Device and method for obtaining measured load in well
FIELD: oil and gas industry.
SUBSTANCE: load is measured in the well location during the well operation; at that, load measurement involves load measurement by means of a subassembly attached to layout of the drilling string bottom. Load data is transferred to surface in real time mode by means of telemetry; load data is evaluated with a control device located on the surface; and corrective action in the well, which is based on the load data, is taken.
EFFECT: improving reliability and quality of analysis of measured load.
18 cl, 10 dwg
The level of technology
To perform many kinds of operations associated with drilling, using a large variety of technical means. Technical tools, such as downhole equipment, often delivered into the well as part of the column of tools to perform the desired operation. For example, in the well can be delivered downhole equipment used to perform drilling operations, processing operations, actuation of operations, operational measurements, fishing operations and other related works well. Within works well equipment may be exposed to a great variety of loads, including loads in compression, tensile loads, twisting, shock and vibration. If these loads become excessive, there will be damage to the equipment in the well.
Attempts were made to detect and measure the load of the equipment in the well. For example, the downhole sensor system with local storage device is used to measure the loads, which were subjected to downhole column tools during the work connected with flexible tubing. Saved local data this operation returned to work remote analysis. However, delayed access to data limits the usefulness of the system classifies the flax adjustments, necessary to reduce destructive loads for works related to the well. This is not to optimise performance in real-time. Have been made other attempts to provide the load to the surface, but such systems have tended to limit the amount of transmitted data and accuracy. Other disadvantages that may be inherent in existing systems, is a relatively large outer diameter, which is a limitation for such systems used in various downhole operations.
The present invention mainly considers apparatus and method for determining conditions in a downhole tool used in conducting well operations in the well. The apparatus and method include measuring the load on a downhole tool during a downhole operation in a downhole location. Load data can be transmitted to the surface for evaluation on the surface of the control device. Although some applications may use locally stored data, other applications benefit from the transfer of part or all of the data to the surface in real time. Based on operational obtained downhole data, you can adjust deistviya fact, so the operation was more than perfect.
Brief description of drawings
Below are some embodiments of the invention, a description will be given with reference to the accompanied drawings, in which adopted digital signs describing the corresponding element, and:
Figure 1 schematically depicts a front external view of the downhole system, which may receive or use the data load in accordance with the embodiment of the present invention;
Figure 2 presents a front external view of a recording unit load for use in downhole system is shown in figure 1, in accordance with the embodiment of the present invention;
3 shows an axial cross-section of the recording unit load is presented in figure 2, in accordance with the embodiment of the present invention;
4 shows a cross section similar to the one shown in figure 3, but with some signs, in accordance with the embodiment of the present invention;
Figure 5 presents the cross-section of part of the recording unit load with the illustration of the trajectory of the load on compression in accordance with the embodiment of the present invention;
Figure 6 presents the cross-section of the unit registration and load with the illustration of the path tensile loads in accordance with the embodiment of the present invention;
Figure 7 presents the front view of the recording unit loads with a partial cutaway to illustrate the switches torque in accordance with the embodiment of the present invention;
On Fig presents the cross-section of part of the recording unit load, illustrating the mounting area of the load cell in accordance with the embodiment of the present invention;
Figure 9 presents the cross-section of the registration unit loads in accordance with an alternative embodiment of the present invention, and
Figure 10 presents an illustration of one example of a switch that can be used to transfer the load torque, if you use a non-rotating connection of the tool, in accordance with an alternative embodiment of the present invention.
In the following description, part numbers made beyond that contributes to the understanding of the present invention. However, the specialist in the art it will be obvious that the present invention can be used without these details and many variations or modifications are possible according to the description of its implementation.
The present invention relates primarily to a device and method of registration of the emission, measurement and control loads experienced by the downhole equipment during various operations associated with the well bore. Load data can be obtained in real time, which allows to simplify the understanding of these loads and improve reliability by introducing corrective actions. For example, the data load in the well can be transferred to the control unit, located on the surface, in order to analyze and determine appropriate corrective action. Data can also be used to synchronize operations operating downhole equipment with a control device located on the surface. In some cases, the application response to the data load can be automated by the control device, located on the surface, so that appropriate corrective actions can automatically be taken to improve downhole operations.
Described herein, the system and methodology can be used for recording and measuring various forces of the load, which can be subjected to downhole equipment during the operation in the well. For example, a force associated with vibration, the forces of compression, tension forces, the forces of the torsional moment, shock and other what types of power loads, associated with exposure can be recorded, measured and transmitted to surface in real time. Depending on the operation in the borehole can be measured also other well parameters, and these parameters can be passed to the control unit, located on the surface. As an example some of these other parameters may include the trajectory, the range, friction, drilling speed, speed, pressure, temperature, and other parameters that may have a specific impact on operations in the well.
With reference to Figure 1 in General is one variant of implementation of the system 20, shown as deployed in a wellbore 22. The system 20 is representative of a variety of downhole systems used in conducting many operations associated with wells, detailed explanation of which is given below. Additionally, the system 20 is designed for registration, measurement and data load from a location in the well to, for example, location on the surface for analysis and use to improve specific downhole operations. In the illustrative application, the system is designed to transfer these data to load in real time, which allows the existence of the Oia immediate corrective action during downhole operations. These additional parameters can be recorded, measured and transmitted in real time to facilitate analysis.
In the illustrative example, the system 20 includes a downhole tool 24, which can be deployed in a desired location in a borehole 22 through conduit 26, such as tubing flexible tubing, downhole columns, stacked pipe or other conduit. The downhole tool 24 is connected to the sub 28 registration load, configured to register one or multiple types of loads, which may be the downhole tool 24. The subunit 28 sends the data load on the surface of the device 30 on the surface and runs on the computer. The data is sent to the surface through line 32 connection, such as fiber optic line. In the illustrative embodiment, the subunit 28 registration load is connected with the pipe 26 through a connecting node 34, which may be a "smart" connector node is able to convert data from subunit 28 into the appropriate format for transmission over fiber-optic lines of communication. Appropriate electronic equipment to transmit data in real time to the surface may be positioned at the connecting node 34, sub 28, combines and these two nodes, or in other suitable locations along the column of tools.
Sub registration load 28 may be designed to register one or several forces, loads, such as loads in compression, tensile loads, loads, torsional moment, shock loads and other loads, which are subject to the downhole tool 24. Additionally, the well can be installed a variety of sensors 36 for recording and measuring other parameters of the well. Data on additional parameters can also be sent to the surface of the device 30 of the control surface through the line 32 communications or other related lines, including wire line or wireless communication line. As an example, the sensors 36 may include a speed measuring devices, gauges, angle gauges gamma radiation, gyroscopic sensors, load cells, sensors state of the clutch casing and temperature sensors.
In many applications, the use of one or more fiber optic lines 32 connection greatly facilitates the transmission of data in real time from subunit 28 registration load and theoretically from other sensors 36. Fiber-optic lines 32 communications can be used in combination with the pipe 26, for example, tubing flexible tubing 26 and deployed, for example, along the inside of the flexible tubing or inside the walls of the flexible tubing. In the joint venture is a special example, the fiber-optic communication line 32 and line 26 of flexible tubing made combined and are industrially manufactured by Schlumberger Corporation. In one embodiment, flexible tubing 26, the fiber optic communication line 32 and the connecting node 34 is made combined, in the form of a platform fiber optic telemetry, industrial manufactured by Schlumberger Corporation. The platform can be used to register various well parameters, such as temperature, annular pressure, the applied pressure and the data of these parameters on the surface, the device 30 controls over fiber-optic communication line 32. In this embodiment, the subunit 28 registration can be installed in the lower part of the measuring platform as a plugin.
The measurement platform usually consists of flexible tubing with a bunch of optical fiber deployed along the inside of the flexible tubing. The bundle optical fiber has one or more optical fibers arranged inside the protective tube, which may be made of metal or other material having appropriate characteristics. Flexible tubing and the bundle of optical fibers have respective upper and lower end fittings or connections that will allow you to enter the fluid inside the flexible tubing and to direct the fluid along the inside of the flexible tubing. However, different build optomologist lines can be implemented in various ways in flexible tubing, in operating the pipe and other suitable pipelines.
In the illustrative example, the system 20 is deployed typically in a vertical well, which extends down from the wellhead 38 wells installed in position on the surface 40. However, the system 20 and its possibilities for registration of loads can be used in different wells, including horizontal wells and other types of deviant wells. The system 20 can also be used in many implementations and applications, including terrestrial and underwater. The type of well tool, or tool 24 used in conjunction with sub 28 registration load, may largely vary depending on the operations in the well. Illustrative downhole tool 24 is represented as a variant of the downhole tool, the descent into the well in order to perform one or more selected operations related to the well.
For example, the downhole tool 24 may include the layout of the bottom hole Assembly (BHA), which is used in the crushing operation. In this example, the bottom hole Assembly includes a drill bit driven by a motor operating through pressure applied by the fluid flowing through the pipe 26, which is made in the form of a pipe. The subunit 28 registration load can be used to check load changes, pointing to alleniana the drill bit. Jamming reduces the average rate of penetration due to the fact that the operator must raise the drill bit and, after a pause again to start crushing. Jamming also shortens the life of the drill bit, as well as the service life of the engine and flexible tubing. The subunit 28 capable of receiving data after twisting BHA 24 in real time, and the stress of twisting moment is used as an indicator of an impending seizure. Information at the beginning makes it possible to adjust the action, preventing jamming, and thus increases the rate of penetration and increases component life. In this embodiment, the sensor 36 can be used to provide additional information. For example, the sensors 36 may include a gyroscope for indicating the orientation sensor of gamma radiation to indicate the correlation of the depth sensor of angular position for the orientation course, and the accelerometer to register shock and/or deviations. The accelerometer may be implemented as a separate sensor, or to be part of the subunit 28 registration load.
In another application of the downhole tool 24 includes a bottom hole Assembly and subunit 28 registration load is used to measure the loads associated with the installation of inflatable or mechanical packer. In rejected is by wells, for example, the definition of the descent of the weight required to activate the packer, causes difficulties in the measurements only on the surface. The subunit 28 can be used to control and receive output for job effort, which at the moment can be applied in the well. Tensile loads can also be measured and displayed to ensure that indicate what the maximum force can be applied during the removal of the BHA. Receiving such data in real time, you can avoid stress, leading to rassoedinenie. Similarly, by controlling the loads in the borehole, it is possible to envisage a situation of excess load, which may cause malfunction of the equipment.
Similarly sub 28 registration load can be used to control and receive the output load when moving cuffs. Additionally, if the shifting tool is not released from the cuff, the updated load information can be transmitted in real time relative to the applied force required to fracture a screw connection for separation. In fishing operations sub 28 can provide similar data load associated with the effort applied to the displacement "lowicki". Data about applied force can means the ü acceleration of fishing operations, to improve its reliability and efficiency.
In another application of the downhole tool 24 includes a vibrating tool that generates vibrations in the well, to reduce the friction force arising from the promotion in the bore flexible tubing. The characteristics of the vibration of the tool 24 can be controlled using subunit 28 and sensors 36 in real time to optimize the operating parameters and thus improve the operation.
The downhole tool 24 may also be composed of a tractor, and the subunit 28 registration load can be used to measure pressures being imposed on the tractor. For example, it may be important to know, involved whether the tractor or not, and to know the magnitude of the force applied by the tractor while pulling the columns. Sub 28 is configured to provide load information in real time so that the operator will have a more accurate view of the operation from the tractor involved in the well. Tracking in real time the load can also prevent damage to the columns of the tools and malfunction. Load data can also be used in combination with a variety of surface measurements and systems, providing optimum Shin is anizatio operations with a tractor, with the control device of a flexible tubing, to prevent congestion and to minimize accidents.
In other cases, the application of the downhole tool 24 includes a drilling tool and a subunit 28 may be used to provide data load, just as it was described above regarding the operation of crushing. For example, tracking in real time the load on the drill bit and the torque applied to the downhole tool can be used to prevent jamming and to maximize the rate of penetration.
The subunit 28 registration load can also be used in other operations. For example, the subunit may be used during works associated with perforation, to control the loads resulting from the punching operation. In this case, the subunit 28 may be used to provide data indicating how and whether the perforator to be activated. Built-in accelerometer can also be used to control shock, and many other sensors can be used to provide data relating to various aspects of the operation of punching. The subunit 28 may also record the resistance movement on the BHA 24 and the column of flexible tubing, which occurs as a result of excessive lane is grusak from lifted placeholder. Similarly sub 28 can be used to identify the situation of the lock, resulting rather in the difficulty of movement than the inability to transfer the load on the BHA.
Thus, the subunit 28 registration load provides in real time the best representation of how the downhole tool 24 is exposed in the hole loads resulting from a variety of twisting forces, vibrations and movement. This is especially important under adverse circumstances, when the transfer of loads in the borehole caused by the geometry of the wells, well completion, liquids and other characteristics of the well. Various measurements provide the best opportunity to analyze and improve the reliability of after appropriate corrective action.
Sensors 36 and subunit 28 registration load can also be used in conjunction with various systems of measurement and control, located on the surface. For example, systems are available that provide an indication of the weight of the flexible tubing or which prevent unplanned overload. These additional systems can be controlled by the device 30 controls on the surface or to work in conjunction with the device 30. In many cases, the application device 30 controlling the Oia on the surface can be programmed to operate in the automatic mode, taking appropriate corrective actions based on predefined parameters, when specific data are provided by the sub 28 registration loads, sensors 36 and/or other co-working measuring and control systems.
Depending on the type of downhole device 24 and the type of downhole tool 24, their shape, size and configuration of the subunit 28 registration load may vary. However, figure 2 shows one example of a subunit 28 registration load. In this embodiment, the sub 28 is enclosed in the upper housing 42, the sensor 44 of the load and the body 46 of the weight sensor. The upper housing 42 is composed of the end connector 48 opposite the sensor 44 weight to ensure connectivity subunit 28 to the connecting node 34 via, for example, a threaded connection or other suitable mechanical connection. At the opposite end sub 28 includes a connector 50, which may be any of a variety of connectors, depending on the downhole tool 24 to which it is attached, for specific, related to well operations.
Figure 3 and Figure 4 presents the cross-section of the subunit, an implementation option, which is presented in figure 2. As shown in the drawings, the subunit 28 includes the Tr is boaty element 52, originating from the sensor 44 load and partially defines the piping 54, passing through the sub 28 for filling with hydraulic fluid through the sub 28. Additionally subunit 28 includes an electronic part 56, which may be mounted on the circuit Board 58 for processing the signal received from the sensor 44 weight. The mounting plate 58 may be mounted between the tubular element 52 and, as illustrated, the upper housing 42. Signals are transmitted from the block 56 electronics connector 60 lines of communication, which is intended for connection with the corresponding connector in the connection node 34, which transmits the signal to the surface.
The subunit 28 includes a chassis 64, which is located in the upper housing 42 in such a way that prevents the passage of flow through the fluid channel 54. The tubular element 52 can be formed as an integral part of the chassis 64. Besides the chassis 64 is firmly connected to or forms a unit with the sensor 44 of the load, as shown in Figure 3. The device 68 of the seal, equalizing the pressure, is installed at the bottom or at the end facing into the borehole, the casing 46 of the load cell through the sealing element 69. The device 68 of the gasket extends into the inner part of the chassis 64 and forms a seal with the chassis 64 across the sealing element 70, as shown in the drawing. In the illustrative embodiment, the device 68 of the seal is formed as a piston, a compensating pressure.
Connections subunit, such as the connection of the upper housing 42 with sensors 44 load, can be formed of detachable connectors 71, which allow you to connect the components, without requiring relative rotation electrical connections. With respect to the electrical connection wires can be carried out from the connection node 34 and an end connector 48 down along the outer diameter of the chassis 64. As an example, wires can be connected to the top facing into the borehole side of the circuit Board 58. From the bottom converts into the hole of the mounting bracket 58 wires then pass along or through the chassis 64 and the composite sensor 44 load. The wiring is implemented on the outer diameter of the sensor 44 load through one or more ports 72, best shown in Figure 4. The wiring radially on the outer side of the sensor 44 load/chassis 64 enables the wires to be respectively connected to the load cell. For example, wires can be connected to the measurement sensors of the load, such as load cells or other measurement sensor 44 load.
Wiring harnesses and location of the components is now in subblock 28 registration load allow you to register and manage loads without load measurement, distorted by external elements. For example, measuring the load is isolated from the effects of radial and tangential forces caused by the pressure of the fluid pumped through the fluid channel 54, and similar effects caused by the pressure that is external to the instrument. Measuring the load is isolated from axial forces caused by the hydrostatic pressure in the well. Thus, as shown in figure 5 and 6, one can get more accurate measurements of load forces, such as forces of compression and stretching forces.
Figure 5 shows the trajectory 74 compression load. The trajectory 74 compression load caused due to the placement subunit 28 under the action of the compression load and illustrates the components of a subunit 28, which carry the force of a load on the sensor 44 load. From facing the bore end of the subunit 28 load power passes through the housing 46 of the load sensor and transmitted to the chassis 64 and the sensor 44 load through the threaded connection 76. Load power compression pass through the sensor 44 of the load and the chassis 64.
Figure 6 shows the trajectory 80 load in tension. The trajectory 80 tensile load resulting from the placement subunit 28 under the action of the load in tension and illustrates the components of a subunit 28, which carry the force load sensors 44 load. the C end sub 28, converted into the well, the force of the tensile load is transferred through the housing 46 and is transmitted to the gear 64 and the sensor 44 load through the threaded connection 76. Power load tensile passes up through the sensor 44 load and transmitted to split a smooth annular plug 71 with the shoulder. Split ring key 71 transmits tensile stress in the upper housing 42 and up through the column of tools.
Under load torque, the load torque can be transmitted between the upper housing 42 and sensor 44 load through one or more switches 82 torque, as shown in Fig.7. The switches 82 torque connected between the sensors 44 of the load and the top of the housing 42 so that any twisting load acting on the pipe 26, is transferred to the sensor 44 load through the upper housing 42 and the switches 82 torque.
The location of the components in the system 20 and the sub 28 registration load facilitates ensuring the accuracy and receive instant information that can be used to prevent accidents and to streamline operations in the well. For example, data obtained in real time, can be transferred to the device 30 on the surface, through, for example, fiber Thelema is a theory. Fiber optic telemetry and placement subunit 28 allows the transmission of data at a time when the operation in the downward borehole has already begun, including situations where through fluid channel 54 is pumped liquid. The design not only allows you to provide mechanical pressure compensation and radial temperature compensation, but also avoids the effect of forces screwing on the load cell region of the sensor 44 of the load.
The purpose of the following explanation, the sub 28 is designed to compensate for both forces, radial and tangential, which is caused by the pressure of the liquid being pumped along the hydraulic channel 54, and for such influences caused by external pressure on the tool. Additionally, sub 28 is designed to compensate for axial forces caused by the hydrostatic pressure in the borehole 22. Compensation of these external pressures/forces is achieved partly by the design of the sensor 44 loads that have the mounting area 84 of the load sensor, for receiving one or more sensors 86 measurement of load, such as load cells, optical sensors, load or other load sensors provided on Fig.
Part of the external diameter of the sensor 44 of the load, in which the sensor is installed 86 load measurement, surrounded by a sealed air chamber 88. The chamber 88 is sealed g is retacnyl element 90, acting together with the elements 69 and 70. Advanced chassis 64, forming a tubular element 52 and the fluid channel 54, is sealed on the end facing into the borehole relative to the mounting platform 84 of sensor loading using device 68 of the seal, equalizing the pressure. Additional radial clearance can be added between the outer diameter of the gear 64 and the inner diameter of the mounting platform 84 of the sensor 44 of the load, ensure that the contact caused by pressure or temperature caused expansion chassis, it is not going to happen. Thus, only the inner diameter of the sensor 44 of the load subject to the influence of atmospheric pressure.
Besides sealed area, which may affect the hydrostatic pressure, extends from the inner diameter of the device 68 of the seal, equalizing the pressure in the area where it seals the inner diameter 46 of the load cell through a tight element 69 in the direction of the outer diameter of the device 68 of the seal, where it seals to the internal diameter of the sensor 44 load/chassis 64 through the sealing element 70, as shown in Fig. In the axial direction of the device 68 of the seal allows the voltage caused by the hydrostatic pressure around the mounting area 84 of the load cell. This effect is due to the fact that sa is th far encapsulated diameter is the same, what with that from the other side air chamber 88. Resulting force is transmitted to the device 68 of the seal, which acts as a compensating piston. In relation to the radial temperature conditions of the atmosphere surrounding the mounting area 84 of the load cell with both internal and external side of the sensor 44 load suppresses any radial temperature gradients in the sensor section 44 of the load containing the load cell 86.
With some types of BHA, such as BHA, which is pushed inside the chassis subunit, may be subjected to significant compression forces caused screwing during impacts in the well. However, when the subunit 28 "screwed" in the upper end of the chassis 64 is pushed from the inside, which causes the compression force sensor 44 load of split ring dowels 71 along its length in the upper direction and in the chassis 64 from its connector with the sensor 44 load along its length in the upper direction. Mounting platform 84 of the load cell not exposed to these forces "screwing". Additionally, when the end of subunit 28, converted into the well, "screwed", the voltage is perceived only by the sensor 44 of the load from the threaded portion 76 of the housing 46 of the load sensor in the area where the housing 46 of the load cell acts against the load cell, as shown at F. g. Thus, the mounting area 84 of the load cell are not affected by the forces of "screwing".
Figure 9 shows an alternative implementation of the subunit 28. In this embodiment, the subunit 28 registration load includes a passage 92 for submission to the downhole equipment bus 94, for example, in the form of wires or cable to provide communication and/or power required for devices installed below subunit 28. Many components in this embodiment are the same as described above with reference to Figures 1-8, however, the passage 92 extends from the top of the block 96 of the connector to the lower block 98 of the connector. Bus equipment, such as a wire, is connected between the mounting plate 58 and the block 96 of the connector. From block 96 of connector wires pass through the passage 92, which extends through the sensor 44 of the load until it reaches the bottom of the block 98 of the connector. To prevent rotation of the connection split ring key 100 can be installed in close proximity to the lower end of the sub 28.
Tensile strength and torsion is transmitted through the multiple switch 102 load, as shown in Figure 10. Switches 102 loads are determined in the respective grooves 104 formed in part of the sensor 44 load. When alternative sub 28 is subjected to loads in compression, nagruzka.pervicnaya directly from the sensor 44 of the load on the chassis, as is described above. However, under load tensile load is transmitted to the upper housing 42 through switches the load 102 and the bypass, thus, the chassis 64. Load switches designed with their comfortable fit in the notches 104 and the corresponding grooves of the upper housing 42. As a result the load torque is also transmitted from the sensor 44 load in the upper housing 42, thus bypassing the chassis 64. In this alternative embodiment, the chassis 64 is hermetically closed from the inside with respect to the sensor 44 load in the hole load cells/strain gauges. This construction provides the same radial compensation of pressure and temperature, described in the previous implementation. Effects svintsovaya" forces on the mounting area 84 of the load cell are avoided in the same manner described relative to the previous implementation.
As described above, the system 20 can be constructed in a variety of configurations for use in many implementations and applications. Sub registration load can be designed to isolate the load cell from excessive internal influences on the sub, external influences on the subunit, the axial impacts arising from regular swieciany tool, as well as the influences of temperature and is Alenia and/or other external loads. Additionally, the size and location of sub registration load can be selected taking into account environmental factors and operations. Types of load cells and sensors embedded in the sub registration load, as well as additional sensors, used in conjunction with the sub, can vary considerably depending on the desired operation and settings can be managed. Electronic devices can be replaced by an optical system, which are connected with optical sensors. Additionally, the control unit 30 located on the surface, is a combination of different systems and can be programmed in many different ways, in order to facilitate the management, analysis and make corrective actions either automatically or with operator assistance.
Thus, although the present invention above is described only certain embodiments of the specialist in the art it is obvious that there are many possible modifications without departure from the essence of the claimed invention. Such modifications suggest that they can be included in the scope of the present invention defined by the claims.
1. The method of registration, measurement and load control in a borehole, namely, that: ISM which accelerate the load at the downhole location during downhole operations, moreover, the measurement includes the measurement of the load through subunit attached to the layout of the bottom of the drill transmit data load to the surface in real time via telemetry; evaluate data load control device located on the surface; and make corrective action in the well, based on the data load.
2. The method according to claim 1, wherein the transmission includes a data transfer load through fiber optic deployed along the tubular pipe.
3. The method according to claim 1, wherein the measurement includes the measurement of the loads acting on the layout of the bottom of the drill during the operation, which is one of: crushing, operations, installation of the packer, operations actuate the downhole tool, the fishing operations and the operations of punching.
4. The method according to claim 1, wherein the measurement includes the measurement of loads to ensure that would not have arisen causing excessive damage to the load on the downhole tool.
5. The method of registration, measurement and load control in a borehole, namely, that
register load downhole equipment in a well, and registration includes the use of subunit registration load attached to to the panovka the bottom of the drill string; and use telemetry data load control device located on the surface, in real time.
6. The method according to claim 5, in which the registration load includes registration of one of the compressive forces acting on the downhole equipment, stretching forces acting on the downhole equipment in a well, the torque acting on the downhole tool in the borehole, and impact forces acting on the downhole equipment in a well.
7. The method according to claim 5, further including using additional sensors for capturing other necessary parameters in the borehole; and data transmission of additional sensors to the control unit, located on the surface, in real time.
8. The method according to claim 7, in which the use contains to check vibration and tilt.
9. The method according to claim 5, in which the registration includes the registration of loads during the use of flexible tubing; and includes data transmission via fibre optics deployed along the tubular pipe.
10. The method according to claim 5, in which register contains the use of subunit registration load, having a housing, the device of the seal formed in the form of a piston, equalizing the pressure, and load cell.
11. System for Regis the radio loads in the well, contains: sub load register having a through channel for the liquid, while the subunit registration load includes: a housing; a piston, equalizing pressure; and a load sensor, in which the housing and the piston, equalizing the pressure, work together to isolate the load cells from the damaging effects of stress.
12. The system according to claim 11, in which the load sensor is isolated from the unwanted effects of load, which are both internal and external, affecting subunit registration load.
13. The system according to claim 11, in which the subunit registration load further comprises an electronic device designed to transfer load to the surface in real time via fiber-optic telemetry.
14. The system according to claim 11, in which the subunit registration load further comprises a set of switches to transfer the load to the body of the load cell.
15. The system according to claim 11, in which the load sensor includes a load cell mounted in a sealed air chamber and insulated from the effects of radial and tangential forces caused by the pressure of the liquid pumped through the channel across the aisle, and from axial forces caused by the hydrostatic pressure in the well.
16. The system according to claim 11, in which the sensor is agrusti contains the load sensor, mounted in a sealed air chamber and insulated from the impacts of unwanted axial forces.
17. The system according to claim 11, in which the load sensor includes a load cell mounted in a sealed air chamber and insulated from the impacts of unwanted load forces resulting from regular work on the screwing tool.
18. The system according to claim 11, further containing a tubular pipe having a fiber optic communication line that can pass the data from the sub register load control device located on the surface.
FIELD: oil and gas industry.
SUBSTANCE: stimulation method of formation fluid influx from the well consists in lowering to the well of a tubing string. Counter pressure on the productive formation is decreased owing to replacing the liquid column with liquid-gas mixture (LGM) at observance of the required value of depression on the productive formation. Before the tubing string is lowered, its lower end is equipped with a remote subsurface pressure gauge and a filter. The tubing string is lowered to the well so that the filter is located opposite the formation perforation interval; after that, treatment of the bottom-hole zone of the formation is performed using a chemical method with process exposure for reaction. Then, the tubing string is lowered further so that the filter is located below the formation bottom, and into the inter-string space there lowered is a string of flexible tubes (FT) 100 m below the liquid level in the well. The liquid column is replaced in the inter-string space of the well with LGW and lowering of the FT string is continued. When lower end of the filter of the tubing string is reached, lowering of the FT string is stopped; then, stimulation of the formation fluid influx is started by gradual reduction of density of pumped LGM till the required depression on the productive formation, which is controlled as per readings of the remote subsurface pressure gauge, is achieved. After completion of stimulation of the influx from the well there removed is FT string from the inter-string space of the well, and operating equipment is lowered to the well and the well is put into operation.
EFFECT: improving efficiency and quality of stimulation of formation fluid influx from productive formation.
FIELD: oil and gas industry.
SUBSTANCE: system includes flexible tubing having a fibre optic conductor and a section with instruments. At that, fibre optic conductor is located in a cavity flush with outer surface of the section of flexible tubing equipped with instruments. Besides, the above cavity is curved. The system also includes a device for fixing the fibre optic conductor on the surface of the wall of flexible tubing, an adapter through which the above conductor passes to an internal fibre optic conductor, and a connecting coupling. The latter has the possibility of data transferring by means of contactless telemetry.
EFFECT: improving measurement efficiency of one or more parameters in the well along a certain zone of the well.
21 cl, 9 dwg
FIELD: oil and gas industry.
SUBSTANCE: method for determining the flow rate and the density of formation fluid of oil formations consists in shaping of signals when a sensitive element passes through the specified levels in the well. Measurement of time intervals between signals, with further calculation of the flow rate of the formation in relation to distance between specified levels to time interval between the appropriate pulses. Measurement of movement speed of several sensitive elements is performed. Flow rate of each next above-lying oil formation or layer is determined as difference between previous and current measurements. Density of formation fluid is determined as integral density value of the last sensitive element that floated up to the surface and that one that did not float up to the surface.
EFFECT: improving measurement reliability of flow rate and density of formation fluid.
FIELD: oil and gas industry.
SUBSTANCE: when surveying a gas well, its head is equipped with a separator, a gas flow rate measuring device and a flow line for flame. Gas pressure and temperature is measured on the installed device and the well flow rate is determined based on performed measurements and structural characteristics of the device. In addition, the well head is equipped with an electric power plant generating electric power at combustion of produced gas. When surveying high-flow-rate wells, the electric power plant is installed between the gas flow rate measuring device and the flame line. When surveying low-flow-rate wells, the electric power plant is installed before the gas flow rate measuring device.
EFFECT: use of produced gas during survey of gas wells for generation of electric power.
SUBSTANCE: device is installed inside horizontal part of flow line of a production well at fixed distance before a sampling point of periodic fluid samples. The turbulator consists of one piece and is provided on a common axis with seven vertical plates, the first six ones of which, being made in the form of segments, are intended for mixing of different layers of pipeline fluid due to vertical fluid flow, and the last plate made in the form of a circle is provided in a circumferential direction with several uniformly located openings focused to the sampling point.
EFFECT: improving objectivity of evaluation of production capabilities of wells and composition of the field fluid transported via pipes.
2 cl, 3 dwg
FIELD: oil and gas industry.
SUBSTANCE: method involves excitation of a well, measurement of parameters by means of bottomhole instrument installed inside perforated tubing in horizontal sections of the well with different geophysical characteristics and processing of measurement results. As bottomhole equipment, remote instruments are used, which are connected to each other by means of a geophysical cable; geophysical cable is led out by means of an outlet adapter from the tubing string to the inter-tube space. In vertical part of the well there installed is a borehole pump, and a downhole pump equipment is lowered together with the lowered geophysical cable. At that, the geophysical cable is fixed on the tubing string with belts; the cable is led out to the surface through a process hole made in a tube holder, where it is sealed and connected to a surface recording unit.
EFFECT: possibility of obtaining operational information on properties of productivity of a horizontal shaft in real time during the well operation.
FIELD: oil and gas industry.
SUBSTANCE: when the method is being realised, at least one container is installed on the lowered equipment and then lowered to the well to the pre-determined distance from the well head and it includes a tracer mark, with further monitoring of wellbore fluid or gas for content of the tracer mark. The container housing is made from the material capable of being dissolved or decomposed under action of water or gas and resistant to action of hydrocarbon medium.
EFFECT: increasing the obtained information on filtration in the formation and on ongoing processes in the well with concretisation in time and space.
FIELD: oil and gas industry.
SUBSTANCE: method involves several well hydrodynamic survey (WHS) cycles at early development stage of oil wells at forced creation in the formation of differently directed two-phase filtrations. Representative reference sample collection of wells is determined. WHS surveys are performed in each of the wells, on the basis of which evaluation of current phase permeabilities as to oil ko_rel and water kw_rel, and initial water saturation Kw_initial.is performed. Values ko_rel, kw_rel and Kw_initial are compared, and relationships of the change between phase permeabilities and water saturation are determined. The corresponding general curves of phase permeabilities as to the unit are calculated. And during the operating period characterised by the change of average water cutting of well production of not less than 30% in comparison to the initial one, current water cutting of well production φw is determined simultaneously with WHS.
EFFECT: improving reliable and objective reproduction of relative phase permeabilities by providing the possibility of spreading relative phase permeabilities obtained for a certain well to other sections of the formation.
2 cl, 2 dwg
FIELD: oil and gas industry.
SUBSTANCE: method for determining orientation of a downhole instrument in a borehole is implemented as per the data of a three-axis accelerometer unit in the borehole section having sufficient inclination for steady work of the accelerometer unit. Turning angle of the sighting point of the downhole instrument is calculated relative to upper side of the borehole and zenith angle of position of the downhole instrument axis. Azimuth angle of position of the downhole instrument is determined as per the inclinometer survey data prior to the performed measurements. Then, in the section of the borehole having sufficient inclination for steady work of the accelerometer unit, there performed is start and uncaging of a gyroscope, the main axis of which is coaxial to the axis perpendicular to the device axis at the uncaging moment. Spatial position relative to cardinal points is calculated for current position of the main axis of the gyroscope through the calculated turning angle of the sighting point of the downhole instrument relative to upper side of the borehole and known azimuth angle of position of the downhole instrument. Then, downhole instrument is delivered to the vertical section of the well, where, using the gyroscope readings, the change of position of the downhole instrument housing relative to the position of the main axis of the gyroscope is determined, and spatial position of the sighting point of the downhole instrument is calculated as per cardinal points.
EFFECT: enlarging the range of use of the downhole instrument at calculation of its orientation as to cardinal points when using it inside the string of steel pipes and in vertical sections.
FIELD: oil and gas industry.
SUBSTANCE: recovering method of the working condition of gas-oil production well involves three stages. At the first stage, geophysical measurements of the well parameters are performed, as per which the profile of influx of the investigated section of the well is determined and non-working intervals are identified. At the second stage, flushing of technogenic fluids of the well sections with non-working intervals is performed. At the third stage, check measurements of the well geophysical parameters are performed so that quantitative and qualitative yield characteristics of non-working intervals are determined. Technological complex used for the method's implementation includes two units with a flexible tubing string, one of which includes a geophysical cable for connection and transportation to the well of a geophysical instrument, and the second unit with the flexible tubing string serves for flushing of bottom-hole part of the well. The second unit with the flexible tubing string has the possibility of being connected to the hydraulic diagram of the first unit with the flexible tubing string and to the well flushing equipment.
EFFECT: increasing the yield of the well in operation owing to connecting non-working sections of horizontal or inclined shaft of the well.
20 cl, 12 dwg
FIELD: mining industry.
SUBSTANCE: invention can be used in case of gas-lift operation of wells equipped by free piston-type installations. Invention envisages stopping well, connecting tube space and annular space in wellhead, recording bottom zone and wellhead pressures in tube and annular spaces, and computing well operation parameters using inflow curve plotted according to differences of bottom zone and wellhead pressures. Volume of produced fluid is found from potential output of formation and from condition of output of free piston. When comparing these volumes, parameters of well are computed in the base of minimum volume value.
EFFECT: optimized well operation.
FIELD: oil and gas extractive industry.
SUBSTANCE: device has body placed in body of stream pump and has locking valve and axial channel for logging cable with fixed logging device. Device also has discharge valve. Device body has ports in middle portion, which connect middle hollow portion of device to displacement chamber for stream pump. In upper and lower portions of body of device upper and lower compactors are placed, limited by support elements on each side of the latter, respectively. Locking valve is mounted in lower portion of device and mated with inner space of tubing string and logging device. Axial channels of valves are eccentric and parallel to first channel of device, while discharge valve is provided with rod with its end prominent relatively to body of device.
EFFECT: broader functional capabilities, higher reliability.
FIELD: oil and gas extractive industry.
SUBSTANCE: method includes selection of cable of required rigidity and fixing devices on it. Transporting of devices into well is performed under effect from weight of cable and devices. Cable also contains inner hermetic pipe, which is plugged on both sides prior to lowering cable into well. Liquid is pumped into pipe under pressure through locking valve in upper plug and is kept in pipe under constant pressure during operation. After that cable is lowered with devices fixed to it. Value of pressure of liquid in pipe is determined from formula Ppipe≥ Pwell(Scable/Spipe-1)-QcablexLcable/Spipe<Ptear, where Ppipe - pressure of fluid in pipe, kg-wt/sm2; Scable - cross-section of cable with pipe, sm2; Pwell - hydrostatic pressure of well liquid column at depth of planned delivery of devices on cable, kg-wt/sm2; Spipe - cross-section area of pipe aperture and plug area equal to it in contact with liquid in pipe, sm; Qcable - weight of 1 km of cable with pipe, kg-wt; Lcable - length of cable to depth of planned delivery of devices, km; Ptear - pressure of liquid in pipe leading to tear of cable, kg-wt/sm2, determined from formula: Ptear=Ftear/Spipe, where Ftear - tear force for cable according to documentation, kg-wt.
EFFECT: higher efficiency.
3 cl, 1 dwg, 1 tbl
SUBSTANCE: device has body, spring-loaded levers jointly connected to it, levers position indicator, made in form of constant magnet mounted at joint connection end of each measuring lever, and signal converter, mounted in body in protective chamber. Constant magnet is made in form of washer and is mounted in circular groove on rotation axis of each lever, and as signal converter magnetic-resistive sensor is used in form of resistive bridge circuit sensitive to direction of magnetic field and non-sensitive to its intensity, while magnetic axis of constant magnet is in plane of washer and is directed perpendicularly to sensitivity axis of magnetic-resistive sensor.
EFFECT: higher precision, simplified construction, lesser dimensions.
FIELD: oil and gas extractive industry.
SUBSTANCE: device has body with ports in lower and upper ends, main sensitive elements in form of turbines and packing elements, placed in pairs at body ends, side port made in body between main sensitive elements and converter, connected to surface equipment. In side pipe, mounted inside the body between main sensitive elements, additional sensitive element is placed in form of turbine and thermal sensor. Lower end of side pipe is connected to side port. Diameter of turbine of additional sensitive element is less than diameter of turbines of main sensitive elements. Converter is a control block mounted above body including sleeves locator and electronic microprocessor device.
EFFECT: higher precision.
FIELD: oil and gas production.
SUBSTANCE: invention relates to gas-liquid systems coming from oil production wells. Mixture is separated into liquid and gas in separator. Liquid is periodically accumulated in separator container and then displaced with gas. During this operation, differential pressure for liquid reaching its lower and upper recorded levels and time required for filling recorded volumes are measured as well as absolute pressure and temperature of gas in container. Liquid flow value expressed in weight is calculated using special mathematical dependence. At oil field, liquid and gas enter separator from preliminary gas intake installation or from the first separation step.
EFFECT: increased accuracy of measurement due to avoided gas density registration and excluded necessity of using strictly cylindrically-shaped measuring container.
FIELD: engineering investigations in building, particularly devices for determining deformation and strength properties of ground in well.
SUBSTANCE: device comprises probe (working tip), control-rod, pipeline, communication line, loading jig and measuring station. Probe includes hollow cylindrical body with bottom and cap filled with working liquid, elastic shell sealed from body bottom and top. Formed in non-fixed elastic shell area are perforations. Piston with rod is installed in upper part of hollow body above working liquid. Rod passes through cap in sealed manner. Rod is connected with control rod so that piston may move in axial direction. Formed above piston is cavity connected to pipeline. Hollow body has bottom in which air-tight plug is installed. Measuring device is made as linear piston displacement transducer. Through orifices are formed in hollow body wall near body bottom. Arranged from body outside are vertical or inclined grooves aligned with through orifices by lower ends thereof. Air-tight plug is provided with adjustable rest for restricting piston stroke.
EFFECT: simplified structure of probe and measuring devices, increased operational reliability and improved validity of obtained data.
2 cl, 1 dwg
FIELD: oil and gas extractive industry.
SUBSTANCE: method includes performing a test pumping of liquid waste into absorbing well before operational pumping, while changing flow step-by-step. From equation of absorption base hydrodynamic parameters are determined for calculation of predicted coefficients of operation characteristics of absorbing well and reserve well. During operational pumping of liquid waste together with thermometry along absorbing well shaft, registration of actual pressures and flow on pump devices, actual pressures on mouth in tubing pipes of absorbing well, actual pressures on face are additionally registered in absorbing well as well as pressures on mouth in behind-pipe space, actual loss at mouth in behind-pipe space, actual loss of waste on mouth, actual positions of face well, upper and lower limits of absorption range from well mouth. In reserve well actual pressures on face are registered, as well as actual positions of liquid level from reserve well mouth, upper and lower limits of absorption range. Prediction coefficients are compared for operation characteristics of absorbing well and reserve well to actual coefficients. 9 conditions of hydrodynamic bed conditions at reserve well and absorbing well are considered during pumping of waste. Specific actions of operator on each condition are described.
EFFECT: higher reliability and trustworthiness.
SUBSTANCE: method includes lowering protective container to the well to portion of intensive curvature of shaft, which container is fixed at end of drilling pipes, lowering of geophysical device into protective container on lower portion of logging cable, delivery of protective container with geophysical device to pit-face by consecutive extending of drilling pipes column, lowering of upper portion of logging cable through remote-controlled compactor of logging cable fixed on branch of swivel, into drilling pipes, until electric contact to free end of lower portion of logging cable via detachable connecting sleeve, geophysical examining of shaft during raising of geophysical device together with drilling pipes with appropriate connection-disconnection of fixing ends of lower and upper portions of logging cable when screwing away each following drill stand. When examining wells having extensive steeply slanted portion of well shaft with zenith angle of 50°-90°, where lowering of upper portion of logging cable to electrical contact with free end of lower portion of logging cable via detachable connecting sleeve under its own weight is difficult due to friction at drilling column wall, forced lowering of detachable connecting sleeve is performed by feeding washing liquid under pressure into drilling pipes and concurrent adjustment of pressure in chamber of remote-controlled compactor of logging cable. Pressure in chamber of remote-controlled logging cable compactor is achieved to be close to pressure of washing liquid in drilling pipes, to provide for optimal speed of cable lowering and its pressurization, and after connection of detachable connecting sleeve to lower portion of logging cable during raising and lowering of drilling pipes, examinations of well are performed.
EFFECT: higher efficiency.
FIELD: oil extractive industry.
SUBSTANCE: mixture is separated on liquid and gas in separator. Liquid is periodically collected and forced away by gas while measuring absolute pressure and gas temperature in separator tank near upper and lower fixed liquid levels, and times of forcing away of fixed liquid volume. Additionally measured are absolute pressure and temperature in moment when liquid reaches intermediate fixed level. Then liquid is forced from intermediate fixed level to lower fixed level separator is switched off from well, and mass loss of gas is calculated from provided relation. Device for realization of method consists of separator with feeding pipe, in which a three-drive valve is mounted, and draining pipe, which through said valve is connected to liquid outlet channel and to gas outlet channel. Separator is provided with sensors of temperature and pressure and sensors of upper, intermediate and lower levels, mounted in such a manner, that they separate fixed volumes between each other in separator tank, in case of equality of which calculations are simplified.
EFFECT: higher precision.
2 cl, 1 dwg