Method and device for data collection on well characteristics in process of drilling

FIELD: mining.

SUBSTANCE: invention relates to determination of various well characteristics in the underground formation, through which the borehole passes. For this purpose a pressure drop is created due to the difference between the internal pressure of fluid that passes through the drilling tools and pressure in the circular space in the borehole. The device contains an extension arm that can be connected with the drilling tools and has an opening that enters into the chamber in the extension arm. A piston is located in the chamber with a rod passing through the opening. The piston can move from the closed position when the rod blocks the opening to the open position when the rod is retracted into the chamber to form a cavity for intake of well fluid. A sensor is located inside the rod, which is intended for data collection from the well fluid contained in the cavity.

EFFECT: increase of accuracy of determination of well characteristics.

34 dwg, 9 dwg

 

The present invention relates generally to the definition of the various downhole characteristics of the underground formation through which the wellbore. More precisely, this invention relates to the determination of borehole characteristics, such as the pressure in the annular space, the reservoir pressure and/or pore pressure during drilling operations.

Development and operation of oil wells currently provide for continuous monitoring of various characteristics of the underground formation. One aspect of the standard estimates of the parameters of the productive formation refers to the parameters of the reservoir pressure and permeability of the porous rock reservoir. Continuous monitoring characteristics such as reservoir pressure and permeability, allows to obtain information about the change in reservoir pressure after a certain period of time and is essential for predicting reservoir performance and productive period of life of the underground reservoir.

When operating at the present time, these characteristics usually get through borehole geophysical research (logging), performed using the drill steel ropes through the test layer. The measurement of this type requires further descent into the well and climb out of the well. In other words, the storm the other column should be removed from the wellbore with the to test the reservoir can be lowered into the wellbore to obtain data on the reservoir, and after the lifting of the test reservoir drill string lowered back into the wellbore for further drilling. Thus, as a rule, the monitoring of the formation properties, including pressure, is carried out using test layer deployed on drill steel rope, such as downhole devices described in U.S. patent No. 3934468, 4860581, 4893505, 4936139 and 5622223. Each of these patents is limited, consisting in the fact that the test layers described in them, are able to obtain data on the reservoir only up until the downhole devices, lowered on drill steel rope, will be located in the wellbore and in physical contact with the area of the stratum of interest. Because "the descent into the well and rise of wells required to use such test layers, takes a considerable amount of expensive rig time, these operations are usually performed in cases where formation data is absolutely necessary, when the ascent and descent of the drill string to perform the replacement of the drill bit or other reasons.

The ability to have data about the reservoir in real time during execution of work on drilling wells is a big advantage. Information the I formation pressure, obtained in real time during the drilling process, will enable the engineer-drilling or driller to make decisions related to the density and composition of the drilling fluid, as well as to the parameters of the sinking, much earlier, which helps to ensure safety during drilling. The possibility of obtaining data on the reservoir in real time is also desirable to enable precise control of the load on the drill bit in response to changes in reservoir pressure and permeability changes, so that the drilling operation can be performed with maximum efficiency.

Developed methods of obtaining data about the reservoir from the subterranean zone of interest at a time when the downhole drilling tool is in the wellbore, and these methods do not require a running in the hole and climb out of the well for the descent of test formations in the borehole to determine these characteristics. Examples of methods involving the measurement of different downhole characteristics in the drilling process described in UK patent No. 2333308 and U.S. patent No. 6026915, 6230557, 6164126.

Despite advances in obtaining downhole characteristics of the layer, there remains a need to further develop reliable methods that provide the ability to collect data at the time of the drilling process. Advantages can also be achieved through the use of rocks surrounding the borehole, and the operations performed by the drilling tool to facilitate measurements. It is desirable to have developed such methods, which will be automatic and/or will not require signals from the surface to initiate the operation. In addition, it is desirable that such methods are provided one or more of the following advantages, such as simplified operation, minimal impact on the drilling process, fast operation, the minimum amount of testing, the external control of various well characteristics, the elimination of the discharge pipeline for testing multiple test devices around tool for ensuring the possibility of getting multiple test results, reducing or eliminating the use of motors, pumps and/or valves, low energy consumption, reducing the number of moving parts, compact design, durability even when dealing with heavy impact loads, fast response. An additional advantage is achieved in the case when such a device can be used in combination with the piston for preliminary tests to obtain pressure data, dependencies, the resulting prior is of spitoni, and other downhole parameters.

In accordance with the invention, a device for collecting data on downhole characteristics during the operation of drilling through the downhole drilling tool located in the borehole, with the pressure in the annular space of the well bore and passing through an underground formation having a pore pressure, while the downhole tool is made with the possibility of transmission of drilling fluid passing through it, so it creates internal pressure between the internal pressure and the pressure in the annular space created by the pressure difference, whereby the device comprises a strip made with the possibility of connection in the working position with the drillstring drilling tool and having performed in it flushing channel for passing drilling fluid through it, the hole passing in the pressure chamber communicated in fluid with the flushing channel and/or the well bore, a piston mounted with a possibility of displacement in the pressure chamber, with the piston rod passing from it into the hole of the extension tube, and is arranged to shift to the closed position under the action of increased pressure drop in the open position under the action of the reduced pressure drop, so that in the closed state the stem fills the hole, and in the open position, at least part of the rod is retracted into the camera, so that the hole forms a cavity for receiving the downhole fluid, and a sensor located in the stem and is designed to collect data from the downhole fluid located in the cavity.

The device may further comprise a piston spring connected in operating position with the piston and made with the possibility of application of force to the piston to provide pressing of the piston in the open position.

The device can be configured so that when the passage of drilling fluid through the flushing channel spring piston capable of creating a force sufficient to overcome the pressure difference applied to it.

The device can be configured so that when the drilling fluid does not pass through the flushing channel, the piston spring is able to create a force sufficient to overcome the differential pressure applied to it.

The device may further comprise measuring head, located in the pressure chamber and configured to shift between a position of the outlet where it is plugged in to an extension, and extended position in which it is extended from the extension, with the measuring head has a hole passing into the chamber of the measuring head, and a piston installed in the camera will measure the school head, in the closed position, the stem fills the hole of the measuring head, and in the open position, at least part of the rod is retracted into the chamber of the measuring head, so that the hole of the measuring head is formed a cavity for receiving the downhole fluid.

The device may further comprise a spring measuring head connected in operating position with the measuring head and made with the possibility of application of force to the measuring head so that there is pressing the measuring head in the extended position.

The device can be configured so that when the passage of drilling fluid through the flushing channel spring piston capable of creating a force sufficient to overcome the pressure difference applied to it.

The device can be configured so that, when the drilling fluid does not pass through the flushing channel, the piston spring is able to create a force sufficient to overcome the differential pressure applied to it.

The device may further comprise a cylinder for measuring the pressure in the annular space, cylinder for measuring the internal pressure and the battery, while the cylinder for measuring the pressure in the annular space indicated by fluid from the wellbore and the pressure chamber, a cylinder for measuring the internal pressure, the deposits reported by fluid from the flushing channel and one of the following elements: a first cavity in the chamber between the measuring head and extension, the second cavity in the chamber between the measuring head and extension, and their combinations, the battery reported by fluid from the pressure chamber in the annular space and the cylinder for measuring the internal pressure. The battery may be selectively communicated in fluid with the cylinder for measuring the internal pressure.

The device may further comprise a check valve, designed to ensure the exit of fluid from the battery and pass it into the cylinder for measuring the internal pressure.

The device may further comprise a throttle is arranged to provide ease the pressure in the line between the cylinder for measuring the internal pressure in one of the following elements: a battery, a second cavity and their combinations.

The device may further comprise a switch for selectively actuating cylinders for measuring pressure.

The device may further comprise an electronic communications device between the sensor and electronic circuits in the downhole tool. The electronic communication device may include perceiving winding having wireless communication with the transmitting coil. Perceiving the winding may be located in the piston, and the transmitting coil is located around the pressure of the second chamber.

The electronic communication device may be connected through a wired connection with electronic circuits in the downhole tool.

The electronic communication device may include perceiving the coil, pickup coil and ceramic window between them, while perceiving the winding has wireless communication with the transmitting coil with ceramic window.

The electronic communication device may be connected via a wireless connection with electronic circuits in the downhole tool.

The device may further comprise one of the sensors: sensor internal pressure made with the possibility of determining the internal pressure in the flushing channel, the pressure sensor in the annular space, is arranged to determine the pressure in the annular space in the wellbore, the sensor of the differential pressure, and combinations thereof.

The device may further comprise a control unit, United in working position with the sensors and configured to process signals from the sensor for use at the top of the wellbore.

The device may further comprise a processor for processing signals, the preamplifier and demodulator for processing signals from the sensors.

In accordance with the present invention, there is also a way of collecting dannijo downhole characteristics during the operation of drilling a borehole through the drilling tool, located in the well bore with the pressure in the annular space of the well bore and passing through an underground formation having a pore pressure between the internal pressure in the downhole drilling tool and the pressure in the annular space created by the pressure difference, and the method includes the following operations:

equipment downhole drilling tool extension having a through flushing channel and a hole passing into the chamber, and a piston mounted with a possibility of displacement in the chamber and having a stem passing from it into the hole, and configured to shift between a closed and an open position;

installation of downhole drilling tool in the wellbore;

electoral change of differential pressure to move the piston between the open and closed position;

perception data from the downhole fluid located in the cavity by a sensor in the piston.

The change in pressure drop may occur automatically as a result of changes in pressure in the annular space and/or internal pressure.

The operation of the electoral changes can be accomplished by selective transmission of drilling fluid through the downhole tool.

In the open position in the hole may create a small amount for prematching fluid medium.

The hole can pass through the outer surface of the extension.

The method may additionally include the flow of energy to the piston. Energy can be supplied from a remote power source. The energy source may be due to changes in differential pressure.

The method may additionally include the perception of data from the internal pressure sensor in the downhole tool and/or pressure sensor in the annular space provided in the downhole tool.

The method may further include processing the data for use at the top of the wellbore.

Other features of the invention will become apparent from the following description with reference to the accompanying drawings, which depict the following:

figure 1 is performed with a partial section and partially in block schematic vertical view of a conventional drilling rig and drill string in which the present invention is used;

figure 2 is performed in partial section and partially in block schematic vertical view of a stabilizing extension, in which there are units for measuring pressure;

figa represents a section of a first variant implementation of the node for measuring pressure, shown in figure 2 in the closed position;

figv represents a cross-section of another embodiment of osushestvleniya for measuring pressure, shown in figure 2 in the open position;

figa represents a section of a first variant implementation of the node for measuring the pressure in the extended position and the corresponding hydraulic control circuit;

figv represents a cross section of another variant implementation of the node for measuring pressure in the position of the bend and the corresponding hydraulic control circuit;

figa represents a schematic view in detail showing a first variant implementation of the electronic device to a host for measuring pressure, shown in figure 2;

figv represents a schematic view in detail showing another variant implementation of the electronic device to a host for measuring pressure, shown in figure 2;

6 is a block diagram showing an electronic device nodes for measuring pressure, shown in figure 2.

Figure 1 shows a typical drilling rig, consisting of ground-based platforms and drilling rigs and located above the barrel 11 wells, held in an underground reservoir F. the Barrel 11 wells formed by rotary drilling a well known manner. However, for professionals in the art after study of this specification it will be clear that the present invention may also find application in cases of directional drilling, and wrestling the drilling, and not limited to surface drilling rigs.

Drill string 12 is suspended in the bore 11 of the bore, and at its lower end has a drill bit 15. Drill string 12 is driven into rotation by the rotary table 16, which is powered by means not shown and which is in contact with the lead pipe 17 located at the upper end of the drill string. Drill string 12 is suspended from the hook 18 attached to a traveling block (also not shown)through lead pipes 17 and the rotary swivel 19, which provides for rotation of the drill string relative to the hook.

The drilling fluid 26 is stored in the sump 27 is formed at the location of the wells. A pump 29 delivers the flow of the drilling fluid 26 into the interior of the drill string through the channel in the swivel 19, causing the passage of drilling mud down through the drill string 12, as shown by directional arrow 9. The drilling fluid exits the drill string 12 through openings in the drill bit 15, and then passes upward through the zone between the outer side of the drill string and the wall of the wellbore, called the annular space, as shown by directional arrow 32. Thus, the drilling fluid lubricates the drill bit 15 and carries cuttings to the surface, when he returned to the sump 27 for recirculation.

The drilling fluid performs various functions aimed at facilitating the drilling process, such as grease on the drill bit 15 and the moving drill cuttings formed by the drill bit during the drilling process. Drill cuttings and/or other solid particles are mixed with the drilling mud to the formation of mud cake 105 mud on the walls of the borehole, which performs various functions, such as coating the walls of the wellbore.

Dense drilling fluid 26 is pumped by the pump 29 is used to maintain the pressure of the drilling fluid in the wellbore (pressure PAndin the annular space at the level exceeding the pressure of the fluid in the surrounding formation F (pore pressure PP), to prevent the passage of formation fluids from the surrounding formations in the wellbore. In other words, the pressure (PAndin the annular space is maintained at a higher level compared to the pore pressure (PP), so that there is excess pressure in the wellbore (RAnd>RP), which does not cause ejection. Pressure (PAndin the annular space usually also support below a given level to prevent cracking of the formation surrounding the wellbore, and to prevent the flow of drilling mud in OCD the outer layer. Thus, downhole pressure, typically support within the specified range.

Drill string 12 includes in addition to the equipment 100 of the bottom of the drill string located near the drill bit 15 (in other words, with a length of up to several lengths of cords in the direction from the drill bit). The equipment of the bottom of the drill string includes devices that provide the possibility of measuring, processing and storing information, as well as communication with the surface. Thus, the equipment 100 of the bottom of the drill string includes, inter alia, the device 200 for measuring and providing a local communication designed to identify and transmit data on resistivity of the formation F, surrounding the stem 11 of the well. The device 200 communication, comprising transmitting antenna 205 and the receiving antenna 207, described in detail in U.S. patent No. 5339037.

Equipment 100 further includes extension tube 130 that is designed to perform various other functions of the measurement, and the sub-node 150 connection with the surface/local communications. The sub-node 150 includes an antenna 250, used for local communication with the device 200, and the acoustic communication system of a known type, which communicates with a similar system (not shown) on the surface of the earth by means of signals transmitted through the drilling R is the target or washing liquid. Thus, the communication system with the surface in the sub-node 150 includes a generator of acoustic waves which generates an acoustic signal in the drilling fluid, which characterizes the measured downhole characteristics.

The sound generator of oscillations of one suitable type is used a device known as a device to produce the sound signal in the drilling fluid, which contains the stator slots and rotor slots, which rotates and repeatedly interrupts the flow of the drilling fluid to create the specified signal transmitted in the form of acoustic waves in the drilling mud. The electronic circuit of the excitation sub-node 150 can include a corresponding modulator, such as a phase manipulator, which usually generates the excitation signals supplied to the transmitter in the mud. These excitation signals can be used to apply the appropriate modulation device for forming audio signal into the mud.

Generated acoustic wave is received at the surface of the transducers 31. Transducers, such as piezoelectric transducers, convert the received acoustic signals into electronic signals. Output transducers 31 is connected with the receiving subsystem 90 at the top of STV is as well, which demodulates the transmitted signals. The output of the receiving subsystem 90 when it is connected to the processor 85 and recording device 45.

Also provided by the transmission system 95 at the top of the wellbore, which is actuated to control the interrupt operation of the pump 29 so that it can be identified transducers 99 in the sub-node 150. Thus, there is full-duplex (simultaneous two-sided communication between node 150 and equipment located at the top of the wellbore, as described in more detail in U.S. patent No. 5235285.

In the embodiment shown in figure 1, the drill string 12 is further provided with a stabilizing extension 300. Such stabilizing cords are used to eliminate the "desire" of the drill string to oscillate and diverge from the center when it is rotated in the wellbore, leading to deviations in the direction of the wellbore from the target path (e.g., straight line). This deviation can cause excessive lateral forces acting on the section of the drill string and drill bit, which causes accelerated innocet phenomenon can be overcome by providing means for centering the drill bit and, to some extent, the drill string in strackbein, such as stabilizing blades 314.

Figure 2 illustrates the stabilizing extension 300A, shown partially in cross-section and is suitable for use in combination with a drilling tool such as a drilling tool 100, shown in figure 1. Extension cable 300A is attached to the drill string 12 and is located in the barrel 11 wells coated filtration crust 105 mud. Stabilizing extension 300A has many stabilizing blades 314a nodes 210A for measuring the pressure provided to them. Extension cable 300A has a flushing channel 215 passing through it and intended for the passage of drilling fluid through the downhole tool, as shown by the arrow. The flow of drilling fluid through the tool creates internal pressure PI. The outer surface of the strip is exposed to pressure PAndin the annular space surrounding the well bore. Drop δP pressure between the internal pressure PIand pressure PAndin the annular space may be used to actuate nodes 210 for measuring pressure, as will be described below. If the equipment design of the bottom of the drill string does not create the specified pressure drop, an additional throttle (not shown) may be fitted the h in the drill string to restrict flow and create backpressure.

Stabilizing extension 300A has a tubular core 302, made with the possibility of joining in the axial direction of the downhole tool, such as drill string 12 of figure 1. Thus, the core 302 can be performed with threaded and socket ends 304, 306, designed for conventional connection to the drillstring. As shown in figure 2, the ends 302, 304 can be a sleeve, a custom-built, which connected to the Central elongated part of the core 302 in the usual way, for example, by threaded connection and/or welding.

Stabilizing extension 300 further includes a stabilizing element or sleeve 308 that is located around the tubular core 302 between the ends 304 and 306. Provided by thrust bearings 312, designed to reduce friction and axial loads generated on the contact surface in the axial direction between the sleeve 308 and ends 304, 306 of the core. Also provides a rotating seal 348 and radial bearings 346 on the contact surface in the radial direction between the core 302 and the sleeve 308.

Stabilizing extension 300A shown in figure 2, has three helical stabilizing blades 314a, located around a circumferential periphery of the extension. Stabilizing lop the STI 314a attached, for example, by welding or bolting, to the outer surface of the roll sleeve 308. The blades preferably are located at certain distances from each other and oriented in a spiral, as shown in figure 2, or in the axial direction (figure 1) along the stabilizing sleeve. At present, it is preferable that the sleeve 308 had three such blades 314, evenly distributed around the circumferential periphery of the sleeve. However, the present invention is not limited to this embodiment with three blades and can be used with ensuring its advantages in other designs of blades.

For purposes of illustration is shown a cross section of two embodiments of a node 210A and 210b for measuring pressure. Node 210A to measure pressure is within the stabilizing blades 314a and is designed to perform various measurements. Node 210A for measuring pressure can be used for automatic control of pressure in the annular space in the wellbore and/or pressure of the surrounding formation when entering this site in contact with the wall of the wellbore. As shown in figure 2, node 210A to measure pressure is not in contact with the wall 110 of the wellbore and, therefore, can realize the measurement of pressure in the annular space when the need is I. When entering this site in contact with the wall 110 of the wellbore node 210A for measuring pressure can be used to measure the pore pressure of the surrounding formation.

As shown in figure 2, node 210b for measuring pressure is arranged to throw it from stabilizing blades 314a to enter into tight contact with the filtration crust 105 drilling mud and/or wall 110 of the barrel 11 wells for the measurement of the characteristics of the surrounding formation. Node 210b for measuring pressure can be powered, as will be described below, to throw him out of the stabilizer so that the node has reached the wall of the surrounding well bore to perform the specified dimension. In a possible variant, but not necessarily, the node 210b for measuring pressure can also be used to measure pressure in the annular space when the node is not in contact with the wall of the wellbore. One or more nodes for measuring pressure having different configurations may be used in one or more stabilizing blades to perform the specified dimensions.

On figa and 3B node 210A to measure the pressure shown in more detail. On figa node 210A to measure the pressure shown in the closed position. On FIGU node for measuring the pressure shown in the ogenyi measurement or open position. Node 210A to measure pressure is in the chamber 355 in stabilizing blades 314a. Node 210A for measuring pressure includes a piston 350 and the spring 365. The piston has a first part 375, made with the possibility of displacement of the sliding inside the chamber 355 in stabilizing blades 314a and the second part or rod 370 passing from the first part. The second part 370 passes from the chamber 355 in the penetration hole 380 and configured to bias it with slip. The piston may be provided with seals to facilitate the movement of the camera and/or in the bore hole. The penetration hole 380 passes from the opening 385 in the extension through stabilizing the blade 314a and into the chamber 355.

The piston preferably has a sensor 360, such as a manometer, capable of performing downhole measurements. The sensor is preferably open to the influence of fluid next to the first part 370 of the piston 350. The sensor may be configured to monitor and/or selective reading, for example, measuring the pressure during the execution of the works in the well.

Spring 365 is located around the first portion 370 in the cavity 381 formed in the chamber 355 between the second part 375 of the piston and the chamber walls. As shown in figa, the spring is compressed in the cavity 381 between the piston 350 and the chamber 355. Cavity 381 communicates via a fluid barrel with SLE is new well through the channel 390. Luggage 355 communicates via a fluid wash channel 215 (2) of the downhole tool. In a possible variant, but not necessarily, filled with oil, the piston can be placed in the channel 397 for isolation of the mud node 210A for measuring pressure, this will continue to ensure that the application of pressure to the given node.

During operation of the drilling mud passing through the downhole tool, creates internal pressure PI. Between the internal pressure and the pressure PAndin the wellbore creates a pressure differential. When the drilling fluid is held in the flushing channel 215, the pressure drop increases, and the pressure will act on the chamber 355. Choke 240 (figure 2) or similar device may be used to limit or delay the passage of drilling fluid through the channel 220 (figure 2), resulting in the movement of the piston is delayed. As soon as sufficient pressure is created in the chamber 355, the internal pressure PIwould cause the application of force to the piston 350, as shown by the arrow. This internal pressure exceeds the pressure PAndin the annular space and the force acting from the side of the spring 365, resulting in the displacement of the piston towards the openings 385 in stabilizing blades 314a.

Fluid under p is lost 381, may freely pass between the bore and the cavity through the channel 390. The first part 375 of the piston compresses the spring 365. The second part 370 is shifted to the hole 385 and fills the bore hole 380. Thus, when the drilling fluid passes through the flushing channel 215, the internal pressure due to them, causes the application of force to the piston 350 and offset it in closed position. In the case when the node for measuring pressure is not in contact with the wall of the wellbore and filtration crust of mud, the sensor can perform downhole measurements in the wellbore, such as the measurement of pressure PAndin the annular space of the wellbore.

As shown in figv when the tool enters the rest state and the drilling fluid ceases to flow through the instrument, the internal pressure decreases and the pressure differential between the internal pressure and the pressure in the wellbore in this case drops to values close to zero. The internal pressure no longer has such a magnitude that causes the application of force to the piston 350 and the compression spring 365, and the spring expands to its provisions weakening. The expansion of the spring causes the retraction of the piston from the hole 385 and in stabilizing the blade. Fluid (drilling mud), which is in the cavity 355, may be displaced into the flushing channel 215 and/or flowing the fluid from the wellbore can be retracted into the cavity 381.

The retraction of the piston in stabilizing the blade creates a small cavity 395 (usually with a volume of approximately 1 cm3up to approximately 3 cm3), passing from the opening 385 in the penetration hole 380. Sensor 360 pressure measures the pressure of the fluid in the cavity as retraction of the piston in the tool. When there is no contact with the wall of the wellbore, it is possible to fill the cavity 395 fluid medium from the wellbore. In this position, the sensor can perform or continue to perform measurements in the wellbore. However, when the node for measuring pressure is in contact with the wall 110 of the wellbore, the exhaust piston in stabilizing the blade will cause retraction of the formation fluid in the cavity 395 and will provide the possibility of obtaining data on the reservoir, such as pore or reservoir pressure. The passage of fluid into the cavity and the corresponding measurements can also be used to perform preliminary tests. How to perform preliminary tests known to experts in the art and described, for example, in U.S. patent No. 4860581 and No. 4936139.

Once again will start the circulation of drilling fluid through the tool and there will be a sufficient pressure differential, the piston will return to the position shown in figa. Thus, the node DL is the pressure measurement can be used to perform multiple downhole measurements. When the drilling fluid passes through the downhole tool, the piston is shifted to the closed position shown in figa, in the process of "training" for the next test (measurement). When the flow of drilling fluid is stopped, the piston returns to its open position shown in figv, and the cycle begins retracting. The operation may be repeated as many times as needed. The delay offset of the piston can be provided by embedding the throttle channel 397 to limit the flow from the chamber 355.

On figa and 4B node 210b for measuring the pressure shown in more detail. On figa node 210b for measuring the pressure shown in the extended position. On FIGU node 210b for measuring the pressure shown in the position-of-way. The corresponding hydraulic circuit 400 controls shown schematically for each of these figures to allow for more job description node for measuring the pressure in each position.

Node 210b for measuring pressure includes internal node 405 for measuring the pressure mounted in the measuring head 410. Measuring head 410 includes a movable bearing element 412, the multiplexer 414, the spring 416 and the sleeve 417. The movable bearing element 412 is located in the chamber 418 in stabilizing blades 314a and configured to bias it with slip. Can be nedosmotreli seal 420 to seal the measuring head in the camera and move easily in it. Seal 414, usually made of elastomer or rubber, is located on the outer end of the movable support member 412 to ensure tight contact with the wall of the wellbore. Sleeve 417 preferably installed inside the chamber 418 and is connected with it through a threaded hole 415 in stabilizing the blade. Sleeve 417 covers the circumference of the movable supporting member and the movable bearing member configured to bias inside the sleeve from sliding. Spring 416 covers the circumference of the movable supporting member and is compressed in the cavity 419 between the sleeve 417 and the flange 422 of the rolling bearing element 412. The cavity 421 is formed between the flange 422, a movable bearing element 412, and a stabilizing blade 314a.

In the movable bearing element 412 has an internal camera 355b. Internal node 405 for measuring pressure is located in the inner chamber 355b. Like node 210A to measure the pressure shown on figa and 3B, the internal node 405 for measuring pressure includes a piston 350 and the spring 365. The piston has a first part 375, made with the possibility of displacement of the sliding inside the chamber 355b, and the second portion 370 extending from the first part. The second part 370 passes from the camera 355b in the penetration hole 380 and configured to bias it with slip. The piston may be provided with seals is s to isolate different parts of the camera from one another and/or from contamination from outside mud. The piston preferably has a sensor 360, capable of performing downhole measurements. Spring 365 is located in the chamber 355b around the first part 370. As shown in figa, the spring is compressed in the cavity 381 in the camera 355b between the second part 375 of the piston and the chamber walls. Cavity 381 reported by fluid from the chamber 418 through the channel 465. Luggage 355b reported in a fluid environment with oil under pressure from the flushing channel 215 of the downhole tool through a channel 460, cavity 419 and channels 448, 440 and 442.

Hydraulic circuit 400 controls that are used to control the node 210b for measuring pressure includes a compensator 424 low-pressure compensator 426 high pressure and battery 428. The hydraulic control circuit is preferably provided to enable selective actuation or disable the measuring head and/or nodes for pressure measurement with sensors. This additional control may be required during drilling, tripping operations or in other situations where it is desirable actuation or disable nodes for measuring pressure. The sensor or sensors can be used for issuing the data necessary to determine whether such a situation.

Expansion joints are preferably made with the possibility lighting is sablemane to changes in volume, caused by pressure drops, temperature changes and/or movement of the downhole tool. The compensator 424 low pressure is connected in the operating position with the chamber 418 in stabilizing blades 314a through channel 429. The low-pressure compensator has a movable piston 433, forming the first chamber 430 variable volume and the second chamber 432 variable volume. The first chamber 430 communicates via a fluid channel 429 and the second chamber 432 communicates via a fluid from the wellbore (and/or her acting pressure PAndin the annular space of the wellbore).

Battery 428 is connected in position with the channel 429 through channel 434. The battery is stored oil under high pressure, and it can be used to increase the pressure in the chamber 421. The battery has a spring-loaded piston 435, forming the first chamber 436 and the second chamber 438. The first chamber 436 is connected by fluid channel 434 and channel 429. The second chamber 438 of the battery is connected through channels 456, 440 and 442 with compensator 426 high pressure through channels 444 and 446 with camera 421 and through channels 444, 460, 442 with a cavity 419.

The compensator 426 high pressure has a movable piston 453, forming the first chamber 450 variable volume and the second chamber 452 variable volume. The first camera 450 is connected on the of Echuca environment with camera 421 through channels 442, 440 and 446, with battery 428 through channels 442, 440 and 456 and cavity 419 through channels 442, 440 and 448. In the channel 456 is located a check valve 454, designed to prevent the passage of fluid from the second chamber 438 428 battery in the channel 440. The second chamber 452 compensator 426 high pressure is communicated in fluid with the flushing channel 215 stabilizing extension 300A (figure 2), and there is an internal pressure PIexisting in the flushing channel 215.

Various devices can be provided in the control circuit to monitor, control and/or regulation of the fluid flow, and/or the measuring head and/or nodes for measuring pressure. May be a sensor 490 internal pressure, designed for monitoring the internal pressure in the hole 415. May be a sensor 495 pressure in the annular space, designed to monitor the pressure in the annular space of the wellbore. Monitoring both pressure can also be carried out simultaneously by a sensor (not shown) of the differential pressure. Choke 458 (or adjustable aperture, electric controller or other limitation) is preferably provided in the channel 460 to slow down the flow of fluid through the channel 460 (i.e., between the second chamber 438 AK is the battery 428 and the compensator 426 high pressure). Choke 462 preferably installed in the channel 460 to limit and/or delay of the fluid flow leaving the camera 355b.

Electric on-off switch (not shown) may also be provided for actuating the hydraulic circuit 400 controls. After turning the system will not need any additional signals to bring the system into action in order to perform tests (measurements). The system is designed with the ability to work without activation. However, there is the possibility of adding electronic control devices and/or signals to communicate with the system. One way to influence this inclusion is to incorporate the dip switch in the hydraulic control system. Electric two-position switch can be connected to the first chamber 430 compensator low pressure and/or with the first camera 450 compensator for high-pressure transmission signal, causing the isolation pressurizer high pressure from the system. In this case, the battery will not be filled, and changes in differential pressure will not affect the system.

In the position shown in figa, node 210b for measuring pressure is in the extended position. Fluid (drilling mud) is no longer passes through the downhole tool, the t to create a pressure drop. The pressure of the fluid in the second chamber 452 compensator 426 high pressure decreases, and the piston 453 may shift, causing a reduction in the size of the chamber 452. The camera 450 increases, which causes a retraction of the fluid from the cavity 419 and enables removal of the spring 416, which leads to the displacement of the rolling bearing element 412 of the blades 314a. The decrease of the internal pressure in the chamber 452 also leads to the displacement of the fluid in chamber 438 of the battery, the channel 444. A large part of the fluid in the channel 444 passes through the channel 446 in the cavity 421, which leads to the application of force to the flange 422, causing the displacement of the movable support member to the outside of the roll blades. Lets pass some part of the fluid channel 460 and the channel 440. However, the throttle 458 restricts the flow of fluid through it and provides only a limited release this fluid environment.

As the displacement of the fluid in chamber 438 of the battery, the piston 435 is shifted, which causes the expansion chamber 436. Fluid is drawn from the chamber compensator 430 424 low pressure in the chamber 436 through the channels 434 and 429. Also allows passage of the fluid in chamber 430, line 429 in the chamber 418.

Internal node 405 DL is the pressure measurement is also made with the possibility of bias in the measuring cylinder 410 between the open position or the measuring position, shown in figa, and a closed position shown in figv. As shown in figa when the tool goes into a state of rest and fluid ceases to flow through the tool, the pressure in the chamber 355b decreases with decreasing pressure differential between the internal pressure and the pressure in the wellbore. The pressure in the chamber 355b is reduced due to the exit of the fluid through the channel 460 into the cavity 419. By decreasing pressure in the chamber 355b, the force acting from the side of the spring 365, leads to vtalkivaniya piston in the chamber 355b. Could be a throttle for restricting the flow through the channel 465 to ensure delays if necessary. Fluid located in the cavity 381, communicates with the fluid medium in the chamber 418 through the channel 465. Preferably provides delay and delay flow into the cavity 418, so that the measuring head is completely out of the blades 314a before the offset of the piston 350.

The retraction of the piston in the extension creates a cavity 395 (usually with a volume of approximately 1 cm3up to approximately 3 cm3), passing from the opening 385 in the penetration hole 380. Is possible to fill the cavity 395 fluid medium from the reservoir, when the sealant layer 414 and creates a seal. Sensor 360 pressure preferably is located next to the bands who followed to measure the pressure of the fluid in the cavity as retraction of the piston in the tool. Pre-test and/or other measurements can be performed to determine various downhole characteristics of the surrounding formation.

You can control the movement of internal node 405 for pressure measurement and the measuring head 410, so that the movement occurred at the specified time. For example, the throttle may be used to delay the flow of fluid and a corresponding retraction of the internal node for measuring pressure in order to ensure the availability of sufficient time to form a seal between the measuring head and the wall of the wellbore. Can be provided by other schemes to create a selective flow of fluid through the circuit and the operation control node for measuring pressure.

As soon as spring accumulator 428 is fully extended, the oil pressure from the chamber 438 is produced)is discharged through channels 444, 460, 440 and 442 in the chamber 450. The pressure in the channel 446 continues to decrease until, until it reaches the hydrostatic pressure environment. Spring 416 allows removal of the measuring head back into the blade 314a, and the cycle is completed. The piston 350 is in its open position, or the position of the measurement (test), and the process can be repeated.

On FIGU node 210b for measuring pressure shown during the operas the tion, performed during filling of the downhole tool. When the fluid (drilling mud) is pumped through the inner flushing channel 215, it creates a higher internal pressure PIcompared with the pressure in the annular space, resulting in a pressure drop. This differential pressure causes displacement of the piston 453, calling the expansion chamber 452 and reducing the size of the camera 450. Fluid displaced from the chamber 450 in the chamber 428 channels 442, 440 and 456. Fluid also is displaced from the chamber 436 and into the chamber 430 through the channels 434 and 429. The flow of fluid entering the chamber 430, causes displacement of the fluid in chamber 432 in the wellbore.

Fluid also passes from the chamber 450 in the camera 355b channels 442 and 448, through the cavity 419 and channel 460. The flow of the fluid coming into the camera 355b, creates pressure to overcome the force acting from the side of the spring 365, and causes displacement of the piston in the direction of the hole 385. Spring 365 is compressed in the cavity 381 between the second part 375 and the chamber walls. Fluid is discharged from the cavity 381 channel 465 into the chamber 418 and goes back into the chamber 430 through the channel 429. The first part 375 piston tightened to a spring 365, and the second part, or the rod 370 fills the bore hole 380. Internal node 405 for measuring pressure t is now filled for the next pressure measurement.

On figa and 5B depicts the electronic elements for a node to measure pressure. On figa shows an implementation option with the inclusion of the windings overlap, and figv shows a variant implementation of the counter-parallel windings. Sensor 360 preferably is a small sensor, such as microelectromechanical sensor located at the outer end of the piston 350 is near the opening 385 in pass-through hole 380. The sensor is preferably configured to measure various downhole characteristics, such as pressure, temperature, viscosity, permeability, chemical composition, H2S, and/or other downhole characteristics. May provide a hermetic seal to isolate the sensor on the end of the piston. Seals can be provided to reduce the volume to conduct research in the cavity 395 needed to perform the specified dimensions. Between the sensor and the tool provided by the contacts through hermetically isolated I/o for connection with the electronic devices of the instrument.

Electronic instrument device preferably provides power to the sensors and/or communication with the sensors. Shown in figa an implementation option with the inclusion of the windings overlap includes the perceiver is bmode 500 & transmitter coil 505. Perceiving winding 500 is preferably located in the first part 375 of the piston 350. The transmitting coil 505 is preferably located around the chamber 355. At least part of the perceiver and/or transmitting windings are preferably made of non-conductive material, such as ceramics.

A magnetic field is created between the perceiver winding 500 and the transmitter coil 505. This field provides the ability to create a wireless connection between the perceiver coil and the transmitting coil. Power supply and data transmission to the sensor are carried out through the wireless connection. However, wired communication is used to create a connection between the electronic circuit node for measuring pressure and electronic circuits in the rest of the instrument, as shown by the arrow in the shape of a spiral. The transmitting coil is preferably overlaps perceiving the coil, but it does not depend on the position of the sensor in the chamber 355.

An implementation option with a counter-parallel windings shown in figv includes perceiving the winding a, transmitting winding a and ceramic window 560. Perceiving winding 500A preferably located in the first part 375 of the piston 350. Ceramic window 560 is preferably located on the inner wall of the chamber 355. The transmitting coil ale is located in the extension next to the ceramic window.

The magnetic field BA is created between the perceiver winding 500A and transmitting winding 505A. This field enables the creation of wireless connection between the perceiver coil and the transmitting coil. Power supply and data transmission to the sensor are carried out through the wireless connection. In this embodiment, wireless communication can also be used to create a connection between the electronic circuit node for measuring pressure and electronic circuits in the rest of the tool.

This variant implementation eliminates the need to use wires for the sensor and the surrounding cap with thread. One or more non-metallic ceramic window can be located between the receptive coil and the transmitting coil to allow communication through these Windows. Mechanical site eliminates the need to use I/o for wire winding. Instead provided a metal box or window between the sensor and the main transmitting coil. Windows allow you to provide a link between the two windings. Although in the shown embodiments, the implementation of the excluded wired connection and/or inputs/outputs, some of the options for implementation may include similar elements.

Figure 6 shows the block diagram illustrated yuusha the interconnection of electronic devices, designed for control units for measuring pressure. One or more nodes to measure the pressure sensors 360 pressure, are used to collect data on borehole characteristics. The sensors are connected to the downhole electronic devices or via a wireless connection, as shown in figa, or via a wireless connection, as shown in figv. Distribution and protection of power and/or signals in communication channels is carried out by using a distribution device 700. The signals pass through the pre-amplifiers 705 and demodulator 710, and fed to the control device 715 for processing. You can also receive signals from one or more sensors, such as sensor 490 internal pressure and/or the sensor 495 pressure in the annular space, and processing them in the control unit. The control device can be used for analysis, collection, sorting, manipulating and/or processing the data otherwise. Data can be transferred to the surface through an interface 720 for telemetry on mud pulse communication channel. Signals can also be fed into the borehole through an interface for telemetry on mud pulse communication channel and thus submitted to the control device.

Battery 725 may be provided about what especiany supply for the control device and/or sensors. Rechargeable battery provides power to the amplifier 730 power. The signal power passes through the device for distribution and protection signals to the sensor or sensors 360 pressure. The signal power can be used to supply power to the sensor or sensors.

Although the invention has been described in connection with a limited number of embodiments, for specialists in the art after study of this specification it will be obvious that can be developed other ways to exercise that will not go beyond the scope of the invention as it is disclosed here. For example, embodiments of the invention can be easily adapted and used to perform certain operations on testing or investigation layers, without departing from the invention. Accordingly, the scope of the invention should be limited only by the attached claims.

1. Device for collecting data on downhole characteristics during the operation of drilling through the downhole drilling tool located in the borehole, with the pressure in the annular space of the well bore and passing through an underground formation having a pore pressure, while the downhole tool is configured to bandwidth brown is on solution passing through it so that it creates an internal pressure between the internal pressure and the pressure in the annular space created by the pressure difference, whereby the device comprises a strip made with the possibility of connection in the working position with the drillstring drilling tool and having made the flushing channel for passing drilling fluid through it, the hole passing in the pressure chamber communicated in fluid with the flushing channel and/or the well bore, a piston mounted with a possibility of displacement in the pressure chamber, with the piston rod passing from it into the hole of the extension tube, and is arranged to bias in the closed position under the action of increased pressure drop in the open position under the action of reduction of the pressure drop so that in the closed position, the stem fills the hole, and in the open position, at least part of the rod is retracted into the camera so that the hole forms a cavity for receiving the downhole fluid, and a sensor located in the stem and is designed to collect data from the downhole fluid located in the cavity.

2. The device according to claim 1, additionally containing a piston spring connected in operating position with the piston and made with the possibility of application of force to the piston to provide is Ojima piston to the open position.

3. The device according to claim 2, in which with the passage of drilling fluid through the flushing channel spring piston capable of creating a force sufficient to overcome the pressure difference applied to it.

4. The device according to claim 2 or 3, wherein when the drilling fluid does not pass through the flushing channel, the piston spring is able to create a force sufficient to overcome the differential pressure applied to it.

5. The device according to claim 1, additionally containing a measuring head, located in the pressure chamber and configured to shift between a position of the outlet where it is plugged in to an extension, and extended position in which it is extended from the extension, with the measuring head has a hole passing into the chamber of the measuring head, and a piston mounted in the chamber of the measuring head so that in the closed position, the stem fills the hole of the measuring head, and in the open position, at least part of the rod is retracted into the chamber of the measuring head so that the hole of the measuring head is formed a cavity for receiving the downhole the fluid.

6. The device according to claim 5, additionally containing a spring measuring head connected in operating position with the measuring head and made with the possibility of application of force to the measuring head is AK, what is pressing the measuring head in the extended position.

7. The device according to claim 5, in which with the passage of drilling fluid through the flushing channel spring piston capable of creating a force sufficient to overcome the pressure difference applied to it.

8. The device according to claim 5, in which when the drilling fluid does not pass through the flushing channel, the piston spring is able to create a force sufficient to overcome the differential pressure applied to it.

9. The device according to claim 5, additionally containing cylinder for measuring the pressure in the annular space, cylinder for measuring the internal pressure and the battery, while the cylinder for measuring the pressure in the annular space indicated by fluid from the wellbore and the pressure chamber, a cylinder for measuring the internal pressure generated by fluid from the flushing channel and one of the following elements: a first cavity in the chamber between the measuring head and extension, the second cavity in the chamber between the measuring head and extension, and their combinations, the battery reported by fluid from the pressure chamber in the annular space and cylinder for measuring the internal pressure.

10. The device according to claim 9, in which the battery is selectively communicated in fluid with the cylinder for measuring inside nego pressure.

11. The device according to claim 10, further containing a non-return valve, is arranged to provide output fluid from the battery and pass it into the cylinder for measuring the internal pressure.

12. The device according to claim 10, further containing a throttle is arranged to provide ease the pressure in the line between the cylinder for measuring the internal pressure in one of the following elements: a battery, a second cavity and their combinations.

13. The device according to claim 9, further containing a switch for selectively actuating cylinders for measuring pressure.

14. The device according to claim 1 or 5, optionally containing an electronic communications device between the sensor and electronic circuits in the downhole tool.

15. The device according to 14, in which the electronic communication device includes perceiving winding having wireless communication with the transmitting coil.

16. The device according to item 15, in which the perceiver winding is located in the piston and the transmitting coil is located around the pressure chamber.

17. The device according to 14, in which the electronic communication device connected through a wired connection with electronic circuits in the downhole tool.

18. The device according to 17, in which the electronic communication device includes perceiving the winding, peregaux the winding and ceramic window between them, while perceiving the winding has wireless communication with the transmitting coil with ceramic window.

19. The device according to p in which electronic communication device connected via a wireless connection with electronic circuits in the downhole tool.

20. The device according to claim 1, additionally containing one of the sensors: sensor internal pressure made with the possibility of determining the internal pressure in the flushing channel, the pressure sensor in the annular space, is arranged to determine the pressure in the annular space in the wellbore, the sensor of the differential pressure, and combinations thereof.

21. The device according to claim 5, additionally containing one of the sensors: sensor internal pressure is made with the ability to determine internal pressure, gauge pressure in the annular space, is arranged to determine the pressure in the annular space in the wellbore, the sensor of the differential pressure, and combinations thereof.

22. The device according to claim 20, further containing a control device that is connected in the operating position with the sensors and configured to process signals from the sensor for use at the top of the wellbore.

23. The device according to item 21, further containing a control device that is connected in the operating position with the sensors and configured to process signals from the sensor for use at the top of the wellbore.

24. The device according to item 22 or 23, further containing processor for processing signals, the preamplifier and demodulator for processing signals from the sensors.

25. The method of data collection downhole characteristics during the operation of drilling through the downhole drilling tool located in the borehole, with the pressure in the annular space of the well bore and passing through an underground formation having a pore pressure between the internal pressure in the downhole drilling tool and the pressure in the annular space created by the pressure difference, and the method includes the following operations:

equipment downhole drilling tool extension having a through flushing channel and a hole passing into the chamber, and a piston mounted with a possibility of displacement in the chamber and having a stem passing from it into the hole, and configured to shift between a closed and an open position;

the installation of the downhole drilling tool in the well bore; a selective change of the differential pressure to move the piston between the open and closed position;

perception data from the downhole fluid located in the cavity, by a sensor in the piston.

26. The method according A.25, in which the change of the pressure drop occurs is avtomaticheskij as a result of changes in pressure in the annular space and/or internal pressure.

27. The method according A.25, in which the operation of the electoral changes performed by selective transmission of drilling fluid through the downhole tool.

28. The method according A.25, which in the open position in the hole to create a small volume for receiving the downhole fluid.

29. The method according A.25, in which the hole passes through the outer surface of the extension.

30. The method according to p. 25, further comprising applying energy to the piston.

31. The method according to item 30, in which the energy is supplied from a remote power source.

32. The method according to item 30, in which the energy source is due to changes in differential pressure.

33. The method according A.25, including additional perception data from the internal pressure sensor in the downhole tool and/or pressure sensor in the annular space provided in the downhole tool.

34. The method according to p. 25, further comprising processing the data for use at the top of the wellbore.



 

Same patents:

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FIELD: mining.

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FIELD: oil and gas industry.

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1 dwg, 6 tbl, 1 ex

FIELD: mining.

SUBSTANCE: invention refers to the mining industry, namely to the drilling equipment, and is designed for research of optimal drilling mode parameters based on the temperature rise criteria in the contact zone of the drilling tool and the rock. The device includes the core holder with a rock sample as the core installed at the spindle of the core drill, the thermal frictional tool, the optic cable laid along the gallery hole of the tool frame with its end at the friction tool end plane, connected in series with the receiver-amplifier and the registering device, the core tube with a nozzle for water input, the anti-spatter protection cover, and the water collector with water drain. There is a gallery hole connecting the internal and the external cavities of the tool in the thermal friction tool frame. This allows to cool the optic cable with water coming to the core tube, which reduces the additional IR-radiation being a hindrance to the main signal.

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2 cl, 2 dwg

FIELD: mining.

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2 dwg

FIELD: oil and gas production, particularly to perform measurements during well drilling (initial well completion) to obtain information concerning temperature and pressure of drilling mud flow injected in well directly from well bottom to area of drilling mud flowing through jet bit nozzles and turbine blades, as well as in hole annuity of the well after rock cutting by bit and turbine blades and crushed rock washing-out from well bottom.

SUBSTANCE: device comprises sub with container connected to outer surface thereof installed between drilling pipe or tubing assembly and drilling tool assembly. The container has orifices in upper and lower parts thereof. Self-contained measuring instrument is installed inside container. Two mutually independent temperature and pressure sensors are arranged in upper and lower parts of measuring instrument so that temperature and pressure are located in immediate proximity to container orifices. Distance between container orifices does not exceed two meters. Heat-insulation sleeve is installed in central container part in fluid-tight manner. Self-container measuring instrument may be supported by springing support and does not touch container body.

EFFECT: increased reliability of results obtained during thermobaric drilling mud or flushing liquid condition measuring in pipe string and annular spaces simultaneously, possibility to take measurements during any technological operation, well construction and development.

4 cl, 2 dwg

FIELD: oil production, particularly thermal field investigation inside producing wells.

SUBSTANCE: method involves lowering downhole cable provided with temperature meter in well, wherein downhole cable is arranged outside production string. Fluid temperature is measured by means of downhole measuring-and-stabilizing unit including at least one temperature sensor and parameter stabilizing device. The temperature sensor is installed so that sensing member thereof touches production string wall or production string clutch wall or is located in immediate proximity thereto. Crystal resonators are used as the temperature sensors. Land-based measuring assembly includes frequency electronic measuring module. The land-based measuring assembly and conductive signal transmitting communication line thereof with measuring-and-stabilizing unit may simultaneously read signals from all temperature sensors if number of temperature sensors exceeds 1.

EFFECT: increased measuring accuracy in working well in initial and following time periods and possibility of method usage in wells with any oil recovery mechanism.

7 cl

FIELD: testing the nature of borehole walls, formation testing, methods or apparatus for obtaining samples of soil or well fluids, namely downhole tools to determine reservoir parameters.

SUBSTANCE: method involves arranging downhole tool having probe in well bore, wherein the probe comprises at least one executive mechanism for probe extension and retraction; moving the probe to provide probe contact with well wall and accumulating reservoir data. Protective screen is arranged around probe. The protective member may slide between retracted position, where protective member is arranged near body, and extended position, where protective member touches well bore wall, independently of probe.

EFFECT: improved probe and well bore protection, possibility to accumulate data or take samples without erosion.

30 cl, 10 dwg

FIELD: survey of boreholes or wells, particularly measuring temperature or pressure.

SUBSTANCE: device comprises pretest piston to be arranged in flow communication with reservoir, a number of manometers installed in pressure line and valves for selectively supply one of fluid or drilling mud in measuring device. Method involves performing the first test to determine reservoir parameter to be estimated; using the first pretest for the second pretest calculation and obtaining estimated reservoir parameters for reservoir characteristics evaluation.

EFFECT: possibility of reservoir testing device usage to perform measurements at well bottom during predetermined period, decreased land-based system intervention.

36 cl, 27 dwg

FIELD: well survey, particularly to control technical condition of oil well sections over or under hydrostatic well level, as well as of gas well under pressure, by repeated non-contact measurement of infrared well wall surface radiation.

SUBSTANCE: device comprises body, protective optical system window, infrared radiation receiver, modulator, thermostat, infrared radiation chopping frequency stabilizing block, thermostating and thermostabilizing unit, signal amplifying and converting unit, body temperature sensor, electronic body temperature sensor signal amplifying unit; electronic protective window radiation compensation unit. Receiver pickup converts infrared well wall radiation and protective window radiation into electric signal. Contact temperature sensor installed in device body generates electric signal, which is proportional to protective window temperature. Said signal is supplied to electronic body temperature sensor signal amplifying unit and to compensation unit and is mixed with electric signal generated by radiation receiver to compensate signal component defined by protective window radiation in real time so that user registers only electric signal proportional to infrared well wall radiation.

EFFECT: decreased measurement time along with decreased costs.

2 cl, 1 dwg

FIELD: well survey, particularly to determine thermal properties of rock seams surrounding wells during well drilling or cased wells, as well as to detect technical conditions of wells during well operation and downhole equipment operation regimes.

SUBSTANCE: device comprises three identical heat-sensitive sensors arranged along well axis at predetermined locations and adapted to measure the second temperature difference, namely the first, the second and the third ones. Each heat-sensitive sensor includes four identical heat-sensitive resistors constituting heat-sensitive bridges. Heat-sensitive bridge unbalance difference is proportional to the second temperature difference. Unbalance sum is proportional to the first temperature difference. All heat-sensitive resistors are used to measure absolute temperature of probe receiving medium. The first temperature difference depends on constant temperature change along well bore and on local temperature change. The second temperature difference depends only on local temperature change.

EFFECT: increased fullness of temperature field recording and measurement accuracy.

2 dwg

FIELD: well boring, particularly for measuring pressure in well during drilling thereof.

SUBSTANCE: device has body with central flushing orifice and grooves. Arranged in the grooves are electrical circuits and positive pressure transducers isolated by pressure-resistant shell. The first pressure transducer is connected with central flushing orifice in tube, another one - with annular tube space. The device is provided with power source and two differential amplifiers with outputs connected to summing unit inputs. Supply diagonal units are linked correspondingly with power source inputs. The first units of measuring diagonals of the first and the second pressure transducers are connected correspondingly with inverting and non-inverting inputs of the first differential amplifier. The second units of measuring diagonals of the first and the second pressure transducers are linked correspondingly to inverting and non-inverting inputs of the second differential amplifier. The first and the second pressure transducers may be arranged in the body at 0°-45° and 153°-180° angles to vertical device axis correspondingly or may be inversely arranged. The body may be formed of titanic alloy.

EFFECT: increased measuring reliability.

4 cl, 2 dwg

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