluid in the borehole using the current, time-varying control downhole device using a working fluid of high pressure and placed around the piping structure of the device impedance for the formation of a conductive section of the pipeline structure, providing a barrier to the flow of current, changing in time.

The method may include controlling an electric motor in the well and run the pump using an electric motor to increase the pressure of the working fluid.

The downhole control device may further comprise using the drive connected in working condition to the downhole device and hydraulically connected to the pump, and selective startup drive with the working fluid of high pressure to actuate the downhole device.

Selective startup drive may further comprise the use of an auxiliary valve hydraulically connected between the pump and the actuator, and adjusting the pilot valve to selectively start the drive.

The method may further comprise storing the working liquid is Ty tank and the conclusion of the working fluid from the reservoir.

The method may further comprise collecting the working fluid of high pressure in the hydraulic accumulator and selectively release the working fluid of high pressure from the accumulator to control the downhole device.

The method may further comprise collecting the working fluid of high pressure in the accumulators, actuators, connected in working condition to the downhole device and hydraulically connected to the hydraulic accumulator, the selective release of the working fluid of high pressure from the hydraulic accumulator to start the drive and, thus, control the downhole device.

Selective release of the working fluid may further comprise the use of an auxiliary valve hydraulically connected between the hydraulic accumulator and the actuator, and adjusting the pilot valve to selectively start the drive.

The method may further comprise the use of an actuator, connected in working condition to the downhole device and hydraulically connected to the pump, selective control of auxiliary valve hydraulically connected between the pump and the drive to start the drive and, thus, control the downhole device.

As a downhole device, you can use the main valve, the actuator opens and closes the main valve.

The method may further comprise collecting the working fluid of high pressure in the accumulators, actuators, connected in working condition to the downhole device and hydraulically connected to the hydraulic accumulator, selective control of auxiliary valve hydraulically connected between the hydraulic accumulator and the actuator, to start the drive and, thus, control the downhole device.

As a downhole device, you can use the main valve, and the actuator opens and closes the main valve.

According to the invention results from the oil well that contains the wellbore, pipeline structure, placed in the wellbore communication system, connected in working condition with pipeline structure for signal transmission, time-varying, along the pipeline structure and hydraulic system, electrically connected to the pipeline structure, which is adapted for connection to the downhole device and for receiving power from the signal changing in time, and to control downhole device. The communication system includes a device impedance placed around the piping structure to form a conductive area, which provides a barrier to the passage of the signal varies is located in time, representing the current.

Signal, time-varying, may include a communication signal to selectively control the downhole device.

The downhole device may be a downhole safety deflecting valve.

The hydraulic system may further comprise a motor for receiving current, time-varying, pipeline structure, a pump for selectively increasing the pressure of the working fluid is connected in operable by the motor and is able to operate with an electric motor, the actuator, hydraulically connected to the pump and operable connected to the downhole device, while the working fluid of high pressure is used to start the drive and, thus, control the downhole device.

The hydraulic system may further comprise a motor for receiving current, time-varying, pipeline structure, a pump for selectively increasing the pressure of the working fluid is connected in operable by the motor and is able to operate with an electric motor, an auxiliary valve hydraulically connected to the pump, actuator, hydraulically connected to the auxiliary valve and operable podsoednineny is to the downhole device, when this auxiliary valve adapted to selectively direct the working fluid of high pressure in the actuator and, thus, to operate the actuator and to control downhole device. The downhole device may be a valve. The hydraulic system may further comprise a motor for receiving current, time-varying, pipeline structure, a pump for selectively increasing the pressure of the working fluid is connected in operable by the motor and is able to operate with an electric motor, a hydraulic accumulator, hydraulically connected to the pump to collect the working fluid of high pressure, the actuator hydraulically connected to the auxiliary valve and operable connected to the downhole device, while the working fluid of high pressure, supplied through a hydraulic accumulator, capable of powering the actuator and, thus, to control the downhole device.

The hydraulic system may further comprise a motor for receiving current, time-varying, pipeline structure, a pump for selectively increasing the pressure of the working fluid is connected in operable by the motor and is able to operate with an electric motor, hydro is ccumulator, hydraulically connected to the pump to collect the working fluid of high pressure, an auxiliary valve hydraulically connected to the pump, actuator, hydraulically connected to the auxiliary valve and operable connected to the downhole device, while the auxiliary valve adapted to selectively direct the working fluid of high pressure in the actuator and, thus, to operate the actuator and to control downhole device.

According to the invention also created a hydraulic drive system containing an electric motor, adapted to receive a signal varying in time and fed along the pipeline structure, a pump to increase the pressure of the working fluid is connected in operable by the motor and is able to operate with an electric motor, the actuator, hydraulically connected to the pump, adapted for mounting in working condition to the downhole device, the selective actuation using a working fluid of high pressure and, thus, start the drive and control the downhole device. The system also includes a device impedance placed around the piping structure for formation of a conductive section of the pipeline structure in which on especially obstacle to the passage of the signal, time-varying representing the current, and the current, time-varying, bubbled along the conductive portion of the piping structure, surrounded by the device impedance.

Signal, time-varying, may include a communication signal to selectively control the downhole device.

The system may further comprise an auxiliary valve hydraulically connected between the pump and the actuator and adapted to selectively direct the working fluid of high pressure in the drive.

The system may further comprises a hydraulic accumulator, hydraulically connected to the pump to collect the working fluid of high pressure.

The system may further comprise a hydraulic accumulator, hydraulically connected to the pump to collect the working fluid of high pressure, an auxiliary valve hydraulically connected between the hydraulic accumulator and the actuator and adapted to selectively direct the working fluid of high pressure in the drive.

The system may further comprise a hydraulic accumulator, hydraulically connected to the pump to collect the working fluid of high pressure, an auxiliary valve hydraulically connected between the hydraulic accumulator and the actuator and adapted to selectively direct the working gigastorage pressure in the actuator, an electrically insulating sleeve placed on the pipeline structure, the device impedance is made in the form of an induction choke is placed around the piping structure, and current, time-varying, is directed along truboprovodnoi patterns between the electrically insulating coupler and the induction choke.

Other objectives and advantages of the present invention in the following detailed description with reference to the accompanying drawings, which depict the following:

figure 1 depicts a diagram of an oil well having a wireless communications system and the hydraulic system according to the present invention;

figure 2 depicts the scheme for an offshore oil well with a wireless communications system and the hydraulic system according to the present invention;

figure 3 shows in enlarged scale a diagram of the pipeline structure of the oil wells that have increased manifold, placed in a hydraulic system according to the present invention;

figure 4 depicts the electrical and plumbing diagram of the hydraulic system, shown in figure 3;

figure 5 shows in enlarged scale a diagram of the pipeline structure of the oil wells that have increased manifold, placed in a hydraulic control system according to the alternatives to the WMD option of implementing the present invention;

6 depicts a circuit diagram of a hydraulic control system is shown in figure 5.

The term "pipeline structure, which is used in this application, may be a single pipe, tubing pipe, casing borehole, pump rod, a series of interconnected tubes, rods, metal truss, grid through a farm, support, idler or lateral extension drill hole, a network of interconnected pipes or other structures known in the art. In a preferred embodiment, the invention is used in the context of oil wells where the pipeline structure comprises a tubular, metallic, electrically conductive tube or column tubing, but the invention is not limited to this. For the present invention, at least part of the pipeline structure must be electrically conductive, such conductive part can be a overall pipeline structure (for example, steel pipes, copper pipes) or passing in the longitudinal direction of the conductive part, combined with passing in the longitudinal direction of the electroconductive part. In other words, the conductive piping structure is a structure that provides a current path from the real the plot, where the power source is electrically connected to another segment, and the device and/or circuit reverse current are electrically connected. The pipeline structure is usually a well-known round metal tubing column, but the geometry of the cross-section of the pipeline structure or any part thereof may vary in shape (e.g. round, rectangular, square, oval) and the size (e.g. length, diameter, wall thickness) along any part of the pipeline structure.

The term "valve" refers to any device that performs the function of adjusting the flow of fluid. Examples of valves include, but are not limited to, bellows-type gas-lift valves and controllable gas-lift valves, each of which can be used to regulate the flow of carrier gas in the column tubing drilling wells.

Internal valves can greatly differ, and in the present application is not limited to the valves described with any particular configuration as long as the valve acts as a flow control. Some of the various types of flow control include, but are not limited to, the configuration of a ball valve, the configuration of the needle valve, the configuration of the shutoff valve and configuration cleavag the valve. The valves are usually divided into two classes: control valves, designed only for full opening or full closing, the intermediate position of the considered transition. The last class of valves can be used to protect personnel or equipment during preventive maintenance and repair, or may form part of a system emergency stop drill hole, in which case they must be able to work quickly and without long training. Subsurface safety valves are an example of this type of valve. The valves can be installed in a downhole location in a borehole in a variety of ways, some of which include installation configuration with floating tubing column, the configuration of the mandrel for removable valve or permanent installation configuration, such as installing a valve in the advanced collector tubing string.

The term "modem" is used here to refer to any communication device for transmitting and/or receiving electrical communication signals through an electrical conductor (e.g. metal). Therefore, the term "modem"that is used here is not limited to the acronym for modulator device that converts goal is with or the data signal to mind suitable for transmission)/demodulator device, which restores the original signal, which was modulated high frequency carrier). In addition, the term "modem"that is used here is not restricted to the well-known computer modems, which convert digital signals to analog signals and Vice versa (for example, for the transmission of digital information signals on the analog public switched telephone network of General use). For example, if the sensor outputs measurement data in an analog format, such measurements can only be modulated (for example, using modulation with expansion of the range) and to transmit, and therefore do not need to perform analog-to-digital conversion. As another example, relay/slave modem or communications device only needs to identify, filter, amplify and/or to relay the received signal.

The term "processor" is used in this application to refer to any device that allows you to perform arithmetic and/or logical operations. The processor may further include a control unit, memory, arithmetical and logical unit.

The term "sensor"as used in this application, refers to any device that detects, identifies, controls, record which indicates or in other words, registers the absolute value or change the value of a physical quantity. The sensors described in this application can be used to measure temperature, pressure (absolute or differential), flow velocity and seismic data, acoustic data, pH, salinity levels, valve, or other physical data.

The term "wireless"as used in this application, means the absence of a known, insulated electric wires, for example, passing from downhole devices to the surface. The use of tubing of the column and/or casing as a conductor is considered as "wireless".

The term "electronic unit" in this application refers to the control device. Electronic components can exist in many configurations and can be installed in the location of the well in a variety of ways. In one configuration the installation of the electronic unit is actually located inside the valve provides control of the motor inside the valve. Electronic components can also be installed outside of any particular valve. Some electronic components will be installed inside the frame for a removable valve or extended pockets tubing the RUB, although other can be permanently attached to the tubing string. Electronic components are often electrically connected to the sensors and help in the transmission of information from the sensor to the surface of the well. It is likely that the sensors associated with the specific electronic unit can even be mounted inside the electronic unit. And, finally, the electronic unit is often closely associated with, and may actually contain a modem for receiving, transmitting and relaying communication signals from and to the surface of the borehole. Signals that take from the surface by means of the electronic unit, often used to implement changes within well managed devices, such as valves. The signals sent or relayed to the surface by means of the electronic unit, usually contain information concerning the physical conditions in the borehole, is transmitted by sensors.

Similarly, in accordance with known terminology used in the practice of the oil industry, the definition of "top", "bottom", "up the wellbore" and "well"as used herein are relative and relate to the distance measured along the borehole depth from the surface, which in inclined or horizontal wells may or may not coincide with the vertical projection, as measured by the to compared to observational data.

1 shows an oil well 10 according to the present invention. Oil well 10 includes a barrel 11 wells, passing from the surface 12 in the operational zone 14 located in the well. Operational platform 20 is located on the surface 12 and includes the suspension 22 to support the casing 24 and columns 26 of tubing. The type of casing 24 is such that is commonly used in the oil and gas industry. Casing 24 is typically installed in sections and cement in the wellbore 11 wells during completionwell. Column 26 of tubing, also called operational tubing column, in General, known and contains many elongated tubular pipe sections connected together by threaded connections at each end of the pipe sections. Operational platform 20 also includes a throttle valve 30 for gas supply, which allows you to feed compressed gas in the annular space 31 between the casing 24 and the column 26 of tubing. Conversely, the outlet valve 32 allows the oil and gas bubbles from the inner part of the column 26 of tubing during oil production.

Oil well 10 includes a system 34 connection for power supply and two-way communication in octopole the situation well in a borehole 10. System 34 connection includes a lower induction choke 42, which is mounted on the column 26 of tubing and acts as a serial impedance for flowing electric current. The size and material of the lower induction choke 42 can be modified to change the value of the serial impedance, however, the lower induction choke 42 is made of a ferromagnetic material. Induction choke 42 is installed concentrically with and outside the column 26 of pump-compressor pipes and usually impregnated with epoxy resin to withstand rougher handling.

Insulating coupling 40 for tubing (also called dielectric coupling) is placed on the column 26 of tubing near the surface of the borehole. Insulating coupling 40 for tubing along with lower induction choke 42 provides electrical isolation for plot columns 26 of tubing located between the insulating coupling 40 for tubing and induction choke 42. Plot columns 26 of tubing located between the insulating coupling 40 for tubing and induction throttle is m 42, can be viewed as a path for power supply and communication signals. In the alternative, or in addition to insulating the coupling 40 to the tubing of the upper induction choke (not shown) can be placed around the column 26 of tubing or you can use an isolating suspension tubing (not shown).

The block 44 of the computer and power source, including a source 46 of the power device 48 spread spectrum communications (e.g., modem), is located on the outside of the barrel 11 wells on the surface 12. The block 44 of the computer and a power source electrically connected to the column 26 of tubing below the insulating coupling 40 for tubing for applying current, time-varying, in column 26 of tubing. Circuit reverse voltage to ensure power is supplied to the casing 24. In the process column 26 of tubing used as a conductor, has a fairly large losses due to the great length, occurring frequently in practice, columns, tubing, along which the feed current. However, the method of spread spectrum communications allows the presence of noise and low signal levels and can work effectively even at high loss -100 dB.

How electric the isolation area of the column tubing, which is depicted in figure 1, is not the only way to supply power and communication signals in the downhole location. In a preferred embodiment, (1) power and communication signals fed to the column 26 of tubing, while the circuit of the reverse current is provided through the casing 24. In addition, the circuit of the reverse current can be performed using the ground. The electrical connection to ground can be performed by passing the wires through the casing 24 or the wire connection to the column tubing below the bottom of the throttle 42 (if the lower part of the column tubing was grounded).

An alternate way to supply power and communication signals can be performed with the help of the casing 24. In a configuration similar to the one used in column 26 of the tubing, the casing string 24 may be electrically isolated for telemetry backbone network for power supply and transmission of communication signals in the borehole. If induction chokes were used for isolation of the casing 24, the chokes were concentrically arranged around the outer side of the casing. Instead of using the choke casing 24 can be used electrically insulated connectors of podobn the e insulating coupling 40 for tubing. In the variants of implementation, which is used casing 24 for power supply and communication signals in the borehole, the circuit of the reverse current can be run through the column 26 of tubing or through the earth ground.

Packer 49 is placed inside the casing 24 below the lower induction choke 42. Packer 49 is located above the operating zone 14 and serves to isolate the operational zone 14 for electrical connection of the metal columns 26 of tubing to the metal casing 24. Typically, the electrical connections between the column 26 of tubing and casing 24 is not allowed to transmit electrical signals or to take them up and down the shaft 11 wells using columns 26 of tubing as one conductor and the casing 24 as another Explorer. However, the combination of an insulating coupling 40 for tubing and the lower induction choke 42 forms an electrically isolated section of the column 26 of tubing that allows the system and method of power supply and communication signals up and down a borehole 11 oil wells 10.

Figure 2 shows the offshore oil bore 60.

Oil well 60 includes exploitatio the ing the platform 62 on the surface 63 of the water, anchored on earth day with 64 elements 66 support. Oil well 60 has many similarities with the oil well 10 (figure 1). The barrel 11 wells 60 begins at the bottom 64. Casing 24 is placed in the barrel 11 of the well, and the suspension 22 tubing column provides downhole support columns 26 of tubing. One major difference between the oil well 10 and the oil hole 60 is that the column 26 of tubing in an oil well 60 67 passes through a water before it reaches the barrel 11 of the well.

Induction choke 42 is placed on the column 26 of tubing a little above the mouth of the 68 wells on the bottom 64. Insulating coupling for tubing (similar insulating coupling 40 for tubing, but not shown) made in the casing 26 of tubing on the operating platform 62. Current, time-varying, served in the plot column 26 of tubing between the insulating coupling for tubing and induction choke 42 to provide power and communications in the mouth 68 of the well.

Specialists will be clear that under normal conditions short circuit will occur for the current that passes along the column 26 is asono tubing, because the column tubing is surrounded by a conductive sea water. However, the corrosion-resistant coating on the column 26 of tubing is normally non-conductive and forms an electrically insulating the "envelope" around the column tubing, thus ensuring the flow of current even when the column 26 of tubing immersed in water. In alternative accommodation meals can be enjoyed in the mouth 68 of the well using a stand-alone cable (not shown) and then submit into the well in the same manner performed in an oil well 10. In this arrangement the insulating coupling for tubing and induction choke 42 will be placed in the barrel 11 oil wells 60.

As shown in figure 2, and figures 1 and 3, the hydraulic system 70 provides the downhole device or the target device (not shown). The hydraulic system 70 is located within the extended manifold 72 on the column 26 of tubing. Figure 3 downhole device is a shut-off valve 74, however, the hydraulic system 70 allows you to operate many different downhole devices. The shutoff valve 74 sequentially driven by the working fluid for the hydraulic system pressure to the Torah is raised by a pump 76. The motor 78 is activated by a current varying in time, which is served along the column 26 of tubing. The motor 78 operable connected to the pump 76 to start the pump 76. The motor 78, resulting in the hydraulic pump 76, has a small power consumption, so it can work with limited power, which is available at a depth in the borehole. With appropriate design of the hydraulic pump 76 and other elements of the hydraulic system 70, especially in the design of the seals that minimize leakage of the working fluid for the hydraulic system in these elements, the low amount of available power does not limit the hydraulic pressure that can be obtained, but rather limits the flow rate of the working fluid for the hydraulic system.

Figure 4 shows in more detail piping and electrical connections for the hydraulic system 70. In addition to the pump 76 and motor 78 hydraulic system 70 includes nutrient reservoir 80, the auxiliary valve 82, the actuator 84 of the valve and the necessary plumbing and hardware for feeding the working fluid between these elements. The tank 80 is hydraulically connected to the pump 76 for feeding the working fluid into the pump 76. Auxiliary valve 82 of hydraulic the key is connected to the pump 76, the actuator 84 and the reservoir 80. Auxiliary valve 82 selectively directs the working fluid under pressure in the actuator 84 to actuate the actuator 84. The actuator 84 includes a piston 86 having a first side 87 and the second side 88. The piston 86 is operable connected to the valve 74 for opening and closing valve 74. In a selective direction of working fluid under pressure to opposite sides of the piston 86, the valve 74 may selectively open or close. For example, in one configuration, the working fluid can be directed into the chamber just above the first side 87 of the piston 86. Fluid under pressure will exert a force on the piston 86, causing the piston 86 to move downward, thus closing the valve 74. The fluid in the chamber, adjacent the second side 88 of the piston 86 will be moved to the tank 80. In this configuration, the valve 74 may be opened by adjusting the pilot valve 82 so that the working fluid under pressure is supplied to the chamber next to the second side 88 of the piston 86. Fluid under pressure will be pushing up on the piston 86, thereby moving the piston 86 up and opening the valve 74. Superseded the working fluid in the chamber, located near the front side 87, will be directed into the tank 80.

As mentioned previously, the electric current is supplied to the motor 78 along the column 26 is asono tubing. Modem 89 placed within the extended manifold 72 for receiving signals from the modem 48 to the surface 12. Modem 89 is electrically connected to the controller 90 to control the operation of the motor 78. The controller 90 is also electrically connected to the auxiliary valve 82 to control the operation of the pilot valve, thus ensuring the correct operation of the valve, which directs the working fluid from the pump 76 in the actuator 84 and the reservoir 80.

In the process, electric current is fed into the borehole along the column 26 of tubing in the modem 89. The controller 90 receives commands from the modem 89 and directs power to the motor 78. The controller 90 also sets the settings for the auxiliary valve 82, so that the working fluid is properly directed throughout the hydraulic system 70. After turning on the electric motor 78 he actuates the pump 76, which displays the working fluid under pressure from the tank 80. The pump 76 is putting pressure on the working fluid, pushing the fluid in the auxiliary valve 82. Of the auxiliary valve 82, the fluid under pressure is selectively directed to one side of the piston 86 to actuate the actuator 84. Depending on the side of the piston 86, which was filed with the fluid, the valve 74 is opened or closed. When you move porn the 86 superseded the working fluid is directed from the actuator 84 in the tank 80.

The hydraulic system 70 may also include a compensator 92 pressure in the bottom hole (figure 3) to equalize the static pressure of the closed fluid flow to the hydraulic system with the static pressure of well fluid in a borehole. The use of pressure compensator minimizes the differential pressure on opposite sides of any rotating or sliding seals between the hydraulic circuit and the borehole fluids, if these seals are present in the design, and thus minimize stress on these seals.

When filling the oil-extended collector 72, the pressure in it is balanced by the pressure of any fluid present in the annular space 31. Transferring one side of the pressure compensator 92 on the outer side of the manifold 72, the pressure oil within the extended manifold 72 may be the same fluid pressure within the annular space 31. Adjusting the pressure inside the reservoir enables more efficient operation of many of the elements of the hydraulic system 70.

Figure 5 and 6 shows an additional variant of implementation of the hydraulic system 70. The elements of this hydraulic system is essentially similar to that shown in figure 3 and 4. However, in this particular embodiment, is sushestvennee accumulator 96 hydraulically connected between the pump 76 and the auxiliary valve 82 for collecting the working fluid of high pressure for hydraulic system supplied by a pump 76. The hydraulic control system 70 is identical to the previously described except that the accumulator 96 is now used for feeding the working fluid of high pressure to the hydraulic system in the actuator 84. Hydraulic accumulator 96 is used to periodically perform promptly hydraulic operation (for example, the rapid opening or closing of the valve). This differs from the previous version of the implementation, which used the pump for a gradual supply of the working fluid of high pressure for hydraulic system actuator 84.

Hydraulic accumulator 96 includes a piston 98, densely situated slidable inside the housing and move in the same direction by means of a spring 100. The hole 102 of the compensator is located in the housing and allows oil under pressure within the extended manifold 72 to provide additional force on the piston 98, which is added to the force created by the spring 100. The motor 78 and the pump 76 is created in the hydraulic accumulator 96 high pressure due to the supply of the working fluid of high pressure to the hydraulic system in the main chamber 104 opposite the offset of the piston 98. When the force provided by the working fluid of the hydraulic system inside the main chamber 104, is equal to the efforts on the opposite side of the piston 98, the us is with 76 stops working and the working fluid of the hydraulic system is accumulated within the accumulator 96 to until it is needed.

Accumulated operating fluid of the hydraulic system high pressure are produced under the control of the pilot valve 82 to operate the actuator 84 and thus to actuate the main valve 74. Thanks to the energy accumulated in the accumulator 96, the valve 74 may be opened or closed immediately after receiving a command for opening or closing. The size of the accumulator 96 is selected such as to provide at least one full cycle (opening or closing) of the valve 74. Thus, the methods of the present invention provide for the successful operation of the valves that require short-term feeding of high power, such as subsurface safety valves.

It is clear that a variety of hydraulic devices can be replaced by a shut-off valve 74, which has been described for illustrative purposes only. It should be also clear that the system 34 communication and hydraulic system 70, made using the present invention, although located on the column 26 of tubing in the preceding description, can be located on the casing 24 borehole or any other pipeline structure associated with drilling a well.

is even if many of the examples discussed herein are applications of the present invention in oil wells, the present invention can also be applied in other types of wells, including, but not limited to, water wells, and wells for the extraction of natural gas.

Specialists will be clear that the present invention can be applied in many areas where there is a need in the communication system and the hydraulic system inside the borehole, borehole or any other hard-to-reach area. In addition, experts will be clear that the present invention can be applied in many areas where there is already a conductive piping structure and the need for power supply and communication signals in a hydraulic system located near the pipeline structure. Water sprinkler system or network in a building for fire fighting is an example of a pipeline structure that already exists and may be the same or similar way, which is necessary to select the direction of the path of power supply and communication signals in the hydraulic system. In this case, as the return circuit, you can use a different pipeline structure or other part of the same pipeline structure. Steel structure building can also be used in which the quality of the piping structure and/or the return circuit for power supply and transmission of communication signals in the hydraulic system according to the present invention. Steel reinforcement in concrete dam or on the street can be used as a piping structure and/or the return circuit for power supply and transmission of communication signals in the hydraulic system according to the present invention. A transmission line and a network of pipelines between the wells or through large sections of the earth can be used as a piping structure and/or the return circuit for power supply and transmission of communication signals in the hydraulic system according to the present invention. Surface network of pipelines to a refinery can be used as a piping structure and/or the return circuit for power supply and transmission of communication signals in the hydraulic system according to the present invention. Thus, there are numerous applications of the present invention in many different areas or fields of application.

From the foregoing it is clear that the invention has significant advantages. Although the invention shows only a few of its forms, it is not limited and susceptible to various changes and modifications without deviating from the essence.

1. The method of controlling a downhole device in an oil well having a wellbore and pipeline structure, placed in the wellbore, the ri serving the current time-varying, along the pipeline structure into the well to increase the pressure of the working fluid in the borehole using the current, time-varying control downhole device using a working fluid of high pressure, characterized in that place around the pipeline structure of the device impedance for the formation of a conductive section of the pipeline structure, which provides a barrier to the flow of current, changing in time.

2. The method according to claim 1, characterized in that it contains the control motor in the well and run the pump using an electric motor to increase the pressure of the working fluid.

3. The method according to claim 2, characterized in that the control of the downhole device further comprises using an actuator, connected in working condition to the downhole device and hydraulically connected to the pump, and selective startup drive with the working fluid of high pressure to actuate the downhole device.

4. The method according to claim 3, characterized in that the selective startup drive further comprises the use of an auxiliary valve hydraulically connected between the pump and the actuator, and adjusting the pilot valve to selectively start the drive.

5. SPO is about according to claim 1, characterized in that it further comprises storing the working fluid in the tank and the conclusion of the working fluid from the reservoir.

6. The method according to claim 1, characterized in that it further comprises collecting the working fluid of high pressure in the hydraulic accumulator and selectively release the working fluid of high pressure from the accumulator to control the downhole device.

7. The method according to claim 1, characterized in that it further comprises collecting the working fluid of high pressure in the accumulators, actuators, connected in working condition to the downhole device and hydraulically connected to the hydraulic accumulator, the selective release of the working fluid of high pressure from the hydraulic accumulator to start the drive and, thus, control the downhole device.

8. The method according to claim 7, characterized in that the selective release of the working fluid further comprises the use of an auxiliary valve hydraulically connected between the hydraulic accumulator and the actuator, and adjusting the pilot valve to selectively start the drive.

9. The method according to claim 1, characterized in that it further comprises using an actuator, connected in working condition to the downhole device and hydraulically connected to the pump, selective control auxil telnum valve, hydraulically connected between the pump and the drive to start the drive and, thus, control the downhole device.

10. The method according to p. 9, characterized in that the downhole device using the main valve and the actuator opens and closes the main valve.

11. The method according to claim 1, characterized in that it further comprises collecting the working fluid of high pressure in the accumulators, actuators, connected in working condition to the downhole device and hydraulically connected to the hydraulic accumulator, selective control of auxiliary valve hydraulically connected between the hydraulic accumulator and the actuator, to start the drive and, thus, control the downhole device.

12. The method according to claim 11, characterized in that the downhole device using the main valve and the actuator opens and closes the main valve.

13. Oil well that contains the wellbore, pipeline structure, placed in the wellbore communication system, connected in working condition with pipeline structure for signal transmission, time-varying, along the pipeline structure and hydraulic system, electrically connected to the pipeline structure, which is adapted for connection to a downhole device, etc the EMA power of the signal, time-varying, and the downhole control device, characterized in that the communication system contains a device impedance placed around the piping structure to form a conductive area, which provides a barrier to the passage of the signal, time-varying, representing the current.

14. Oil well according to item 13, in which the signal is varying in time, includes the communication signal to selectively control the downhole device.

15. Oil well according to item 13, in which the downhole device is a downhole safety deflecting valve.

16. Oil well according to item 13, in which the hydraulic system further comprises a motor for receiving current, time-varying, pipeline structure, a pump for selectively increasing the pressure of the working fluid is connected in operable by the motor and is able to operate with an electric motor, the actuator, hydraulically connected to the pump and operable connected to the downhole device, while the working fluid of high pressure is used to start the drive and, thus, control the downhole device.

17. Oil well according to item 13, in which the hydraulic system further comprises ele is tradigital for receiving current, time-varying, pipeline structure, a pump for selectively increasing the pressure of the working fluid is connected in operable by the motor and is able to operate with an electric motor, an auxiliary valve hydraulically connected to the pump, actuator, hydraulically connected to the auxiliary valve and operable connected to the downhole device, while the auxiliary valve adapted to selectively direct the working fluid of high pressure in the actuator and, thus, to operate the actuator and to control downhole device.

18. Oil well at 17, in which the downhole device is a valve.

19. Oil well according to item 13, in which the hydraulic system further comprises a motor for receiving current, time-varying, pipeline structure, a pump for selectively increasing the pressure of the working fluid is connected in operable by the motor and is able to operate with an electric motor, a hydraulic accumulator, hydraulically connected to the pump to collect the working fluid of high pressure, the actuator hydraulically connected to the auxiliary valve and operable connected to the downhole device, while working the I fluid of high pressure, supplied with a hydraulic accumulator, capable of powering the actuator and, thus, to control the downhole device.

20. Oil well according to item 13, in which the hydraulic system further comprises a motor for receiving current, time-varying, pipeline structure, a pump for selectively increasing the pressure of the working fluid is connected in operable by the motor and is able to operate with an electric motor, a hydraulic accumulator, hydraulically connected to the pump to collect the working fluid of high pressure, an auxiliary valve hydraulically connected to the pump, actuator, hydraulically connected to the auxiliary valve and operable connected to the downhole device, while the auxiliary valve adapted to selectively direct the working fluid of high pressure in the actuator so way to start the actuator and to control downhole device.

21. The hydraulic drive system containing an electric motor, adapted to receive a signal varying in time and fed along the pipeline structure, a pump to increase the pressure of the working fluid is connected in operable by the motor and is able to operate with ele is tradigital, the actuator hydraulically connected to the pump, adapted for mounting in working condition to the downhole device, the selective actuation using a working fluid of high pressure and, thus, start the drive and control downhole device, characterized in that it contains the device impedance placed around the piping structure for formation of a conductive section of the pipeline structure, which provides a barrier to the passage of the signal, time-varying, which represents the current, and the current, time-varying, bubbled along the conductive portion of the piping structure, surrounded by the device impedance.

22. The hydraulic drive system according to item 21, wherein the signal changing in time, includes the communication signal to selectively control the downhole device.

23. The hydraulic drive system according to item 21, characterized in that it further comprises an auxiliary valve hydraulically connected between the pump and the actuator and adapted to selectively direct the working fluid of high pressure in the drive.

24. The hydraulic drive system according to item 21, characterized in that it further comprises a hydraulic accumulator, hydraulically connected to the pump to collect R is the working fluid of high pressure.

25. The hydraulic drive system according to item 21, characterized in that it further comprises a hydraulic accumulator, hydraulically connected to the pump to collect the working fluid of high pressure, an auxiliary valve hydraulically connected between the hydraulic accumulator and the actuator and adapted to selectively direct the working fluid of high pressure in the drive.

26. The hydraulic drive system according to item 21, characterized in that it further comprises a hydraulic accumulator, hydraulically connected to the pump to collect the working fluid of high pressure, an auxiliary valve hydraulically connected between the hydraulic accumulator and the actuator and adapted to selectively direct the working fluid of high pressure in the actuator, an electrically insulating sleeve placed on the pipeline structure, the device impedance is made in the form of an induction choke is placed around the piping structure, and current, time-varying, is directed along the piping structure between the electrically insulating coupler and the induction choke.



 

Same patents:

FIELD: oil industry, particularly to supply and store power necessary for downhole device and appliance operation in oil well.

SUBSTANCE: power supply system has current impedance device arranged around borehole pipeline structure and adapted for at least partial defining supply part to transfer alternate current through and along conductive pipeline structure part. System also has power storing device adapted to be electrically connected to conductive pipeline structure part, to be discharged with alternate current and to be linked with downhole device so supply power thereto. Embodiments of oil well structure including above system are also disclosed, as well as oil well operation method and power supply method with the use of the described system.

EFFECT: improved stability of power supply to downhole devices and appliances.

37 cl, 8 dwg

FIELD: oil production industry, particularly to perform fluid flow control during oil extraction process.

SUBSTANCE: well has casing pipe with a plurality of perforated sections and production string located inside casing pipe. Alternating current source electrically linked with at least one of casing pipe and production string is located on ground surface and serve to conduct alternating current from ground surface into well through casing pipe or production string. Controlled well section is also provided. Controlled well section includes communication and control unit electrically linked with at least one of casing pipe and production string and having sensing means and electrically operated valve connected thereto. Communication and control unit is adapted to regulate flow between outer and inner production string parts at least partly in accordance with sensing means measurements. To extract oil a number of controlled well sections are provided. Some controlled well sections have flow limiter retarders located around production string part to prevent fluid flow between controlled well sections. Fluid characteristic is measured in each controlled well section and fluid flow is regulated on the base of performed measurements at least in one controlled well section with the use of valves. Then oil is extracted from well through production string. Fluid injection is performed along with control fluid flow from inner production string part to outer one with the use of above method, wherein each controlled well section is provided with above flow retarder. Packer or electrically operated packer comprising electrically operated valve or expanded production string part or sleeve located around production string in perforated casing pipe section may be used as the flow retarder. Flow, pressure or fluid density transducers or acoustic signal converter may be used as the sensing means.

EFFECT: provision of dynamic oil extraction process control for optimization thereof.

32 cl, 6 dwg, 3 ex

FIELD: oil producing industry; testing facilities.

SUBSTANCE: invention relates to pumping facilities. Proposed ejector multifunctional formation tester has mechanical or hydromechanical packer installed on tubing string for fixed positioning in released state in well at preset depth, jet pump accommodating nozzle and mixing chamber with diffuser in its housing, and stepped through channel is made with possibility of fitting functional inserts, for instance, functional insert for recording pressure built up curve. Jet pump is located in casing string over well producing formations, self-contained logging complex is installed lower than packer on tubing string for measuring, for instance, specific electric resistance of rock or for action onto formation by physical fields, for instance, acoustic fields, and second additional packer is installed being made of elastic material in form of open-top cup with conical side wall. Cup bottom is hermetically secured on tubing string, and ring is arranged on rubbing string lower than additional packer for centering packer in casing string, distance between packers being not less than outer diameter of tubing string in place of mounting of additional packer. Thanks to it intensification of investigation and testing of wells with open or cased hole, primarily crooked or horizontal ones, optimization of arrangement of packers at their operation together with jet pump and self-contained logging complex are provided.

EFFECT: improved reliability of operation of well jet plant.

2 cl, 1 dwg

FIELD: oil producing industry; pump facilities.

SUBSTANCE: according to proposed method, the following devices are mounted on tubing string in turn from top to bottom: jet pump, upper mechanical packer, lower packer made of elastic material, centering ring, and, on lower end of tubing string with perforated section, self-contained logging complex is installed and said assembly is lowered into on tubing string. In process of lowering, recording of background values of rock physical fields is done and when self-contained logging complex reaches design depth, upper mechanical packer is released and functional insert is installed in stepped through channel of jet pump to record pressure built up curves and then, by delivering liquid medium into nozzle of jet pump, at least three step rising values of drawdowns are built in underpacker zone and by measuring amounts of pumped out liquid on surface during each down, yields are found, and then drawdowns are built additionally and rock physical fields are recorded by self-contained logging complex.

EFFECT: improved reliability and increased capacity at investigation and testing of formations in wells with walls not strengthened by casing string, improved accuracy of geological-field information at earlier stages of well building.

2 cl, 3 dwg

FIELD: oil producing jet units.

SUBSTANCE: proposed formation tester contains jet pump, unit for connecting and disconnecting tubing string, valve unit with seat for valve insert with check valve, packer and liner with intake funnel, all mounted on tubing string from top to bottom. Jet pump housing accommodates coaxially installed active nozzle and mixing chamber, and channels are made to deliver active medium, pumped out of well and stepped through channel with seat between steps. Possibility is provided for in-turn mounting of sealing unit and interlock insert with through channel which are arranged on flexible smooth pipe higher than tip for connecting self-contained logging complex and insert for recording pressure built-up curves I underpacker space of well under which self-contained instruments are installed for recording pressure, temperature and other physical parameters of well and forming fluids. Invention provides intensification of investigation, testing and preparation of wells, mainly, horizontal and high curvature wells, optimization of operation of jet pump used together with self-contained logging complex and other functional insets for investigation of producing formation.

EFFECT: improved reliability and increased capacity of operation.

3 cl, 3 dwg

FIELD: oil producing industry; pump facilities.

SUBSTANCE: method comes to mounting the following device onto tubing string: pump with through channel, packer and liner with intake funnel, lowering the assembly into well, releasing the packer and creating required drawdown in underpacker zone by pumping liquid medium out of underpacker zone by jet pump. Assembly is furnished additionally with unit for disconnecting and connecting tubing string, and valve unit with seat for mounting check valve, and then tubing string is assembled in definite sequence. After these operation, investigation, testing and completion of well are carried out. Then well is set in operation.

EFFECT: intensified investigation, testing and completion of horizontal crooked wells, improved reliability of formation tester.

2 cl, 3 dwg

FIELD: mining industry.

SUBSTANCE: system has first induction throttle, second induction throttle and controlled switch. Second induction throttle is positioned near second branch of pipeline structure. Controlled switch has two outputs. First switch output is electrically connected to pipeline structure on the side of induction throttles connection, where first and second branches of pipeline structure intersect. Second output of switch is electrically connected to pipeline structure on other side of at least one induction throttle. Pipeline structure can be positioned inside oil well, and can have casing string and operation tubing column. Also described is method for extracting oil products from oil well using said system.

EFFECT: higher efficiency.

4 cl, 10 dwg

FIELD: oil industry.

SUBSTANCE: at least one acoustic dynamic is mounted immediately on product pipe in oil well and acoustic characteristic of flowing environment flow is determined in product pipe. It is sent into surface controller, using product pipe. Using surface controller flowing substance flowing mode is determined, on basis of which working parameters of oil well are adjusted. Working parameters of oil well can be adjusted to detect Taylor mode of flow. For adjustment of working parameters throttle is used and/or controlled valve of oil well, controlling amount of gas, forces into product pipe. For determining mode of flow of flowing environment artificial neuron net can be used. It is possible is provide energy for acoustic sensor through product pipe. It is possible to determine additional physical characteristics of flowing substance, for example pressure and temperature.

EFFECT: higher efficiency.

3 cl, 22 dwg

FIELD: oil producing industry; pumping facilities.

SUBSTANCE: according to proposed method jet pump with stepped through channel in its housing and packer with through channel and complex logging device are lowered into well on tubing string. Logging device is installed under packer on tubing string. Perforated section is made on tubing string from side of its lower end. In process of lowering, using logging device, background values of physical parameters of producing formations are recorded, and then packer is released. Packer is installed higher than producing formations under surveying, and complex logging device is installed in zone of producing formations. Then depression insert is installed in stepped through channel of jet pump housing to separate tubing string, and working liquid medium is fed into nozzle of jet pump, thus building different value depressions in underpacker space of well. At each value of depression, well production rate is measured and then, with jet pump operating, complex logging device is moved along producing formations by displacing tubing string without depacking of packer and geophysical parameters of producing formations are recorded. After completion of surveying, depacking of packer and lifting of tubing string with jet pump and logging device to surface is done.

EFFECT: provision of intensification of surveying, testing and preparation of wells, mainly, horizontal and highly slanted wells, optimization of functions of packer and improved reliability of jet plant.

1 dwg

FIELD: oil producing industry; pumping facilities.

SUBSTANCE: proposed well jet plant contains packer and jet pump installed on tubing. Pump is provided with nozzle and mixing chamber with diffuser installed in housing, and stepped through channel is made. Possibility is provided for fitting functional inserts in through channel, for instance, for recording formation pressure built-up curves, and self-contained logging complex is installed on tubing lower than packer for checking physical values, for instance, specific electric resistance of rocks. Jet pump is arranged in casing over producing formation of well. Ring is arranged on tubing lower than packer to center packer in casing. Packer is made of elastic material in form of open-top cup with cone-shaped side wall. Bottom of cup is hermetically secured on tubing, and packer, in its position before removing, has the following dimensions: maximum outer diameter of packer side wall D2 is 0.75-0.99 of inner diameter D1 of casing; length L of packer is from 0.5 to 3 diameters D4 of packer cup bottom; maximum inner diameter D3 of side wall of packer cup is 0.6-0.96 of maximum outer diameter D2of packer cup; and outer diameter D5 of centering ring is 0.8-1.05 of diameter D4 of packer cup bottom.

EFFECT: intensification of surveying and testing of walls with open and cased holes, mainly crooked and horizontal holes, optimization of sizes of packer operating together with jet pump and self-contained logging complex, improved reliability of well jet plant.

2 cl, 1 dwg

Well killing fluid // 2260112

FIELD: oil production industry, particularly for filling oil and gas-condensate wells with special fluids before well workover, especially at low temperatures.

SUBSTANCE: well-killing fluid includes polyglycols, aliphatic alcohol and water. The fluid additionally has flotation agent-oxal. Above components are taken in the following amounts (% by volume): polyglycols - 5-35, flotation agent-oxal - 45-65, aliphatic alcohol - 15-20, remainder - water. Isopropyl, ethyl or butyl alcohol is used as the aliphatic alcohol.

EFFECT: increased frost-resistance and viscosity, prevention of foaming and reduced permeability of bottomhole zones by reason of well killing.

2 cl, 3 ex, 1 tbl

FIELD: oil and gas industry, particularly process liquids for killing oil, gas and gas condensate wells with formation pressure exceeding hydrostatic pressure.

SUBSTANCE: liquid includes hydrocarbon base, synthetic fatty acid and atactic polypropylene used as structure-forming agent, sodium hydroxide and weighting agent - barite. Liquid additionally has mineral rubber used as structure-forming agent and silicone fluid. All above components are taken in the following amounts (% by weight): hydrocarbon base - 69-84, synthetic fatty acid - 0.7-2.0, sodium hydroxide - 0.42-1.08, atactic polypropylene - 1.59-4.34, silicone fluid - 0.3-0.5, mineral rubber - 1-8, remainder - weighting agent.

EFFECT: extended range of liquid application, reduced fluid loss, reduced negative action on well bore zone permeability, extended density and temperature range.

3 ex, 2 tbl

FIELD: mining industry.

SUBSTANCE: system has first induction throttle, second induction throttle and controlled switch. Second induction throttle is positioned near second branch of pipeline structure. Controlled switch has two outputs. First switch output is electrically connected to pipeline structure on the side of induction throttles connection, where first and second branches of pipeline structure intersect. Second output of switch is electrically connected to pipeline structure on other side of at least one induction throttle. Pipeline structure can be positioned inside oil well, and can have casing string and operation tubing column. Also described is method for extracting oil products from oil well using said system.

EFFECT: higher efficiency.

4 cl, 10 dwg

FIELD: oil industry.

SUBSTANCE: at least one acoustic dynamic is mounted immediately on product pipe in oil well and acoustic characteristic of flowing environment flow is determined in product pipe. It is sent into surface controller, using product pipe. Using surface controller flowing substance flowing mode is determined, on basis of which working parameters of oil well are adjusted. Working parameters of oil well can be adjusted to detect Taylor mode of flow. For adjustment of working parameters throttle is used and/or controlled valve of oil well, controlling amount of gas, forces into product pipe. For determining mode of flow of flowing environment artificial neuron net can be used. It is possible is provide energy for acoustic sensor through product pipe. It is possible to determine additional physical characteristics of flowing substance, for example pressure and temperature.

EFFECT: higher efficiency.

3 cl, 22 dwg

FIELD: oil and gas industry.

SUBSTANCE: method includes serial pumping into well of buffer, blocking and pressing liquid, blocking liquid contains hydrocarbon base, acyclic acid, caustic soda and mineral filler with following relation of components in percents of mass: hydrocarbon base 41-72, acyclic acid 6.1-14.4, caustic soda 4.9-13.0, mineral filler the rest. Hydrocarbon base of blocking liquid is oil or oil processing products. As mineral filler blocking liquid has calcium carbonate with diameter of particles no less than 2 micrometers.

EFFECT: higher efficiency, simplified maintenance, simplified construction.

3 cl, 1 ex

FIELD: oil and gas production.

SUBSTANCE: water-based composition that can be used for killing of well during pullout of hole and well remedial work as well as for temporary abandonment of well contains, wt %: carboxymethylcellulose3.5-4.5, sodium hydroxide1.5-2.0, copper sulfate 0.3-0.4, and methanol 4.0-16.0.

EFFECT: improved rheological properties of composition and increased lifetime of formed gels.

1 tbl

FIELD: oil and gas industry.

SUBSTANCE: method includes preparation of technological liquid - water solution of sylvinite ore mixture with chlorine calcium by solving a mixture of components in hot fresh technical water, drained from oil and water preparation plants or bed water. During solution of sylvinite ore mixture with chlorine calcium in bed water the latter is drained from the well at temperature 60-90°C. Technological liquid is produced with solution density 1.23-1.37 t/m3. Then prepared technological liquid is fed into well shaft a bit lower, oppositely to zone and above ceiling of productive bed with forming of hydraulic column above the latter. Then well shaft to the mouth is filled with water. Value of technological liquid hydraulic column of high density on basis of said mixture, fed into well shaft above ceiling of productive column of technological liquid is taken in amount, necessary and enough from well stopping conditions.

EFFECT: higher efficiency.

6 cl, 1 ex

FIELD: oil extractive industry.

SUBSTANCE: method includes mounting compressor pump in such a way, that input aperture of tail piece was positioned below bed sole. Prior to that water cone in face-adjacent zone is destroyed by draining water through tail piece, connected to lower suck-in valve of compressor pump cylinder, and along behind-pipe space through side suck-in valve of compressor pump cylinder. In case of increase of hydrocarbon contained in drained liquid beginning of water cone destruction is assumed. Draining is continued until destruction of emulsion in water cone, formed in non-homogenous porous environment of bed at limits of hydrocarbon-water and water-hydrocarbon, separation of water and hydrocarbon streams and bringing current water-hydrocarbon contact to initial position. Then during extraction water is drained through tail piece, and hydrocarbon - along behind-pipe space.

EFFECT: higher yield.

3 cl, 1 dwg

FIELD: oil and gas producing industry, in particular composition for killing of well.

SUBSTANCE: claimed polysaccharide gel contains sweet or mineralized water, polysaccharide gelling agent, boron cross-linking agent, diethanolamine, quaternary ammonium compounds, and mixture of non-ionic and anionic surfactant (complex surfactant). Mixture of water soluble oxyethilated alkylphenols and their sulphoethoxylates in form of sodium salts or salts with triethanolamine is used as complex surfactant in amount of 0.1-0.5 kg on 1000 l of water being the gel base. Polysaccharide gel is obtained by dissolution and hydration of polysaccharide gelling agent in sweet or mineralized water (preferably monovalent ion solution) followed by treatment of obtained polysaccharide solution with aqueous solution including boron cross-linking agent, diethanolamine, quaternary ammonium compounds, and complex surfactant.

EFFECT: well killing composition of improved quality.

2 cl, 6 ex, 1 tbl

FIELD: oil and gas extractive industry.

SUBSTANCE: compound includes water and inhibiting salt, as inhibiting salt contains processed electrolyte - side product during production of magnesium via electrolysis from carnallite, and additionally as reducer of filtering and thickener - carbooximethylcellulose polymer, and as colmatation agent - magnesium oxide with following relation of components in percents of mass: processed electrolyte - side product of magnesium production via electrolysis from carnallite 10.0-15.0, carbooximethylcellulose 2.5-3.0; magnesium oxide 1.0-2.0, water 80.0-86.5.

EFFECT: higher efficiency.

3 tbl

FIELD: oil production industry, particularly to regulate and/or measure flow parameters.

SUBSTANCE: regulator comprises body with outer groove, side pass channels and axial connecting channel, lower and upper collar holders with outer packing members, fishing head and tail piece with fixer. Fishing head has side pass channels and/or through axial connecting channel. The body or lower and upper collar holders and/or fishing head and/or tail piece have inner landing seats for receiving locks or have borings. Removable restrictors are installed at least in two borings and have opposite direction. The restrictors have equal or different pass and/or outer diameters and may have free or spring-loaded back valves performing restricted movement. Summary flow area of removable restrictors is less than that of side pass channels of the body.

EFFECT: increased efficiency of output and/or pressure well formation operation due to increased regulator cross-section along with limited size thereof, extended range or pressure and flow regulation during fluid extraction and/or working substance pumping-in.

18 cl, 9 dwg

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