Producing reservoirs survey method at dual operation of multi-pay well and installation for its implementation
FIELD: oil and gas industry.
SUBSTANCE: installation consists of a liner with blind, overflow valves, packer, connecting and disconnecting device, junk basket, electric valve with latching mechanism equipped with pressure transducer, submersible motor supplied by electricity through a cable, submerged telemetry unit connected by electric circuit through windings of the submersible motor and cable with control station and data receipt and processing unit. Knock-off valve and return valve are placed above the electrically operated pump. The installation comprises a unit that excludes impact of the submersible motor to power supply line of the electric cable, to data measurement and receipt.
EFFECT: improved efficiency of reservoir parameters measurement at the well survey, efficiency of electric valve control, optimised production in real-time mode.
8 cl, 2 dwg
The invention relates to the oil and gas industry, namely to methods and means for measurement of productive layers, in particular the definition of production of each productive stratum, the implementation of simultaneous-separate operation of multilayer wells with the use of electrical submersible pump with electric valve.
The known method of simultaneous-separate operation of two reservoirs in the well (patent RF №2380525, IPC EV 43/14, publ. 27.01.2010), implemented with the ability to determine reservoir productivity.
The method includes the descent of the tubing with the packer, equipped with an anchor to the desired installation interval, the fixation anchors with installation of the packer between the layers, the descent of the pump and the selection of products seam, joint or separate. According to the invention the packer with an anchor and an additional rotating electric drop cable, the length of which is sufficient to choose the installation of the packer between the layers with the pump placed below the liquid level of the two layers. After which the cable is attached on the column of pipes, equipped with electrical submersible pump, which is equipped with an additional cable with a capacity sufficient for pumping production of both layers. The column of pipes with cables run into the well before the packer between the layers. Supply direct �of atragene cable set by means of the electric motor with an anchor packer between the layers. Voltage supply via additional cable run the pump. As a result determine the productivity of the upper layer. Next, the flow of reverse voltage on the cable to the actuator packer and anchor return to the transport position. Then additional cable run the pump. As a result determine, based on the initial study of the hydrodynamic properties of the lower stratum. The results of these studies choose the frequency of installation and removal of the packer to anchor for optimal production from the upper reservoir when the packer to reduce the liquid level below the dynamic level of the less productive formation and above the top of the pump or of both layers when removing the packer to achieve the dynamic level of the liquid is less productive formation.
The disadvantage of this method simultaneously-separate operation is necessary to end the pumping of products both layers at conducting research since first start the pump, determine the productivity of the upper layer, unplug it, return the packer and anchor in the transport position, and then re-start the pump. To enable and disable the pump takes time, also requires the energy costs when returning the operation mode of the pump at steady state. Frequent start-stop submersible electric�strobing equipment adversely affect the turnaround time of its operation, submersible motor has a low MTBF. Obviously, if the pump is not disconnected, the technology research and simultaneous-separate operation of the wells would be more effective. The implementation of multiple-entry and landing of failure of the packer during operation will not ensure the reliability of Petrovci and sealing due to deposition of salts and paraffin on the surface of a production string and packer. In addition, there is a possibility of transfer of fluid from one reservoir to another, which is contrary to the requirements of Rostekhnadzor in the simultaneous-separate operation.
Known installation for simultaneous-separate study and operation of electrical submersible pump multizone wells (RF patent No. 2380522, IPC E21B 43/12, E21B 47/12, publ. 27.01.2010).
Installation includes equipping wells mnogopikselnoy or odnopikselnoj layout at the depth of layers with descents into the well column pipe with electrical submersible pump with or without a casing and at least one regulating valve. Mohapatra layout feature connected or disconnected between each other, at least two landing sites, located respectively above the upper packer between packers. Control valve bottom equipped with an external disconnector and internal shank with FDA�taosim device. During the descent of electrical submersible pump above mnogopikselnoy layout provided with the possibility tight connection between them, simultaneously, as a sealing device and a landing site between the packers and the outdoor disconnector and landing site above the upper packer. The control valve consists of a housing, at least two interconnected hydraulically connected uniaxial and one axial-bandwidth channels, which is placed inside electro-mechanical, electromagnetic or hydraulic action of the shut-off element type piston, plunger, bolt or rotary drive is arranged to move, for example, in the middle, up or down, or rotate from one position to another and the control signal or impulse from the surface of the well or automatically from the parameters of fluid transfer through a cable or a tube, or pipe string, or the environment. Thus in one position all bandwidth channels hydraulically, partially or completely reported with the reception of electrical submersible pump and reservoir wells for simultaneous extraction of fluid from them, but on the contrary, in the other position cutting off the flow of fluid, at least one of the reservoir by closing the input or output of the corresponding uniaxial bandwidth for the study of the characteristics and mode, cu�ina least one of the remaining open reservoirs. For odnopikselnoj layout control valve is connected on top to the housing and the bottom of the packer.
The disadvantage of the present invention is the absence of a telemetry system in the control valve (pressure sensor) associated electrical circuit through the windings of submersible electric motor with a control station for centrifugal pump that does not meet the requirements of Rostekhnadzor.
The known method of extraction of fluid from layers of one borehole electric pump with electric valve and installation for its implementation (patent RF №2385409, IPC E21B 43/00, E21B 47/12, publ. 27.03.2010).
The method includes running-in-hole layout consisting of tubing, equipped with at least one packer to isolate objects with isolator-coupler or without electric pump with or without casing, equipped with an input module, power cable, submersible motor without or with block submersible telemetry, shank and at least one controlled electrical valve with shut-off element. Opening it regulate the flow of fluid, at least one object passing through the valve to the upstream input module electrically driven pump. According to the invention the electric valve electro�itogo or Electromechanical actions electrically connect or with submersible motor, or submersible telemetry unit, or with a cable. Besides, its mechanically connect, harshly or not harshly or with submersible motor or submersible telemetry unit, or with a casing or liner. Moreover, the electric valve fitted above the packer. While performing the electric valve or single, hydraulically connected with the space under the packer or packer, or with two separate entrances, one of which is hydraulically connected with the space under the packer, and the other with the space above the packer, or the layout equipped with two electric valves, one of which is hydraulically connected with the space under the packer, and the other with the space above the packer, while providing managed as clipping, and passes through fluid flow to the bottom or to the top of the object, or both the bottom and top of objects without or with flux measurements. For implementing the method provides for a device.
Practical implementation of the method and installation according to the patent of Russian Federation №2385409 has the following disadvantages:
1) a separate cable line (when the electric control valve according to the additional cable) does not ensure the continued operation of the centrifugal pump (ECP) - it quickly goes down p�d the action of aggressive media, through 180-200 days is a failure; also increase the complexity of installation and tripping operations, the layout of underground equipment with two cable lines; there are frequent damage of two cable lines when going downhill, ESP;
2) during the descent and ascent of the two lines of the cable into a downward-directed bore increases the likelihood of damage to the line, which is controlled by the electric valve; also decreases the flow area between the column pipe and casing, which can result in a stuck downhole equipment in a borehole;
3) requires a separate control valve, which creates problems for the placement of equipment at the wellhead.
The known method and installation for the control of electric valve cable electrically driven pump have its own scope. The present invention expands the Arsenal of tools that serve the same purpose.
The technical result of the present invention is to improve the efficiency measurements of aquifer parameters in the study wells, the efficiency of the electric control valve and, consequently, optimization of extraction of fluid from the upper productive formation with simultaneous-separate operation of multilayer wells electrical submersible pump with electric valve, the exception flow of fluid from the top�it in the bottom of the reservoir, production optimization in real time and to study the dependence of percentage of water content at different bottom-hole pressures, no need to turn off the pump when AC power is supplied to the electric actuator of the valve and switch, guaranteeing trouble-free retrieval of the packer, eliminating the need for additional wires and conducting unconventional operations at the wellhead (soldering, wiring) and also remove the need to amend the scheme of arrangement of equipment at the wellhead.
The technical result is achieved by the implementation of the method of the study of productive layers with simultaneous-separate operation of multilayer wells, including the descent into the multi-hole on the column of pump-compressor pipes lower section of the installation consisting of a shaft with a stub, receptor for entry into the column of pipes of fluid from the lower layer in the form of excess flow valves, retainer, disconnect switch connector, installing a packer between the lower and upper productive layers, separation of tubing from the packer and her ascent, descent on the column of pump-compressor pipes the top section of the plant, including bottom-up electric valve with the possibility managed as clipping, and the prop�ka through fluid flow the lower stratum with the measurement of flow parameters, connected electrically and mechanically with the submersible telemetry unit, submersible motor with cable, electrically driven pump, installation of wellhead equipment, electrically driven pump and a product selection of layers according to the invention, installed above the disconnector-connector classlevel, electrical equip the valve with a pressure sensor and a node, excluding the impact of the submersible motor current on the supply line of the electric cable, the measurement and transmission of information, wherein the electric valve actuator electrically connect with the submersible telemetry unit via the control system by the electric valve by means of one or more wires laid inside the submersible telemetry unit and valve, and the submersible telemetry unit electrical circuit connects through the windings of submersible motor and cable from the control station and the unit receiving and processing information from the management station through the cable supplying submersible motor, serves current to the motor valve, overlap the inner cavity of pump-compressor pipes, transmit the pressure of the lower stratum of the pressure sensor through the valve submersible telemetry unit for receiving unit information, then transmit the information about the measurements in the control field, when�eat pump operation when the pressure measurement is not stopped, after measuring the bottom-hole pressure bottom of the productive formation by the pressure sensor from the management station valve, combined with station management unit of electric submersible pump, serves a current of reverse polarity to the motor valve, produce opening of the valve, transfer pump for permanent operation.
To achieve the goal can be used the following particular solutions:
- the installation of the above electrically driven pump equipped with reverse and whipped valves;
- equip installation of additional packer.
The technical result is achieved by the use of the installation for simultaneous-separate operation of multilayer wells containing two sections - top and bottom, and the bottom section is lowered and pre-equipped with a shaft with a cap, a receiver for receipt in the column of pipes of fluid from the lower layer in the form of excess flow valves, packer, planted between the lower and upper productive layers, disconnect the connector on the upper end of the lower section and the upper section of the installation has the possibility of lowering and is equipped with an electric valve connected mechanically and electrically with the submersible telemetry unit and provided with a device for measuring one or more parameters of a formation, submersible motor with KAB�LEM, electrically driven pump according to the invention, the above-disconnector-connector installed classlevel, electric valve provided with a pressure switch and the node, excluding the impact of the submersible motor current on the supply line of the electric cable, the measurement and transmission, the electric drive of the valve is connected electrically with the submersible telemetry unit via the control system by the electric valve by means of one or more wires laid inside the submersible telemetry unit and valve and a submersible telemetry unit electrical circuit is connected through the winding of submersible motor and cable from the control station and the receiving unit and information processing, the station control valve is combined with the station control unit of electric submersible pump that can adapt to any manufacturer of control stations.
To achieve the goal can be used the following particular solutions:
- classlevel made in the form of a piece of tubing to put on her body, the bottom of which is sealed against the pump-compressor pipe and the open top is made in the shape of a funnel;
- the locking mechanism of the electric valve is conical relative to the saddle of the locking mechanism;
- higher e�caprioglio pump are the reverse and whipped valves;
- equipped with an additional packer.
The invention is illustrated shown in Fig.1 installation diagram for simultaneous-separate operation of multilayer wells and is shown in Fig.2 scheme of monitoring downhole parameters.
Installation (Fig.1) consists of a shank 1 with a plug 2, the bypass valve 3, the packer 4, the disconnector-connector 5, clamslammability 6, an electric valve 7 with a locking mechanism (not shown in the figures) provided with a pressure sensor (Fig.2), submersible electric motor (SEM) 8, powered by an electric current through a cable 9, block submersible telemetry (BPT) 10, the electrical circuit through the windings of the associated pad 8 and the cable 9 with the control station 11 and the receiving unit and information processing 12.
The locking mechanism of the electric valve 7 may be made conical in relation to the seat locking mechanism. This version of the locking mechanism allows Stolbovaya flow by partial displacement of the locking mechanism.
Mechanical valve 7 is connected to the TTO 10 through the coupling and flange-connector (not shown in the figures), the electrically driven valve 7 is connected to the TTO 10 through the valve control system (Fig.2). Electrical connection electric actuator valve 7 with the TTO 10 is performed by one or more Pro�odes (not shown in the figures), padded inside BPT 10 and the valve 7.
Classlevel 6 made in the form of a piece of tubing (tubing) placed on her body a certain length, the bottom of which is sealed against the tubing, and the top is made open in a funnel shape. The performance of clamslammability 6 allows you to capture any objects that might fall into the wellbore. Thus, the presence of clamslammability 6 allows to exclude complications of breakdown and the rise of the packer 4.
The installation contains the node 13, which excludes the impact pad 8 on the supply line of the electric cable, the measurement and transmission of information. Node 13 is set to improve the reliability of information transmission by reducing interference pad on the power supply line and transmission of information.
Packer 4 is designed for the separation of the bottom 14 and top 15 productive layers of the multilayer wells. Above electrically driven pump 16 are whipped 1 7 and return valves 18.
The method is as follows.
Divide the installation into two sections. Lower in a multi-hole 19 on the column tubing (not shown in the figures) in a known manner using standard equipment and tools teams workover bottom section installation consisting of a shaft 1 with a plug 2, a receptor for admission in to�onnu tubes of fluid from the lower reservoir 14 in the form of by-pass valves 3, the packer 4 and the disconnecting switch-connector 5. Set the packer 4 between the lower 14 and upper 15 productive layers, produce a separation of the tubing from the packer 4 and its lifting. Then pull the top section of an installation consisting of an electric valve 7, BPT 10 with the pressure sensor, so that the pad 8, the electrically driven pump 16, 17 and whipped return valves 18, connect in a place of separation connection with the packer 4, carry out the installation of wellhead equipment. Start the electric pump 16. Thus the fluid from the lower reservoir 14 through the Central channel of the packer 4 into the internal cavity of the tubing 20 and through the open valve 7 opens into the annulus 21 and mixes with the fluid of the upper layer 15, then the pump 16 through the tubing string 22 is pumped to the surface.
To monitor the work of the layers 14, 15 from the control station 11 via the cable 9, the feeding pad 8 provides a current to the motor (Fig.1, not shown) of the valve 7, as a result overlaps the inner cavity of the tubing 20 and the pressure increases to the true values of the bottom-hole pressure bottom of the reservoir 14 in 30-60 minutes. The pressure sensor (Fig.2) located in the valve 7, transmits the pressure through the TTO 10 to the receiving unit 12. Then this information about the measurements is transmitted to the remote control of the whole field (not shown in the figures). This procedure periodically �overeats, for example, twice a month. When measuring pressure work electrically driven pump 16 is not stopped. The pump 16 operates in a low frequency mode and pumps the fluid of the upper layer 15. A pressure sensor (not shown in the figures) located in the TTO 10, indicates the pressure in the annulus in operation, electrically driven pump 16. After measuring the bottom-hole pressure bottom of the reservoir 14 by a sensor located in the valve 7, the control station 11 is supplied a current of reverse polarity to the motor valve 7, produce opening of the valve 7, whereby the internal cavity of the valve 7 communicates with the annular space 21, is transferred electrically driven pump 16 on the continuous operation mode by restoring a frequency of 8 SEM.
A method is described for odnopikselnoj installation. When implementing the method described above is possible as tropicanna and Mohapatra installation.
The proposed method allows to adjust the volume of extraction of a partial opening of the valve. Periodic opening and closing of the valve is performed when operating electrical submersible pump. Termination of the selection of fluid from the lower stratum in the study of aquifer parameters has no effect on operation of the upper layer.
The advantages of the present invention in comparison with known methods and installations of: electrically driven pump for�stantly works in prior art pump is turned off to pass current to the motor valve, overlying the lower layer. This ensures optimization of the extraction of fluid from the upper productive formation with simultaneous-separate operation of multilayer wells electrical submersible pump with electric valve, as well as improved measurements of aquifer parameters in the study wells. The advantages include the fact that precluded the flow of fluid from the upper reservoir in the bottom that is not provided in prior art. The flow of the lower stratum staterooms, which gives the opportunity to optimize production in real time, to carry out research according to the percentage of water content at different bottom-hole pressures. The use of clamslammability guarantees trouble-free retrieval of the packer. Combined design of the valve block and submersible telemetry eliminates the need for additional wires, also excludes non-standard work on the wellhead (soldering, wiring). By combining the station control unit of electric submersible pump station and control valve eliminates the need for amendments to the scheme of arrangement of equipment at the wellhead.
1. Method of the study of productive layers at the same time-separately� operation of multilayer wells, including the descent into the multi-hole on the column of pump-compressor pipes lower section of the installation consisting of a shaft with a stub, receptor for entry into the column of pipes of fluid from the lower layer in the form of excess flow valves, retainer, disconnect switch connector, installing a packer between the lower and upper productive layers, separation of tubing from the packer and her ascent, descent on the column of pump-compressor pipes the top section of the plant, including bottom-up electric valve with the possibility managed as clipping and passes through fluid flow the lower stratum with the measurement of flow parameters, connected electrically and mechanically with the submersible telemetry unit, submersible motor with cable, electrically driven pump, installation of wellhead equipment, electrically driven pump and a product selection of layers, characterized in that the set above disconnector-connector classlevel, electrical equip the valve with a pressure sensor and a node, excluding the impact of the submersible motor current on the supply line of the electric cable, the measurement and transmission of information, wherein the electric valve actuator electrically connect with the submersible telemetry unit via the system control electric valve using one�about or more wires, padded inside unit submersible telemetry and valve, and the submersible telemetry unit electrical circuit connects through the windings of submersible motor and cable from the control station and the unit receiving and processing information from the management station through the cable supplying submersible motor, serves current to the motor valve, overlap the inner cavity of pump-compressor pipes, transmit the pressure of the lower stratum of the pressure sensor through the valve submersible telemetry unit for receiving unit information, then transmit the information about the measurements in the control field, and the operation of the pump when the pressure measurement is not stopped, after measuring the bottom-hole pressure bottom of the productive formation by the pressure sensor from the management station valve, combined with station management unit of electric submersible pump, serves a current of reverse polarity to the motor valve, produce opening of the valve, transfer pump for permanent operation.
2. A method according to claim 1, characterized in that the installation of the above electrically driven pump equipped with reverse and whipped valves.
3. A method according to claim 1, characterized in that the installation be equipped with an additional packer.
4. Installation for simultaneous-separate operation of multilayer wells containing two sections - lower�Yu and top, and the bottom section is lowered and pre-equipped with a shaft with a cap, a receiver for receipt in the column of pipes of fluid from the lower layer in the form of excess flow valves, packer, planted between the lower and upper productive layers, disconnect the connector on the upper end of the lower section and the upper section of the installation has the possibility of lowering and is equipped with an electric valve connected mechanically and electrically with the submersible telemetry unit and provided with a device for measuring one or more parameters of the reservoir, submersible motor cable, motor-driven pump, characterized in that the above-disconnector-connector installed classlevel, electric valve provided with a pressure switch and the node, excluding the impact of the submersible motor current on the supply line of the electric cable, the measurement and transmission, the electric drive of the valve is connected electrically with the submersible telemetry unit via the control system by the electric valve by means of one or more wires laid inside the submersible telemetry unit and valve and a submersible telemetry unit electrical circuit is connected through the winding of submersible motor and cable from the control station and the receiving unit and processing information�and, the station control valve is combined with the station control unit of electric submersible pump that can adapt to any manufacturer of control stations.
5. Apparatus according to claim 4, characterized in that classlevel made in the form of a piece of tubing to put on her body, the bottom of which is sealed against the pump-compressor pipe and the open top is made in the shape of a funnel.
6. Apparatus according to claim 4, characterized in that the locking mechanism of the electric valve is conical relative to the seat locking mechanism.
7. Apparatus according to claim 4, characterized in that the above electrically driven pump are the reverse and whipped valves.
8. Apparatus according to claim 4, characterized in that is equipped with an additional packer.
FIELD: oil and gas industry.
SUBSTANCE: method of a well bore zone treatment for a productive formation that includes running in of an in-series bottom-up mounted hydroimpulsive device and a jet pump at the pipe string to the well. Fluid is delivered to the hydroimpulsive device and this fluid is used for an impact on the well bore treatment zone with simultaneous pumping the fluid with colmatage particles by the jet pump to the surface. A depth gauge is mounted additionally at the tubing string in front of the hydroimpulsive device. At that a rotary hydraulic vibrator is used as the hydroimpulsive device to create a water jet and pulse-cavitating flow along the perforation interval. An impact on structures of the formation with fluid is made by the excitation of resonant oscillation of the fluid column in the well due to matching of the ripple frequency of the rotary hydraulic vibrator and own resonance frequency of the casing string with the fluid, placed below the rotary hydraulic vibrator and being a resonator of an organ pipe type. The required oscillation frequency f, Hz, is determined by the specified mathematical expression.
EFFECT: improved efficiency of performed surveys and treatment of the well bore zone of the formation with a combined water-jet effect on perforated openings or filters of the production casing and the pulse-cavitating flow to the formation structure with fluid and monitoring of the treatment parameters.
2 cl, 1 dwg
FIELD: oil and gas industry.
SUBSTANCE: invention refers to the oil-extracting industry and can be used on oil deposits for measuring formation pressure for controlling and managing the oil extraction process. The method involves measuring the formation pressure in an oil producer equipped with a submerged electric-driven pump. A calculation process involves using a fluid influx point from the formation to the well via a known uniform-density damping fluid when commissioning the well after the damping procedure by formula.
EFFECT: reducing a surveyed well downtime, increasing the accuracy and reliability of determining the foundation pressure, and facilitating the implementation when commissioning the well after damping.
SUBSTANCE: according to the method, a casing string with temperature sensors attached to its outer surface is lowered to a well and cement is pumped to an annular gap between the casing string and well walls. During a cement filling and hardening process, temperature measurements are made and thermal conductivity of surrounding mine rocks of the well is determined as per the measured relationship between temperature and time.
EFFECT: possibility of simultaneous reception of information on properties of a relatively thick layer of rocks around the well and information on thermal conductivity of rocks for the whole cemented interval of depths.
3 cl, 2 dwg, 1 tbl
FIELD: oil and gas industry.
SUBSTANCE: device includes a mechanical oscillating system with constant magnets fixed on it and a converter of mechanical oscillations to electrical ones. A mechanical oscillating system is made in the form of a cylindrical bimetallic spiral, one end of which is rigidly fixed, and the other one is free, and the converter of mechanical oscillations to electrical ones is made in the form of a system of interacting electromagnetic fields of constant magnets rigidly fixed on a cylindrical bimetallic spiral and coils of a drive and pickup of oscillations providing for transverse oscillations of the cylindrical bimetallic spiral.
EFFECT: enhancing reliability of a device and improving its design.
FIELD: oil and gas industry.
SUBSTANCE: invention is related to the area of wells completion and testing in oil industry and intended for calculation of parameters for the well bottomhole and bottomhole area. The method where in process of string movement in the well pressure is measured by two sensors, at that one sensor is installed over the packer while the second one is installed below the packer. According to results of pressure measurement fluid density is determined and then flowing bottomhole pressure is determined on the basis of fluid density, gravity constant, preset rate of drilling string motion, cross-sectional area of the drilling string, formation pressure, and productivity index of the well.
EFFECT: potential determination of parameters for the well bottomhole and bottomhole area during round-trip operations with further calculation of liquid influx/reflux at the bottomhole and calculation of skin factor, permeability or thickness of the reservoir.
13 cl, 5 dwg
FIELD: oil-and-gas industry.
SUBSTANCE: evaluation of fluid inflow fraction from every productive zone of multi-zone productive well comprises determination of pressure at wellhead. Integrated indicator curve (IPR1) is obtained to describe the relationship between pressure and fluid yield from first productive zone and integrated indicator curve (IPR2) is obtained to describe the relationship between pressure and fluid yield from second productive zone. Value for integrated indicator curve at the point of mixing (IPRm) is obtained with the help of IPR1 and IPR2. Initial fluid inflow fraction from first productive zone at mixing points and initial fluid inflow fraction from second productive zone are defined. First total curve of outflow (TPR1) is obtained describing the relationship between fluid pressure and yield, fluid flowing from mixing point to wellhead. First portion of fluid inflow from first productive zone (Q11) and first portion of fluid inflow from second productive zone (Q21) are defined at mixing point with the help of IPRm and TPR1. Machine-readable carrier accessible for processor comprise program including instructions for above listed jobs.
EFFECT: more efficient evaluation of the portion of influx from productive seam.
20 cl, 5 dwg
FIELD: measurement equipment.
SUBSTANCE: system (100) of sensors for measurement of a technological parameter of a fluid medium in a well location, comprising a resonator (110) of a parameter, which is located in a well (106), having resonance frequency that varies depending on the technological parameter of the fluid medium and which in response generates a resonant acoustic signal on the resonance frequency that indicates the technological parameter. Besides, the system comprises an acoustic sensor (118), arranged in the location near above the surface, spaced from the parameter resonator, a measurement circuit (102), connected with the acoustic sensor, and an acoustic source connected with a pipe in the location near above the surface and spaced from the parameter resonator placed in the well. At the same time the acoustic sensor is made as capable of receiving the resonant acoustic signal, transmitted from the parameter resonator, the measurement circuit is arranged as capable of formation of an output signal of the technological parameter, corresponding to the technological parameter of the fluid medium, in response to the received resonant acoustic signal, and the acoustic source is arranged as capable of transmission of the acoustic signal into the well.
EFFECT: provision of measurement of well fluid medium properties in real-time mode both in process of drilling and in process of well operation.
20 cl, 6 dwg
FIELD: oil and gas industry.
SUBSTANCE: the method is realized in two stages. At the first stage to the lower horizontal producer a flow string is run in to the beginning of a slotted filter. A heat insulated filter is set in the upper horizontal injector above the slotted filter. In the upper horizontal injector temperature tests are made in the interval from the well head up to the packer. Steam is injected to the lower horizontal producer and temperature tests are made simultaneously in the upper horizontal injector. Upon completion of steam injection to the lower well the final temperature test is made in the upper well. At the second stage fresh water is injected to the upper horizontal injector and a heat insulated flow string is run in with a thermal packer and shank. The packer is set before the slotted filter and control temperature test is made in tubular annulus in the interval from the well head up to the packer. Steam is injected to the upper horizontal injector though the heat insulated flow string, through the packer and shank to the beginning of the slotted filter. At that, periodically, upon commencement of injection, temperature tests are made in tubular annulus in the interval from the well head up to the packer. Upon completion of steam injection the final temperature test is performed in the upper horizontal injector. When required, tests in the lower producer and operational procedures for the wells are interchanged.
EFFECT: improving authenticity of the obtained results during identification of intervals with cross flows behind the casing for wells operated in deposits of viscous and superviscous oil.
SUBSTANCE: proposed device comprises housing to accommodate the set of pressure and temperature gages, moisture metre and flow metre, electronics unit connected by logging cable, on one side, with surface control station and. On opposite side, with said gages, coupling unit with cable joint head and centring skid. Instrumentation module is secured at said housing by leverage, said module including inclination metre and extra gages, at least, moisture metre and flow metre connected with electronics unit. This module can reciprocate along the gravity vector between casing pipe and housing. It is located at casing pipe profile lower part by centring skid and coupling unit. It is equipped with housing turn drive and instrumentation module to turn them from gravity vector set by inclination metre via electronic unit.
EFFECT: registration borehole fluid interface boundaries and flow rate of every separate phase in conditionally horizontal wells.
4 cl, 3 dwg
FIELD: oil and gas industry.
SUBSTANCE: bubble-point pressure determination method includes measurement of bottomhole pressure at different oil production rates and registration of bottomhole pressure change curves upon returning the well to production in linear and nonlinear oil influx modes above or below bubble point pressure. At that wellhead pressure change curves and dynamic level changes in annular space are recorded additionally. By measurement results average density is calculated at each moment of time for the mixture column at annular space and the curve of average density changes in time at annular space is plotted. The free gas release is fixed when a gas separator releases it to the annular space. The value of bubble point pressure is determined by comparison of the mixture density change curve with pressure changes at pump suction at a certain period of time.
EFFECT: improvement of accuracy measurement of bubble point pressure.
1 tbl, 1 ex, 3 dwg
FIELD: oil and gas industry.
SUBSTANCE: installation comprises the production string, a packer with cable entry, a hydraulic manifold, a reciprocating pump and electrically operated centrifugal pump with locking and circulating valve connected to the packer by a connecting pipe and a power cable. In the manifold there is the central opening and longitudinal channels in parallel to the central opening as well as radial channels communicated to annular space. In the central opening of the manifold, above radial channels, a reciprocating pump is fixed so that it forms a cavity communicated with longitudinal channels and cavity of the production string. Below radial channels in the manifold central opening there is a bypass group that covers radial channels in the barrel simultaneously below circular cups of the packer isolating the well formations or ejector releasing gas cap from blinded below-packer annular space covering the central opening and fixed in the manifold by expandable collets with their potential removing by means of a rope and installation tool with capture of grabbing head. In the bypass group and ejector below the blind there are radial openings communicating cavity of intermediate pipe with prolonged channels of the manifold.
EFFECT: increased processibility of well operation.
3 cl, 3 dwg
FIELD: oil and gas industry.
SUBSTANCE: according to the first version the installation comprises flow column, two packers, ground control station, electric cable feeding electric motor of a submersible pump, borehole chamber, which body is limited at butt ends by crossover couplings communicated through longitudinal channels of the couplings to outlet fitting of the submersible pump at the one side and to the flow column at the other side, two units regulating influx and recording fluid for the lower and upper seams separately, which contain telemetric modules measuring physical values of fluids state and adjustable electric valves. The lower packer is set above the lower seam outside the shank. The upper packer is installed below the upper seam; it forms with the lower packer an interpacker section of the well, in which cavity there is the submersible pump with input module and electric motor, the latter is connected to the shank connecting the lower seam to the interpacker section through channels of the shank and adjustable electric valve of the unit regulating influx and recording fluid, which is placed in the shank covering the cavity and connected by communications cable to the ground control station. In the borehole chamber there is a cylinder placed concentrically to the body and matched to crossover couplings communicating the upper seam to the interpacker section through radial channels of couplings and adjustable electric valve of the unit regulating influx and recording fluid, which is placed in the upper coupling and connected by communications cable to the ground control station.
EFFECT: increased efficiency of wells operation.
7 cl, 3 dwg
FIELD: oil and gas industry.
SUBSTANCE: method includes running in of the assembly to the well, setting packers and their leak testing, dual injection of working fluid to productive formations. Before running in the production string is gauged by a gage with length from 30 up to 100 m and diameter less than diameter of the production string per 4-6 mm, at that intervals of gage setting and tightening are marked and reasons for tightening are defined. The production string is studied within intervals of packer setting and intervals of the gages setting and tightening. The well is washed by back washing until clean flush fluid is obtained. The assembly is being assembled. Axial packer is used as the lower packer and thrust plate packers are used as the upper packers. A cable is connected to devices and fixed at outer surface of the assembly. The assembly is run in and its hydraulic leak testing is performed. The plug is removed by means of wire-line technique. The assembly is run in to the well to the required depth at tubing string with measuring length and gaging of inner cross-section of the tubing string. Simultaneously the cable is fixed at outer surface and the cable is run in together with the tubing string. Running speed should be maintained at 0.1 m/s at most. The cable tension is controlled during its running in; no jerks and tension release are permitted. When the tubing string is set to power slips the cable should not be trapped by slips, when releasing the tubing string out of power slips pulling depth should be less than 0.25 m. During running-in weight unload of the tubing string should not be more than 2 t and at unplanned setting of the packer in transport position the tubing string is lifted per 2-3 m and the tubing string is run out slowly passing the packer through interval of unplanned setting. The packers are positioned, fitting of the assembly is made to the preset interval by adjustable tubes, the cable is spliced with wellhead devices, chuck and preventer is mounted, hydraulic leak testing is performed for the tubing string. Value of the tubing string lifting with assembly for packers setting is calculated, the required length is determined for cables from the wellhead up to the controller panel, cable excess is cut, cables are bypassed through the cable input, the packers are set by fixating changes in weight of the tubing string, glands of the cable input are sealed off and functional check of the devices is made. The packers are pressed together and set to gas lift mandrels of pressure regulators with unions of the preset diameters or bottomhole pressure gages, at that during operation at working fluid pumping pressure is measured in the tubing string and annular space between formations and opposite each formation. Dependence of pressure in annular space is controlled on changes in injection pressure of the tubing string; overflow availability is monitored from under the packer to behind-the packer space. Fluid flow rate is defined between packers opposite the formations and when pressure occurs in annular space notwithstanding changes in injection pressure then pressure is released through the casing valve.
EFFECT: improved efficiency of multiple packer assembly setting in the well.
FIELD: oil and gas industry.
SUBSTANCE: device includes a hollow case with a discharge channel and protrusion from below, a barrel placed coaxially inside the hollow case and designed for axial movement, a replaceable jet nozzle and a valve passing fluid inside-out. The hollow case is equipped with inner circular breakdown, the barrel is equipped with an outer circular bore with a locking ring installed in it; the barrel is fixed in regard to the hollow case by a shear tie. On the top the barrel is equipped with a plug catching baffle for a ball thrown to the flow string. Opposite the discharge channel in the hollow case there is an adjustable valve mounted eccentrically; the valve consists of a spring-actuated piston with a rod and an adjusting nut. Below the piston in the valve there is a hydraulic chamber, which can be interconnected to inner space of the hollow case, at that under excess pressure in the hydraulic chamber the piston can be moved axially upwards thus interconnecting the hydraulic chamber to the bed through an outlet opening of the valve, which is equipped with a replaceable jet nozzle and screwed into the outlet opening of the valve.
EFFECT: more reliable operation of the device.
FIELD: oil and gas industry.
SUBSTANCE: invention refers to the oil industry and can be used in multi layered reservoir development with horizontal wells. The method involves recovering the pools as the productive formation intervals along the horizontal bore of the development well. Filtered pipe strings are lowered. The horizontal well bore is sectioned with packers. The well production is separated. That is followed by the production selection and water injection. The formation is sectioned according to a permeability value. If the sections differ more than twice as much, water-swellable packers are arranged at the section boundaries. A filter inside is provided with a solid horizontal partition extending along the whole filter. This partition is used to separate upper and lower portions of the filter. The partition has a hydrophilic surface having a degree of hydrophility of no less than 99%. Capillary holes have a diameter of no more than 2 mm. The holes density is not less than 50 holes/m. A horizontal position of the partition is controlled by sensors mounted at an inlet and an outlet of the filter. An upper portion of a filter wall is perforated, while a lower portion is solid. A water portion is reduced in a liquid supplied from the well bore through the upper portion of the filter. The water is injected through the hydrophilic surface and capillary holes into the lower portion of the filter. In front of the perforations of the filter, the packer is mounted to cut off an annular space of the well. The lower portion of the filter has holes for water outflow into the annular space. The above water is pumped into another formation. The lower portion of the filter is not connected to the piping string, whereon the filter is lowered. The upper portion of the filter is connected to the pipe string. The low-water fluid is supplied from the upper portion of the filter into the pipe string, which is brought up by means of a pump.
EFFECT: more effective separation of oil and water in the well bore, more effective water-flooding and as a consequence the higher oil recovery factor of the deposit.
3 dwg, 1 ex
FIELD: oil and gas industry.
SUBSTANCE: unit includes a packer, hydraulic channels, which number corresponds to the number of production facilities. All channels are connected hydraulically to the aggregated hydraulic channel equipped with a pump unit, and each of them is connected to the respective production facility. The unit comprises also a shutdown valve, which is designed to open/close the hydraulic channel of one of disengaged production facility to the pump unit. One of packers is installed above the upper production facility. The shutdown valve is placed below it or in its hydraulic channel and made as a shutdown valve capable to open/close hydraulic channel of the production facility by generating pressure drop by a control hydraulic signal. The shutdown valve comprises a body with a spring-loaded hollow element installed in it; the element is capable of reciprocative axial movement and of rotary traverse around the vertical axis, it is equipped with a saddle in its upper part and a shutoff device and radial openings in the wall, as well as with guides in the lower part matching the guides in the body, which ensure its turning around the vertical axis at reciprocative axial movement of the element when pressure drop generated by the control hydraulic signal impacts it, at that opening/closing of the radial openings is ensured for hydraulic channels. In the body there are hydraulic channels, each of them is coupled hydraulically by its one end to the respective production facility and by its other end to the element cavity by the above radial opening in the wall of the above element in open position, at that the element cavity id coupled to the aggregated hydraulic channel from the side of the shutoff device.
EFFECT: improved efficiency of dual operation of several production facilities at the same well.
20 cl, 4 dwg
FIELD: oil-and-gas industry.
SUBSTANCE: invention relates to the oil-and-gas industry and can be used for the development of hard-to-extract gas deposits. The proposed method comprises drilling of the main wellbore, running-in of a production string, surveying, drilling of a horizontal section in a productive formation. Note here that the said main wellbore is drilled with a preset inclination angle, encased by the production string with a precut opening in an aluminium shell for drilling and finishing of a smaller-diameter lateral borehole. The wellbore production sections are drilled gently sloping and equipped with appropriate filters. Simultaneously, a dual production string is run-into the main and lateral horizons to be isolated by a packer above the roof of the lower productive horizon to develop separately the horizons by separate production strings. In the well operation, methanol is fed automatically at a preset flow rate in the main wellbore annulus and lateral borehole annulus.
EFFECT: higher efficiency of development.
FIELD: oil and gas industry.
SUBSTANCE: group of inventions is related to the oil industry and may be used for dual operation of deposits. The installation includes a producer equipped with a tubing string and a deep well pump, an injector equipped with a tubing string of the preset length, which is capable of the gravity segregation of the fluid into brine water and hydrocarbon fluid in an annular space, and wellhead equipment with valves. At that the tubing string of the producer and the tubing string of the preset length in the injector are interconnected by wellhead equipment with the valves.
EFFECT: simplification of the process of dual oil production and brine water disposal.
13 cl, 18 dwg
FIELD: oil and gas industry.
SUBSTANCE: method includes measurement of yields for the upper and lower formations and formation pressure, as well as degree of water cut in the lower formation. At that each tube of the flow string is equipped preliminary with an acoustic converters and controllers installed at its length mid with its own control code for the purpose of communications with the system telemetric module, and during the period of short-term stop of the centrifugal pump, besides measurement of yields for the upper and lower formations and formation pressure against level and pressure build-up curves, according to results of continuous polling of acoustic converters and controllers boundaries of gas-oil and oil-water levels are determined upon stratification of the three-phase mixture in the tubing string, as well as production volume for each of the three components in the mixture and its water cut.
EFFECT: improved accuracy for determination of yields and water cut for each developed formation of a multipay well.
1 dwg, 1 tbl
FIELD: oil and gas industry.
SUBSTANCE: invention relates to oil industry and can be used in developing of multilayer oil deposit. The concept of the invention is as follows: the method is characterized by identification of areas with increased thickness of sedimentary rocks during development of a deposit represented by the upper formation of sedimentary rocks of marine genesis and the lower carbonate formation. When such areas are available then the conclusion is made about available area of carbonate formation decompaction with increased oil flow rate. At that the increased thickness of sedimentary rocks coincides with the area of carbonate formation decompaction in plain view. The upper and lower formations are penetrated by injectors and a working agent is injected through them. The area of increase thickness in the upper formation sedimentary rocks and the decompaction area of the lower carbonate formation are penetrated by producers and the product is extracted through them.
EFFECT: improving oil recovery of the deposit.
1 tbl, 1 ex
FIELD: oil and gas extractive industry.
SUBSTANCE: device has operation columns of upper and lower well zones, placed eccentrically one inside the other in upper zone of well, double airlift column, mounted in upper well zone, and double airlift column, connected to operation well of lower well zone, separation column, mounted coaxially to operation column of upper well zone, and cementation pipe. According to invention, in a well with significant power of non-productive zone it is equipped with additional separating column with cleaning channels for lowering drilling tool therein and drilling well to lower well zone with removal of drilling slurry by double airlift column of upper zone through cleaning channels. Additional separating column is combined coaxially with operation column of lower well zone and is rigidly fixed to separation column.
EFFECT: higher efficiency.
1 dwg, 3 cl