Method and device for evaluation of drill bit conditions

FIELD: mining.

SUBSTANCE: invention relates to drill bits. Brill bit comprises body with at least one gaging plate and set of accelerometers. Said set comprises radial and tangential accelerometers for determination of radial and tangential acceleration of drill bit. It includes data analysis module incorporating processor, memory and communication port. This module is designed to fulfil the jobs that follow. Sampling the data on acceleration from accelerometers during the analysis. Loading said data to memory to get the acceleration time history. Analysis of acceleration time history for determination of distance made by at least one gaging plate. Analysis of acceleration time history for determination of at least one plate cutting period and at least one plate sliding period. Evaluation of gaging plate wear proceeding from determination of distance made by at least one gaging plate and at least one sliding period. In compliance with proposed method, data is collected from accelerometers by periodic sampling of data from at least two accelerometers arranged in drill bit to get acceleration time history during the analysis. Acceleration time history data is processed for determination of profile of distance made by at least one gaging plate. Rock current hardness is defined for analysis of the profile of distance made by at least one gaging plate. Now, current rock hardness is defined to evaluate the gaging plate wear.

EFFECT: adequate determination.

14 cl, 13 dwg

 

The claim to priority

This application claims the priority of patent application US 12/391665, filed February 24, 2009, for "Method and device for assessing the condition of the drill bit".

The technical field

Embodiments of the present invention relates to drill bits for drilling subterranean species, in particular to methods of monitoring the operating parameters of drill bits during drilling, and related devices.

The level of technology

In the oil and gas industry spent considerable resources in the development of cutting tools such as drill bits for drilling wells, including a roller bit, also called crushing bits, and the bits with fixed cutters having a relatively long life with relatively rare failures. In particular, considerable sums are spent on the development and manufacture of cone crushing bits and drill bits, fixed cutter bits, the design which minimizes the possibility of sudden failure on the drill bit during drilling. The loss cone or inserts made of polycrystalline diamond (PKA) of the bits with fixed cutters during drilling may delay the work and, in the worst case, make necessary an expensive Lovell who's works well. In case of failure for fishing operations must be boring inclined shaft around the part of the borehole, including the lost cone or PKA cutters. Usually during drilling bits extracted and replaced by new bits even when a replaceable chisel haven't used a significant portion of their life. Such premature replacement of downhole drill bits are very expensive, since each stroke of the tool from the borehole extends, terms leads to loss of valuable time drilling rig operation and requires a large labor costs, but their conduct to avoid much more painful and costly procedures for removing, in the best case, the drill string and replace the bit or the conduct of fishing operations and kickoff inclined shaft, which may be necessary if one or more milling cutters or inserts will be lost as a result of the destruction of the bit.

With the increasingly growing needs in the dynamic data about the operation of the downhole drilling was developed and installed in the drill columns large number of "adapters" (i.e. secondary nodes entered in the drill string above the drill bit and used to collect data regarding drilling parameters). Unfortunately, these adapters are not able to provide data about the ohms, what is really happening in the process of the bit, due to the fact that physically they are located above the bit.

Data collection is usually done by installing the adapter in the layout of the bottom hole Assembly (BHA)at a distance from a few feet/meters to tens of feet/meters away from the bit. Data received from the adapter, located so far from the bit may not accurately reflect what is really happening with the bit during drilling. Often this lack of data leads to assumptions regarding the causes of damage to the bit or his good work, not taking into account the factors or data that is directly associated with the operation of the bit.

In recent time there are proposals to establish data collection systems in the drilling bit. However, the capabilities for collecting, storing and outputting data in these systems were limited. In addition, regular data collection in drilling bits did not possess the ability to adapt to events in the drilling process, which could be interesting from the point of view of obtaining and analyzing more detailed information upon occurrence of these events.

There is a need to create a drill bit, equipped with means of collection, storage and analysis over an extended period of time data related to the characteristics of cutting and status is brought about by the drill bit and gage pads on the drill bit.

Disclosure of inventions

The present invention provides methods and devices for receiving and processing information relating to the characteristics of the cut and condition of the drill bit and gage pads on the drill bit. In a particular example, information about the condition of the drill bit can be used to determine the point of resource exhaustion bits and need to be replaced and the necessary changes in the conditions of carrying out drilling to extend the service life of the bit. Information about the condition of the drill bit, is received from an existing drill bit, also could be used to develop further improvements in drill bits.

In one embodiment of the invention drill bit for drilling subterranean species includes the body of the bit and extending from the body of the bit shank adapted for connection to the drillstring. Inside of the shank is formed an annular chamber. In the drill bit is a group of accelerometers, including radial accelerometer to determine the radial acceleration of the drill bit and the tangential accelerometer to determine the tangential acceleration of the drill bit. With a group of accelerometers are functionally connected, the data analysis module, located in the annular chamber. The data analysis module VK is uchet processor, the storage device and the communication port. The data analysis module is adapted for receiving selection data about the acceleration from the radial and tangential accelerometer accelerometer during the period of analysis and remembering information about the acceleration in the storage device for shaping the time course of the acceleration. In addition, the data analysis module adapted to analyze time course of the accelerations to determine the distance traveled at least one calibrating plate to define at least one period (interval) of cutting pads and determining at least one period-slip pads. The data analysis module is also adapted for evaluation of the wear of the gage plates taking into account the distance travelled at least one period of cutting pads and at least one period of slip lining.

In another embodiment of the invention drill bit for drilling underground formation includes a casing bit, which has at least one gage pad and a shank extending from the body of the bit and adapted for connection to a drill string. Inside of the shank is formed an annular chamber. In the drill bit is at least one radial accelerometer to determine the radial acceleration of the drill bit and hence the it least one tangential accelerometer to determine the tangential acceleration of the drill bit. With a group of accelerometers are functionally connected, the data analysis module, located in the annular chamber. The data analysis module includes a processor, storage device and the communication port, and is adapted to receive information via the communication port on the hardness of the rock. The data analysis module is also adapted for receiving selection data about the acceleration from the at least one radial accelerometer and at least one tangential accelerometer during the period of analysis and data analysis of the accelerations to determine the speed of rotation of the drill bit. The data analysis module is also adapted for the evaluation of wear based on the analysis of the speed of rotation and information about the hardness of the rocks.

Another variant implementation of the invention is the way in which periodically collects sensor data by sampling over the period of analysis from at least one tangential accelerometer located in the drill bit, and at least one radial accelerometer located in the drill bit. The method also includes processing the data of the sensors in the drill bit to obtain the time dependence of the tangential acceleration and the time course of the radial acceleration. Analyze the time course of the tangential acceleration and the time course of the radial acceleration to determine soon the free rotation of the drill bit, at least one period-slip pads and at least one period of cutting pads. The change in the state of wear of the gage plates is estimated on the basis of the analysis of the speed of rotation of at least one period of cutting pads, and at least one period of slip lining.

Another variant implementation of the invention is the way in which gather information about the acceleration through periodic sampling from at least two accelerometers located in the drill bit, for the period of analysis to obtain the time course of the acceleration. The time course of the acceleration process in the drill bit to determine the profile of the distance to at least one of the gauge pads on the drill bit. The method also includes determining the current hardness of the breed. Profile distance for at least one gage plates and current hardness of the rocks analyzed to estimate and report on the temporal course of the wear gauge overlay.

Brief description of drawings

Below the invention is described in more detail with reference to the accompanying drawings, on which:

figure 1 illustrates a typical drilling rig to conduct drilling operations;

figure 2 presents a perspective view of conventional bladed drill bit for rotary drilling is trichloro type;

on figa presents a perspective view of the shank with the end cap and inserted in him the embodiment of the electronic module;

on figb presents a view of the cross-section of the shank and the end cap;

4 shows a drawing case for an electronic module in the form of a flexible printed circuit Board, allowing you to turn it into a ring for installation in the shank shown in figa and 3B;

on figa-5D shows in perspective the drill bit, showing the possible locations in the drill bit, which can be installed an electronic module, sensors, or combinations thereof;

figure 6 presents a block diagram of a variant of implementation of the data analysis module in accordance with the present invention;

figure 7 shows the illustration of the placement of multiple accelerometers;

on Fig examples data sample magnetometers two rotating axes of the rectangular coordinate system;

figure 9 shows examples of sample data of the accelerometers and magnetometers on the three axes of a rectangular coordinate system fixed relative to the drill bit, but rotates relative to the stationary observer;

on figa and 10B shows a possible standard (VCS) values of the radial and tangential accelerations for relatively short periods of time;

the piano is g is a graph of a possible time dependence of the wear of the gage pads covered by these overlays distance;

on figa is a graph of a time course of the tangential and radial accelerations during the rotation of the drill bit in a borehole;

on figb is a graph illustrating the possible time dependence of the wear of the gage pads depending on changes in drilling conditions on covered calibrating plates distance;

on figa given the graph of the changes in the hardness of the rock with the deepening of the drill bit in the borehole and

on figb is a graph illustrating the possible time dependence of the wear of the gage pads depending on changes in the hardness of the rock traversed calibrating plates the distance.

Detailed description of the invention

The present invention includes methods and devices for information related to the status of the drill bit and gage pads on the drill bit. In particular examples of the implementation of the information about the condition of the drill bit can be used to determine the point of resource exhaustion bits and need to be replaced and the necessary changes in the conditions of carrying out drilling to extend the service life of the bit. Information about the condition of the drill bit, is received from an existing drill bit, also could be used to develop further improvements borowy the bits.

Figure 1 presents an example of a conventional device for underground drilling. The drilling rig 110 includes a derrick 112, the floor 114 of the drilling rig, drilling rig winch 116, lifting hook 118, swivel, 120, square rod 122 and table 124 drilling of the rotor. The drillstring 140, including section 142 of the drill pipe, column 144 heavy-weight drill pipe, passes downward from the drilling rig 110 into the well 100. Section 142 of the drill string may include multiple tubular segments of the drill string or threads connected to each other, and the pillar 144 drill may include a few weighted tubes. In addition, the drillstring 140 may include a logging site measurement while drilling (MWD - from the English. measurement-while-drilling) and interacts with the host mud pulse telemetry channel, which together are called the MWD system 146 communications, and other system data.

During drilling operations the drilling fluid circulates from the reservoir 160 for drilling mud through the mud pump 162, the absorber 164 water hammer and line 166 submission mud swivel 120. Drilling fluid (also referred to as wash liquid) passes through a square rod 122 and into the hole along the axis of the drill string is 140. In the end, the drilling fluid exits through holes or wash nozzles located in the drill bit 200 is attached to the bottom of the drill string 140 under the column 144 drill. The drilling fluid flows back up through the annular space between the outer surface of the drill string 140 and the inner surface of bore hole 100 to the surface, where it is returned to the reservoir 160 to the drilling fluid line 168 return mud.

For the Department of rock fragments from mud before returning to the reservoir 160 to the drilling mud can be used vibrating screen (not shown). The MWD system 146 may be used mud pulse telemetry to transmit data from the well to the surface during drilling operations. To obtain data on the surface is used with pulse Converter 170 associated with the line 166 supply of drilling mud. This pulse Converter 170 generates electrical signals in response to pressure fluctuations in the drilling fluid in the line 166 supply of drilling mud. These electrical signals are transmitted via a wired line 172 on the surface of the electronic system 180 processing, typically a data processing system with a Central processor DL the implementation of programmes and execution of user commands, input either from the keyboard or through a graphical pointer. System mud pulse telemetry is used to transmit data to the surface relating to different States in the well received from downhole systems registration and measurement, which is usually located inside the MWD system 146 communication. Hydraulic impulses that define the data transmitted to the surface, generated by the equipment, usually located inside the MWD system 146 communication. This equipment typically includes a pulse generator pressure, controlled by the electronic circuit located in the housing of the device, allowing drilling mud to pass through the hole in the wall of heavy-weight drill pipe. Whenever under the action of the generator pulse pressure is a way of solution, is passed a negative pressure pulse, which pulse is received by the transducer 170. In a commonly used alternative to the system are generated and transmitted to the positive pressure pulses. Circulating the drilling fluid is also useful as a source of energy for driven turbine generator (not shown), which may be located near the BHA (bottom hole Assembly). Working from the turbine generator can generate electrical energy for the pulse generator Yes the population and for various schemes including schematic form the functional components of instruments for measuring while drilling. As an additional power source may be batteries, in particular, to reserve the turbine generator.

Figure 2 shows perspective view of the embodiment of the drill bit 200 so-called vane type. Usually drill bit 200 includes a thread on the shank 210 in the upper part of the drill bit 200 for connection to the drill string 140 (Fig 1). Opposite to the shank 210 of the end may be at least one vane 220 (shown)having multiple cutting elements of natural or synthetic diamonds in the form of inserts of polycrystalline diamond or PKA cutting elements 225, installed along the leading in the direction of rotation of the blade surfaces 220 for efficient destruction of formation material during the rotation of the drill bit 200 in a borehole 100 when force is applied to the bit weight (AND - axial load on the bit). The surface 230 calibrating plates passes upward from each of the blades 220 near and generally in contact with the side surfaces of the borehole 100 (figure 1) during use of the drill bit 200 in drilling operations. Multiple channels 240, referred to nakami for the removal of drill cuttings, pass between the blades surfaces 220 and 230 gage pads, forming intervals for removal of broken rock formed PKA cutting elements 225.

On surfaces 230 gage pads on the drill bit 200 has multiple gage pins 235. Cutting gage pins 235 on surfaces 230 gage pads on the drill bit 200, for example, PKA cutting elements 225 a special form, provide an opportunity for intensive cutting formation material on the side wall of the borehole 100 (figure 1) and provide high wear resistance according to the diameter of drill bits, fixed cutter bits. Drill bit 200 is shown as a drill bit with inserts of polycrystalline diamond (PKA), but calibrating pins 235 can be equally useful in other bits with fixed blades or paddle bits, which include surface 230 gage pads for contact with a lateral wall of the borehole 100.

For professionals it should be clear that the present invention can be implemented with drill bits of various types. The present invention can be used in so-called trehalose conical or cone-rotary drilling bits or other tools for subterranean drilling, known in the prior art, which can be used in wash Nashik is for supplying drilling fluid to the cutting structure in the drilling process. Accordingly, the term "drill bit"used herein includes and encompasses any and all of the bit rotary drilling, including core bits, roller bits, rock bits, fixed cutter bits, including without limitation the bit with PKA, natural diamond, synthetic diamond, thermally stable synthetic diamonds and impregnated diamond, hybrid bits, using the fixed cutting elements in combination with one or more roller cutters, eccentric bits, chisels with a displaced center, rasburicase, ribbed extenders, and other drilling tool adapted for installation in the electronic module 290 (figa).

On figa and 3B shows a variant implementation of the shank 210 attached to a drilling bit 200 (not shown), the end cap 270 and variant implementation of the electronic module 290 (not shown in figb). The shank 210 includes a Central opening 280 formed along the longitudinal axis of the shank 210. In conventional drill bits 200 a Central hole 280 is adapted for the passage through it of the mud flow. In the present invention at least part of the Central hole 280 has a diameter sufficient to accommodate the electronic module 290 having a generally annular shape, while maintaining construction the th strength of the shank 210. Thus, the electronic module 290 may be placed in the Central hole 280 around the end cap 270 passing inside with a ring shaped electronic module 290, which forms together with the wall of the Central hole 280 water resistant annular chamber 260 (figb), and sealing the inside of the shank 210 is placed there, the electronic module 290.

End cover 270 has a through hole 276, through which drilling fluid can flow through the end cap 270, through the Central hole 280 of the shank 210 to the other side of the shank 210 and forth in the body of the drill bit 200. In addition, end cap 270 has a first flange 271, including the first sealing ring 272 near the lower end of the end cap 270 and the second flange 273 having a second sealing ring 274 near the upper end of the end cap 270.

On figb presents a view of the cross-section located in the shank of the end cap 270 without the electronic module 290 (figure 4), which shows the annular chamber 260 formed between the first flange 271, the second flange 273, building 275 end cover and the walls of the Central aperture 280. The first sealing ring 272 and the second sealing ring 274 form a protective moisture-proof seal between the end cap 270 and the wall of the Central hole 280 for semitischen module 290 (figure 4) from the adverse effects of the environment. Protective seal formed by the first sealing ring 272 and the second sealing ring 274 may also be adapted to maintain in the annular chamber 260 to about atmospheric pressure.

In the embodiment shown in figa and 3B, the first sealing ring 272 and the second sealing ring 274 is formed of material suitable for use in conditions of high temperatures and pressures, such as o-ring seal from gidrirovannoe nitrile-butadiene rubber with polyetheretherketone protective ring. In addition, end cap 270 may be attached to the shaft 210 in a variety of ways, for example on a tight fit with the o-rings 272 and 274, a threaded connection, epoxy, clamp shape memory, welding and soldering high-melting solder. The specialist should be understood that the end cap 270 may be held quite firmly by means of relatively simple coupling mechanisms due to high differential pressure and directed downward flow of drilling fluid during drilling operations.

Electronic module 290, having the form as shown in the embodiment, on figa may be a flexible printed circuit Board that allows you to make electronic module 290 the form of a ring, suitable to fit the district of the end cap 270 and the Central bore 280.

Figure 4 shows a variant implementation of the electronic module in the form of a flexible printed circuit Board in a flat unfolded state. A flexible printed circuit Board 292 includes a sturdy reinforced frame (not shown) to provide acceptable transmission of the impact acceleration sensors, for example accelerometers. In addition, other parts of the flexible printed circuit Board 292, which are electronic components that are not related to the sensors, can be attached to the end cap 270 viscoelastic binder material to at least partly mitigate the impact of the acceleration experienced by the drill bit 200 during drilling operations.

On figa-5D presents the views in perspective of the parts of the drill bit, illustrating examples of placement in the drill bit electronic module 290 (figa), sensors 340 and 370 (6) or combinations thereof. On figa shown the shank 210, is shown in figure 3, is attached to the housing 231 of the bit. In addition, the shank 210 includes a circular cutout A formed in the Central bore 280. This circular neckline A may provide for the expansion of the electronic module 290 in the annular cutout A, when the end cap 270 is installed in its place.

On figa also shows two other alternative locations for the electronic module 290, sensors 340 or combinations thereof. Oval neckline 260, located outside of the material recess (also called socket for tightening tool), in which stands out the serial number of the bits can be cut with a cutter to put down the electronic circuit. Then, to protect the electronics in this area can be plugged and sealed. Alternatively, in an oval cavity in which stands out the serial number of the bit may be made round neckline S for electronics, who later drowned and is sealed to protect the electronics.

On figb shown the shank 210 of another form. The shank 210 may be made circular recess 260D, and the Central hole 280 formed around the circular recesses 260D, ensuring the passage of drilling mud.

Round notch 260D may be plugged and sealed for protection in a circular recess 260D electronics.

On FIGU-5D shows a circular recess (E, 260F, 260G), formed in certain locations on the drill bit 200. In these places there is enough space for electronic components, while providing sufficient structural strength of the blade.

The electronic module may be adapted to perform a variety of functions. In one embodiment, the electronic module 290 (figure 4) it can be a data analysis module adapted to retrieve the data in different modes, the sampling data with different sampling frequency and analysis of the s.

Figure 6 shows a variant implementation of the module 300 data analysis. The module 300 data analysis includes source 310 power supply, a processor 320, a storage device 330 and at least one sensor 340, adapted for the measurement of several physical parameters related to the status of the drill bit, which may include the mode of operation of the drill bit, the conditions of drilling operations and the environmental conditions near the drill bit. In the embodiment shown in Fig.6, the sensors 340 includes multiple accelerometers 340A, several magnetometers M and temperature sensor T.

Magnetometers M in the embodiment, figure 6 by turning them on and receiving from them the data sampling estimate the orientation of the drill bit 200 along at least one of three orthogonal axes associated with the magnetic field of the Earth. The analysis module 300 may include additional magnetometers M to obtain a system with redundancy, which can be selected or disabled various magnetometers M when the fault detection processor 320.

The sensor T temperature can be used to collect data relating to the temperature of the drill bit 200 and the temperature near accelerometers 340A, magnetometers M and other sensors 340. Temperature data can be useful when calibrating acceler the meters 340A and magnetometers M to ensure accuracy when the temperature changes.

If desired, can be used and other sensors 340 as part of the module 300 data analysis. Some examples of sensors that could be used in the present invention include strain gages, installed in different parts of the drill bit, the temperature sensors in different parts of the drill bit, the pressure of the drilling fluid for measuring the pressure of the drilling fluid inside the drill bit and the pressure sensors in the borehole to measure the hydrostatic pressure outside the drill bit. Can also be used sensors to determine the properties of the drilling fluid, for example, to determine the conductivity or impedance for AC and DC current sensors for determining the receipt of fluid from the well at the termination of flow of the drilling fluid, sensors to detect changes in the properties of the drilling fluid and sensors to determine the properties of the solution, such as solution-based synthetic liquid or water-based.

These additional sensors can include sensors 340, integrated with module 340 data analysis and made a part hereof. These sensors 340 may also include additional remote sensors 340 placed in other areas of the drill bit 200 (figure 2) or on the drill bit 200 in the layout of the bottom of the drill string. Communication with D. the additional sensors 340 may be a direct wired connection, or through an additional receiver 360 sensors. Receiver 360 of sensors adapted to communicate wireless remote sensor via a wired connection 362 to limited distances in the conditions of the borehole, as is known in the art.

The memory device 330 may be used to store data from sensors, signal processing, data obtained for long periods, and computer programs, performed by the processor 320. Part memory 330 may be located outside of the processor 320, and a part of the inside of the processor 320. The memory device 330 may include a dynamic random access memory (dynamic memory), static random access memory (static memory), persistent memory (ROM), nonvolatile random access (volatile NVR), such as flash memory, electrically erasable programmable permanent memory (EEPROM), or combinations thereof. In the embodiment shown in Fig.6, the storage device 330 is a combination of static memory in the processor (not shown), a flash memory 330 processor 320, and an external flash memory 330. The use of flash memory, it may be desirable to work with low power consumption and the need to retain information in the absence of a power storage device 330.

Module 00 data analysis may include a port for connection to external devices, for example, the MWD system 146 communication and remote system 390 processing. The communication port 350 may be adapted for use with line 352 direct connection with the remote system 390 processing using a direct wired connection or wireless application Protocol, protocols such as infrared communication, BLUETOOTH® and 802.11 a/b/g. When using a direct connection module 300 data analysis can be adapted for communication with a remote system 300 of processing, such as a computer, a portable computer and "electronic Secretary", in case the drill bit 200 is out of the well. Thus, line 352 direct connection can be used to perform various functions, such as downloading software and its updates, to prepare for the module 300 data analysis by loading configuration data and to download data sampling and data analysis. Port 350 of connection can also be used to enter a query in the module 300 data analysis to obtain information relating to the drilling bit 200, for example the serial number of the bits of the serial number of the data analysis module, software version, full time bits and other data bits are received for long periods, which can be stored in non-volatile NVR.

Port 350 may also order to be adapted for communication with the MWD system 146 due to the layout of the bottom of the drill string through a wired or wireless line 354 communication and Protocol, providing communication with a remote subscriber for limited distances in the conditions of the borehole, as is known in the art. One of the known modes of transmission of data signals to the adjacent auxiliary node in the drill string (figure 1) is depicted, described and claimed in US 4884071 entitled "Downhole tool with the connector on the Hall effect", issued on November 28, 1989 (Howard).

The MWD system 146 may, in turn, to transfer data from the module 300 of the analysis data to the remote system 390 using mud pulse telemetry channel 356 communication or other means of communication that is suitable for communication at relatively large distances encountered in drilling operations.

The processor 320 in the embodiment shown in Fig.6, is adapted for processing, analysis and storage of the collected sensor data. For discrete sampling of analog signals from various sensors 340, the processor 320 in the present embodiment, includes a digital to analog Converter (DAC). Professionals, however, it should be clear that the present invention can be performed with one or more external DAC connected between the sensors 340 and the processor 320. In addition, the processor 320 in this embodiment, includes internal static memories and non-volatile NVR. Experts, however, should Bitonto, that the present invention can be executed only from the external to the processor 320 of the storage device, and also in the variant without an external storage device 330 and only with the internal memory 330 processor 320.

In the embodiment shown in Fig.6, uses a battery as a working source 310 power. Battery ensures operation without the need to connect to another power source in the process of drilling operations. When the battery power, however, the issue of saving energy is important to the present invention. As a result, the battery life can be increased through use of a processor 320 and a memory device 330 low. By analogy to the present invention can be set to other ways of reducing energy consumption.

In the embodiment presented on Fig.6 shows the controllers 316 power supply for controlling the supply of power to a storage device 330, the accelerometers 340A and magnetometers M. Using these controllers 316 nutrition program installed in the processor 320 may control bus 326 power, including control signals for individual enable signal 314 voltage to each component connected to the bus 326 power supply. At that time, is to signal 314 voltage is shown in Fig.6 as one signal, for professionals it should be clear that the various components may require different voltages. Thus, the signal 314 voltage may be a bus, including voltage required to power the various components.

Several accelerometers 340A may include three accelerometers 340A, located on the axes of a rectangular coordinate system. Similarly, several magnetometers M may include three magnetometer M located on the axes of a rectangular coordinate system. While within the scope of the claims of the present invention can be used in any coordinate system, figa presents a rectangular coordinate system that defines the z-axis is located along the longitudinal axis of rotation of the drill bit 200, the x-axis located perpendicular to the z-axis, and y axis is located perpendicular to the axes z and x with the formation of the three orthogonal axes of a Cartesian coordinate system. Because the module 300 data analysis can be used to rotate the drill bit 200, and when the position of the drill bit 200 that is different from the vertical, the coordinate system can be considered as rotating rectangular coordinate system with changing orientation with respect to still located on the surface of the drilling rig 110 (Fig 1).

Accelerometers 340A rela is availa able scientific C with the embodiment, shown in Fig.6, by turning them on and getting them to sample signals indicate the magnitude of the acceleration of the drill bit along at least one of three orthogonal axes. The analysis module 300 may include additional accelerometers 340A to obtain a system with redundancy, which can be mounted or dismounted different accelerometers 340A when the fault detection processor 320. In addition, additional accelerometers can be used for more information about the dynamics of the bit and distinguish between lateral accelerations and angular accelerations.

Figure 7 presents a top view of the drill bit 200 inside the borehole 100. As shown in Fig.7, the drill bit 200 is displaced within the bore 100, which may occur when the deviation of the bit from the simple rotation around the axis of rotation. Figure 7 also shows the location of several accelerometers, the first group which, accelerometers 340A, placed in the first installation site. Can also be enabled and accelerometers 340A' of the second group, located in the second mounting location inside the body. As an example, the first set of accelerometers 340A includes accelerometers x, y, z of the first system 341 coordinates and the second set of accelerometers 340A' includes accelerometers x and y of the second system 341' coordinates. These axes system the m coordinate in the present description may be called the axial (z-axis), tangential (y axis) and radial (x axis). Thus, there may be used one or more radial accelerometers, one or more tangential accelerometers and axial accelerometer. Of course, other options for implementation may include the three-coordinate system in the second group, accelerometers, and other design and orientation of both the accelerometers and accelerometers in groups with multiple coordinates.

When placing the second group of accelerometers in a different location on the drill bit differences between groups of accelerometers can be used to distinguish between lateral accelerations and angular accelerations. For example, if two groups of accelerometers placed at the same radial distance from the center of rotation of the drill bit 200 and the drill bit 200 rotates around the center of rotation, then two groups of accelerometers will experience the same angular acceleration. However, the movement of the drill bit may be more complex in nature, such as vortex (forward or backward), or be accompanied by withdrawal of the bit or transverse vibrations. These movements include various kinds of lateral displacement in combination with the angular movement. For example, as shown in Fig.7, the drill bit 200 can rotate around its axis of rotation and at the same time move in a circle inside the drilling of wells the ins 100 larger diameter. When the movements of this type, two groups of accelerometers located at different locations will experience different accelerations. With appropriate signal processing and mathematical analysis of the lateral acceleration and the angular acceleration can be more easily determined if there are additional accelerometers.

Furthermore, if known or can be estimated initial conditions, can be obtained from the velocity profiles of the bit or the trajectory of the bit by mathematical integration of these accelerometers using conventional methods of numerical analysis,

On Fig presents the time dependence of the data sample magnetometers for samples H the magnetometer X-axis and samples 610Y for magnetometer axis Y. for Example, at point 902 sampling sampling values 610Y the Y-axis are near the minimum, and the sample values H on the X-axis shifted by 90 degrees. Tracking progress according to these samples, the program can detect when a complete turnover. For example, the program can determine when sampling H the magnetometer X positive (i.e. greater than the specified value), as the starting point of turnover. Next, the program can determine when sampling 610Y of magnetometer Y be positive (i.e. greater than the specified value) as evidence of the ongoing rotation. Then the program can determine the ü next moment, when sampling X magnetometer H become positive, indicating completion of the total turnover. As a particular example, each time there is a turnover, during the registration results can be updated various registered variables, to perform data compression, data transmission, transmission of events or combinations of this information.

Figure 9 shows examples of the types of data that can be received by the module 300 data analysis (6). These figures illustrate an example of how data accelerometers (also referred to here as the information accelerometers and magnetometers can look during torsional vibrations. Originally measurement data 610Y and H (also referred to here as the information magnetometers) show a rotation speed of about 20 revolutions per minute (rpm), as shown in frame 61 IX. This low speed can specify to capture bits of any underground rock. Next magnetometers show a significant increase in speed to about 120 rpm, as shown in frame 611Y. This high speed rotation may indicate that the bit is released from the catching of his power. This increase in speed is also illustrated by the measurements of the accelerometers for the radial acceleration G, tangential acceleration 620Y and axial would accelerate the Oia 620Z.

As mentioned previously, the present invention includes methods and devices for obtaining information relating to the characteristics of the cut and condition of the drill bit. As a particular example, information relating to the characteristics of the cut and condition of the drill bit, may be used to determine the proximity of the end of the resource bit and need to be replaced and the necessary changes in the conditions of carrying out drilling to extend the service life of the bit. Information about the condition of the drill bit, is received from an existing drill bit, also could be used to develop further improvements in drill bits.

Software that can be integrated module 300 data analysis (6)includes computer program for execution by processor 320. The software may be stored in the external storage device 330 or the internal storage device of the processor 320.

As shown in more detail below with reference to specific methods of obtaining data, can be selected software modules for the allocation of memory for data storage. The amount of data stored can be modified adaptive sampling and data compression. For example, first data can save what I uncompressed. Later, when there are restrictions of free space in memory can be data compression to free up additional memory. In addition, data may be assigned a priority so that when there are limitations of memory, data with a high priority are stored, and low-priority data can be written new.

One of these methods of data compression, which also provides additional analysis of the condition of the drill bit, is the conversion of the raw accelerometer data in RMS (dscv) data acceleration. This conversion reduces the amount of data and also generates information indicating power consumption in the direction of each accelerometer.

It is well known that RMS acceleration (dscv) is the square root of the mean sum of the squared accelerations during analysis. As the data analysis module collects samples of acceleration, it generates the dependence of acceleration against time for the period of analysis. These values are based acceleration time can be squared and then averaged to determine the mean square acceleration values during analysis. Thus, dscv is the square root of the mean square acceleration. In this disclosure SLE accelerated the e and dscv can be used equally. In General, dscv can be understood here as SLE acceleration, showing SLE acceleration at a certain point, or as the dependence on time of the SCR accelerations relative to the array of values SLE accelerations during the period of analysis. In addition, the dependence on time of the SCR accelerations can, in General, be treated either separately depending on the time of SLE tangential accelerations or depending on the time of SLE radial accelerations or him together.

On figa and 10B shows a possible SLE value for SLE radial acceleration 720R and SLE tangential acceleration T for relatively short periods of time, for example for a few minutes or hours. On figa shows the status of the predominance of the tangential acceleration, where SLE tangential acceleration T significantly higher SLE radial acceleration 720R. The presence of a state with a predominance of tangential acceleration in General is evidence of good cutting and contact gage pads with drilling well, because most of the energy consumed in the tangential direction, i.e. to perform cutting and not in the radial direction.

On figb, opposite, shows the state with a predominance of radial acceleration, which may indicate the vertical movement or sliding instead of a steady cutting action. In operation with a predominance of p is dialogo acceleration value SLE radial acceleration 720R close to or exceeds the value of SLE tangential acceleration T.

The peak value 735 on the chart SLE tangential acceleration T can show the moments when the cutters capture and cut, while the region of low values between the peaks 735 show, when the movement of the bit is a vortex character or is slipping. In embodiments of the present invention can be used raw data from the accelerometers and the data SLE accelerations. In addition, you may be used and other information derived from the raw data of the accelerometers, for example filtered data, compressed data and other information received by the data processing and data compression.

Embodiments of the present invention provide estimates and forecasts of wear of the gage pads 230 (figure 2) on the drill bit 200. Gage plates 230 (figure 2) have wear and tear over time as the drill bit vyborove the formation material in a borehole. As mentioned above, the number of revolutions of the drill bit (also called speed) can be determined from the data sets of radial accelerometers and tangential accelerometers. In addition, to determine the number of revolutions of the drill bit can be used information from the magnetometers, or it can be used for this purpose in combination with the information from the accelerometers.

The IPMS is to gage plates depends on the distance, covered calibrating plate 230 in contact with the drill hole, the surface area of gage pads 230 in contact with the drilling well and the material properties of the rock, which cuts the drill bit. In a particular example, the hardness of the rock affects the coefficient of friction between rock and calibrating plate and as a result, the degree of wear experienced by calibrating plates in the process of friction of the rock.

Distance gage pads from the center of the drill bit (i.e., the radius R is known, and the distance traveled calibrating plate for each turnover is 2πR. Thus, the distance traveled by calibrating plates 230 can be obtained as a function of speed, as is well known to experts.

To trace the long history of the drill bit can be used by software modules. However, based on the drilling parameters obtained during the work on the drill bit, may be formed with a forecast of the expected durability of the drill bit. Breakage of the drill bit may result in a very large financial losses. If forecasts durability, based on real data bits, the software module may be adapted to determine the state of wear of the gage pads and duration of his work is about the end of their operational life. The result of this analysis can be transmitted through port 350 connection (6) on an external device, the operator of the drilling rig or both addresses.

Figure 11 shows a plot of the possible wear of the gage pads from covered calibrating plates distance. The dashed line 810 shows theoretical dependence of the degree of wear at a constant speed, when the gage plates are constantly in contact with the drilling well, and constant hardness of the breed. Line 820 shows the dependence of the wear of the gage pads, which may be due to variations in the speed of rotation, the frequency of contact between the gage pads with drilling well and changes the hardness of the rock. You can see that the graph 820 wear gage pads may deviate from theoretical dashed line 810 for different trip distance (also called profile distances). Graph 820 wear gage pads, which can be considered as the time course of wear of the gage pads or wear of the gage pads may be used to identify specific points within the time course of the wear pads. In embodiments implementing the present invention assesses how the time course of wear of the gage pads will depend on progene what about the distance, the behavior of the bit defined by the readings of the accelerometers, and information about the hardness of the rock, and the combination of all these factors.

One state of wear of the gage pads may be defined as a critical value 824 wear. As a particular example, the wear of the gage pads of approximately 0.25 inches (0,635 cm) may be a critical value 824 wear. When the wear of the gage pads reaches a critical value 824 wear can be determined the maximum allowable wear 826 as time or distance, or their combination, when the gage plates reach the state of wear at which it is advisable to replace the drill bit. Of course, the distance can be defined as the number of revolutions as the distance traveled calibrating plates or other measured against the drill bit length, for example, achieved by the drilling bit depth.

Line 828 shows the current distance traveled calibrating plates. On line 828 profile 822 wear gage pads may be extrapolated extrapolated time dependence 820 wear gage pads to the state of wear and tear that can occur when the estimated depth, estimated time and estimated distance, or a combination of these factors.

<> On figa see graph 830 dependence of the tangential acceleration and the schedule 835 dependence of the radial acceleration during rotation of the drill bit in a borehole. During the rotation of the drill bit in a borehole of the time gage plates can come in contact with the drilling well and hit it as the rotation of the bit in the working direction. For another part-time gage plates may not come into contact with the drill hole or drill bit can be rotated in the reverse direction, or to be in any other non-operational state when the gage plates are not fitted in the bore-hole. Graph 830 dependence of the tangential acceleration and the schedule 835 dependence of the radial acceleration can be used to obtain information about when the gage plates cut the breed and when they do not cut into the rock.

In a particular example, the period (interval) 840 cutting gage plates can be defined by the condition when the graph 830 according to the testimony of tangential accelerometer goes above graph 835 according to the testimony of the radial accelerometer. Similarly, the period 850 sliding gage plates can be defined by the condition when the graph 830 according to the testimony of tangential accelerometer passes below the graph 835 dependence showing the deposits of the radial accelerometer. Specialists, of course, it should be clear that for a period of 840 cutting and period 850 sliding gage pads may be installed and other threshold limits. As a particular example, to determine the periods of cutting and sliding gage pads may be defined by a specific level of acceleration for the tangential and radial accelerations instead of just the point of intersection. In addition, instead of the threshold values can be defined periods 840 cutting and periods 850 sliding gage pads, and they can be assigned to a variable weighting factor based on the differences between the readings of the tangential accelerometer and indications radial accelerometer.

When gage plates cut in the rock, they may experience significant wear, when the slip pads, wear pads small or absent entirely. Thus, the dependence 820 pad wear time can be estimated with greater accuracy when taking into account these periods 820 cutting and periods 850 slip calibrating strips.

On figb presents a graph illustrating the dependence of the time course of wear of the gage pads from changes in drilling conditions on the studied calibrating plates the distance. Periods 840 cutting and periods 850 sliding gage pads, on Azania on figa, also shown on figb. There is also a dashed line 810 shows theoretical progress of wear of the gage plates for constant speed rotation, when the pads are in constant contact with the drilling well and the breed has a constant hardness. Line 870 shows the evaluation of the wear of the gage pads with changes in speed and periods 840 cutting and 850-slip pads. It is evident that the assessment may have a steeper slope, indicating greater wear for distance traveled during periods of 840 cutting pads. On the contrary, a smaller slope during periods of 850 slip lining indicates slight wear during periods of 850 slip. Given the periods 840 cutting, and the periods 850 slip pads, you can get a more accurate estimate of the amount of wear during operation of the drill bit.

Although it is not shown in figb, specialists should be clear that the critical value 824 wear from 11 and maximum permissible wear 826 and the predicted profile 822 wear equally applicable to graphics on figb.

On figa shows a graph of the changes in the hardness of the breed as dip the drill bit in the borehole. The degree of wear of the gage pads associated with the friction coefficient and hardness of material being cut. Options implemented the program of the present invention may include the assessment of information on the hardness of rocks, which is included in the module 300 data analysis (6) prior to drilling. In other embodiments, the current implementation of the hardness of rocks derived from General information about lithology, can be passed to the data analysis module of the other devices located on the drill string, or from the surface. On figa data changes 910 on the hardness of the rocks are shown depending on the mileage gage pads distances (for example, by correlation with the depth in the borehole and speed). For ease of description, and without limiting the invention, as an example, information about the hardness of the rocks shows the segment 920 high hardness, segment 930 low hardness and segment 940 intermediate hardness.

On figb the schedule 970 possible time dependence of the wear of the gage pads depending on changes in the hardness of the rock traversed calibrating plates a distance. On figb appear the same segment 920 high hardness, segment 930 low hardness and segment 940 intermediate hardness. As before, the dashed line 810 shows theoretical time dependence of the wear of the gage pads at a constant speed of rotation for the case of constant contact pads with the drill hole and constant hardness of the breed. Line 970 shows the evaluation of the wear of the gage is ukladki with changes in the speed and current of the hardness of the rocks.

As shown by line 970, when the gage plates cut solid materials in the segment 920 with high hardness, the slope of a plot of 970 dependence of the wear pads from time to time can be quite steep, as gage plates wear out relatively quickly on a particular covered their distance. On the contrary, the slope of a plot of 970 dependence of the wear pads from time to time may be relatively small segment 930 with low hardness, as the pads wear out relatively slowly at a certain they travelled distance during the eruption of soft rocks. In the segment 940 intermediate hardness graph 970 dependence of the wear pads from the time also has a slope intermediate between the slopes of the graph segments 920 with high hardness and segment 930 with a low hardness.

Although it is not shown in figb, specialists should be clear that the critical value 824 wear of 11, and maximum allowable wear 826 and the predicted profile 822 wear equally applicable to graphics on figb.

Data on the wear of the gage pads, depending on the time of acceleration, rate of rotation, or all of this information together can be periodically communicated to the operator or equipment on the surface through port 350 connection (6). The operator taking into account wear kalibrowannoj may find it necessary to change the conditions of drilling. In a particular example, when the wear of the gage pads becomes visible, the operator may wish to extend the work on the drill bit by changing one or more drilling parameters, such as torque, speed of rotation or axial load on the bit. Naturally, such a change in drilling parameters mean less consumed during the drilling of energy, and the rate of penetration may fall so that the depth of penetration at a given wear and tear will not be significantly different. This, however, will give the operator the possibility of postponing the expiry of the resource on the drill bit in the case, for example, when another drill bit is not yet prepared to replace the bit with the approaching full wear or when worn out drill bit is already close to the desired depth of drilling and change one or more drilling parameters will be possible to achieve the desired depth at a lower rate of penetration, thanks to which it will be possible to avoid time and cost by removing the drill bit from the well to replace it with another drill bit to finish drilling the remaining short cut.

While the present invention has been described in relation to certain preferred embodiments, the experts should be clear that only these versions of the invention are not limited.

In contrast, in preferred embodiments, the implementation can be done numerous additions, deletions and modifications without departure from being claimed here, inventions, including equivalent signs. In addition, the characteristics of a variant of implementation can be combined with features of another variant implementation, while remaining within the stated scope of the claims of the invention.

1. Drill bit for drilling subterranean rocks, including: the body of the bit, having at least one gage pad and adapted for connection to a drill string; a group of accelerometers placed in the drill bit and including a radial accelerometer to determine the radial acceleration of the drill bit and the tangential accelerometer to determine the tangential acceleration of the drill bit; and a data analysis module, functionally connected with a group of accelerometers placed in the drill bit that includes a processor, a storage device and a communication port and configured to: sampling information about the acceleration from the radial and tangential accelerometer accelerometer during analysis; making information about the acceleration in the storage device to obtain the time course of the acceleration, the analysis of the time course of the acceleration to determine the races of the situation, passed at least one gage pad; analysis of the time course of the acceleration to determine at least one period of cutting pads and at least one period-slip pads; and evaluation of the wear of the gage plates on the basis of analysis of the covered distance, at least one period of cutting pads and at least one period of slip lining.

2. Drill bit of claim 1, wherein the data analysis module is configured to receive via the communication port information on the hardness of the breed, and which in the evaluation of the wear of the gage plates using the data on the hardness of the rock in the analysis of the covered distance of at least one period of cutting pads and at least one period of slip lining.

3. Drill bit according to claim 1 or 2, wherein the data analysis module is configured to: determine at least one period of cutting pads as the period of time during which the tangential acceleration is greater radial acceleration; and determining at least one period of the sliding pads as the period of time during which the radial acceleration of more tangential acceleration.

4. Drill bit according to claim 1 or 2, wherein the data analysis module is configured to issue data about the wear calibrating ele the key through the communication port.

5. Drill bit according to claim 1 or 2, wherein the data analysis module is configured to: time course of formation of wear gage plates through periodic evaluation of the wear of the gage plates for analysis; and data output time course of wear of the gage plates through the communication port.

6. Drill bit according to claim 5, in which the data analysis module is configured to: extrapolation of a time course of wear of the gage plates to determine the maximum allowable wear when the wear of the gage plates close to the critical amount of wear after some time or drilling to a certain depth or a combination of both factors; and outputting data maximum permissible wear through the communication port.

7. Drill bit according to claim 1 or 2, including a magnetometer coordinates X and magnetometer Y coordinates, functionally connected to the data analysis module, which is configured to: sampling data magnetometers from the X-and Y magnetometer the magnetometer during the analysis; and use information from the magnetometers to determine the distance travelled.

8. Method of assessment the drill bit, in which: collect information from accelerometers through periodic sampling data of at least two accelerometers placed in the drilling Dol is those to obtain the time course of the acceleration at the time of analysis; process data time course of the acceleration in the drill bit to determine the profile of the distance that at least one gage pad on the drill bit; define the current hardness breed; analyze the profile of the distance that at least one gage pad, and the current hardness of the breed for assessing the state of wear of the gage plates.

9. The method according to claim 8, in which information from accelerometers includes the time course of the tangential acceleration and the time course of the radial acceleration and the performance of which analyze the time course of the tangential acceleration and the time course of the radial acceleration to determine at least one period-slip pads and at least one period of cutting pads and the profile analysis distances take into account at least one period of cutting pads and at least one period, slip lining, and also the current hardness of the rocks.

10. The method according to claim 9, in which: at least one period of cutting pads is defined as the period of time when the value of the time course of the tangential acceleration is greater than the value of a time course of the radial acceleration; and at least one period of the sliding plates is defined as the sub is OK time when the value of the time course of the radial acceleration is greater than the value of a time course of the tangential acceleration.

11. The method according to claim 8 or 9, which give information about the state of wear of the gage pads through the communication port of the data analysis module, functionally associated with at least one tangential accelerometer and at least one radial accelerometer.

12. The method according to claim 11, in which, after the issuance of data on the state of wear of the gage pads change the drilling parameter, which is chosen from the group consisting of torque, rotation speed and axial load on the bit.

13. The method according to claim 11, in which the issue of data about the state of wear of the gage pads perform periodically to obtain the time course of wear of the gage pads on the drill bit.

14. The method according to item 13, in which extrapolate the time course of wear of the gage pads to determine the maximum allowable wear when the wear of the gage plates close to the critical amount of wear after some time or drilling to a certain depth or a combination of both factors; and provide information about the maximum allowable wear.



 

Same patents:

FIELD: mining.

SUBSTANCE: in compliance with first version, borehole tractor comprises two draw blocks including cylindrical bodies connected by coupling and propulsors. Propulsors include screw with kinematic thread coupled via turn-slide levers with studded press-on bush to interact with the screw, and buffer bush via two parallel levers. Buffer bush comprises spring-loaded brake shoes and is fitted on the screw by its central opening. Lengthwise grooves are made in said bodies to accommodated press-on bush studs, buffer bush shoes and riffled slips with turn-slide levers to be displaced over the screw. Said bodies accommodate reversible motors to transmit torque via magnetic coupling arranged in sealed shell to screws. Motors are interconnected and connected with the surface logging cable control station.

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5 cl, 2 dwg

FIELD: oil and gas industry.

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1 dwg

FIELD: oil and gas industry.

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FIELD: oil and gas industry.

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FIELD: oil and gas industry.

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FIELD: mining.

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16 cl, 19 dwg

FIELD: oil-and-gas industry.

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FIELD: oil and gas industry.

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13 cl, 10 dwg

FIELD: physics; geophysics.

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FIELD: mining.

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FIELD: mining.

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FIELD: oil and gas industry.

SUBSTANCE: suggested umbilical cable has channels along the whole its length filled with working media of low density as well as functional components representing components of the umbilical cable required for insulation, strength and transmission of different media - liquids, gases, electric energy and data. At that a solid body, liquid, gas or their combination may be used as working media. Characteristic property of the umbilical cable consists in that the channels filled with working media are interconnected by their ends. At that the above working media have different density and divided by elastic pistons. Besides, the umbilical cable can contain additional dummy channels permanently filled with working medium of low density. The invention also suggests the method for delivery of a subsurface device to the well survey interval by the above umbilical cable.

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4 cl, 3 dwg

FIELD: oil and gas industry.

SUBSTANCE: method for integral status assessment of bottomhole formation zone includes operation of the well in steady conditions before hydrodynamic research, hydrodynamic research by repressuring method, determination of bottomhole pressure and continued fluid influx to the well from formation after its shutdown and processing of measurement results. At that during processing of measurement results current formation pressure is determined by multiplication method, approximation of the measurement results is made including division of actual pressure buildup curve (APBC) into separate sections at coefficient of determination less than 0.99. Then selection of approximate equations is made for the selected sections and division of the whole research period into intervals with uniform time increments. Values of bottomhole pressure are calculated for the specified intervals. The approximated APBC is processed by determined pressure moments with determination of formation pressure and nondimensional diagnostic property. The obtained formation pressure is compared with the pressure obtained by multiplication method. When the values differ per more than 0.3 MPa, approximation procedure shall be made with use of other approximate equations. Then against results of formation pressure determination by multiplication method the degree of bottomhole pressure buildup is assessed and well production index is determined for the conditions. In order to specify position of the processed section the log-log plot is plotted. The actual and approximated APBC is processed by tangent method with determination of parameters for the remote formation section. The results of actual and approximated APBC processing by tangent method are compared. When permeability coefficients for the remote formation section are different as related to actual and approximated curves, then approximation procedure is performed with use of other approximate equations. Then skin factor is determined for APBC with almost full pressure buildup, at least equal to 99%, and for APBC without pressure buildup. Status of the bottomhole formation zone is assessed against values of diagnostic property and skin factor. When APBC cannot be processed by tangent method, processing is made by differential or integral methods considering influx after the operations, with preliminary made procedure of approximate buildup curves for equidistant time values. Parameters are determined for the remote formation zone using several methods considering influx after the operations, in case of their status deterioration dimensions and properties of the remote formation zone are determined using permeability values determiner at earlier stage for the remote formation zone. Status of the bottomhole and remote formation zones is assessed against values of diagnostic property, permeability, hydraulic conductivity, piezoconductivity and dimensions of the bottomhole formation zone.

EFFECT: improving determination accuracy for indices characterising status of the bottomhole formation zone.

11 dwg

FIELD: mining.

SUBSTANCE: proposed method comprises tripping the video camera in hole with turbid medium on logging cable over tubing. Logging zone is isolated by packer and web in tubing suspension wherein suspended rock is settled by gravity. Visualised logging is executed in column of laminated optically clear fluid by displacement of video camera inside tubing suspension. Logging results are used to estimate operating conditions of the hole. If required, extra web is used to confine the logging zone. In compliance with first version, logging device comprises tubing suspension with packer separating the logging zone from hole behind-the-packer chamber, logging cable, video camera suspended from logging cable inside the suspension. Web is hooked to video camera to fit in suspension seat and to be detached at camera tripping in hole along suspension to logging zone. Web and seat in suspension are furnished with locking elements. Web has a central hole with gland for logging cable to slide there over and can have filter cells. Said web features OD smaller than tubing ID. Video camera is equipped with centring skid. Logging cable is coated with polyamide shell over logging length. In compliance with second version, logging device comprises tubing suspension with packer separating the logging zone from hole behind-the-packer chamber, logging cable, video camera suspended from logging cable inside the suspension. Web is secured to video camera to slide by its edges over suspension wall. Video camera is equipped with centring skid. Gland seals are arranged over web edges. Said web can be made of filter material. Said web features OD smaller than tubing ID.

EFFECT: lower costs, accelerated analysis.

15 cl, 2 dwg

FIELD: oil and gas industry.

SUBSTANCE: method involves separation of oil-gas-water fluid contained in a measuring cylinder using chemical reagents for oil and water with gas emission, measurement of height of liquid column, hydrostatic pressure, emptying of the measuring cylinder, measuring current values of differential pressure and levels of oil-gas-water fluid, oil-water fluid, oil, calculation of oil and water density. At that, volume content of water is calculated by a mathematic formula, and weight content of water is calculated as difference between the value of differential pressure of water in the measuring cylinder and the value of differential pressure of oil-water fluid in the measuring cylinder.

EFFECT: increased measurement accuracy for determination of parameters of oil-gas-water mix.

1 dwg

FIELD: oil and gas industry.

SUBSTANCE: invention is related to method and a device for pressure and/or temperature control in one or few annular spaces of well casing in natural deposit without disturbance of well sealing or structure. The device includes a Wireless Sensor Unit (WSU) located outside of the section of non-magnetic casing and including an ambient pressure and/or temperature measuring sensor; at that, WSU can be mounted or positioned at any height of well bore, and power for WSU can be supplied by energy collection. At that, induction signal frequency is within 10-1000 Hz for deep penetration through non-magnetic casing. Sensor Electronics Unit (SEU) is located inside of well bore casing and used for WSU power supply and communication; at that, SEU is mounted on a drill pipe or structure of an equipped well with the use of a pipe with thread, which allows adjusting its height position; at that, SEU converts DC power supplied by cable from surface into AC electromagnetic field providing power supply for WSU located outside of casing. At that, SEU and WSU use electromagnetic modulation for data communication between those components.

EFFECT: accurate pressure and/or temperature control in one or few annular spaces of well casing.

35 cl, 6 dwg

FIELD: oil and gas industry.

SUBSTANCE: bore core is selected in the well and surveyed, the oil saturation factor is determined for the bore core, an integrated well log survey is performed and the oil saturation factor is determined according to the survey results, a relative factor is determined as a ratio of the core oil saturation factor to the oil saturation factor of the well log survey, log curves for wells are analysed in the terrigenous section of the productive formation, reservoir beds are identified with induction logging apparent resistivity less than 3 Ohm/m, among the identified reservoir beds the beds are selected with the mineral composition of the core and mud having minerals reducing specific resistivity and high content of current-carrying elements against the log survey data, the true oil saturation factor is determined for the identified beds by multiplying the oil saturation factor of the well log survey by the relative factor and the obtained result is compared with oil saturation factor values for low oil-saturated and oil-saturated reservoir beds and the respective bed is referred to the low oil-saturated and the oil-saturated reservoir beds.

EFFECT: improving accuracy of the oil-saturated bed in the well log.

3 tbl

FIELD: electricity.

SUBSTANCE: method for automated calibration of temperature measurement in hydrogen-rich media with high temperature in the system using a fibre-optic distributed temperature sensor includes the following stages: a. in a measurement mode when flash burn energy of the primary light emission source is delivered to the sensing fibre, and b. in a correction mode when selection of the secondary light emission source is made and pulses of the above secondary source are delivered to the sensing fibre. At that at the first stage backscattered Stokes and anti-Stokes components of Raman emission are collected and temperature values are calculated using intensities of the backscattered Stokes and anti-Stokes components of Raman emission. At the second stage the backscattered Stokes and anti-Stokes components of Raman emission are collected from the secondary light emission source; this Stokes component of Raman emission is used for correction of a profile for anti-Stokes component of Raman emission collected from the primary light emission source during the measurement mode; corrected temperature value is calculated based on the corrected profile of anti-Stokes component of Raman emission. At that the used distributed temperature sensor is an optical fibre with a pure silicate core (PSC). At that the primary light emission source is a source with a wave length of 1,064 nm and the secondary light emission source is a source with a wave length of 980 nm.

EFFECT: ensuring potential operation of the fibre-optic sensor in conditions with higher temperature and increase of its operational reliability during the whole service life of this sensor.

3 cl, 7 dwg

FIELD: mining.

SUBSTANCE: chisel for drilling of wells includes mills of conical shape, where teeth crowns are arranged, having a tail of a cylindrical shape and a working head. Control teeth are installed along the mill on its different crowns, inside working heads of which a radioactive isotope indicator is placed tightly at the distance from the top to the permissible wear of teeth.

EFFECT: increased validity of chisel arming state monitoring in process of well drilling.

1 dwg

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