RU2273868C2 - Device for placement of descending instrument, method of transmission and/or reception of signal from ground formation and method of measurement of characteristics of ground formation using by descending instrument - Google Patents

Abstract

FIELD: testing of ground formation.

SUBSTANCE: device has change-over unit which has elongated body with tubular walls and central hole, made for placement of descending instrument. Tubular member has sections for transmission or/and reception of signal through tubular member; sections are provided with slots. Hydraulic insulation between internal and external sides of tubular member is provided by making anti-pressure barrier in slot-provided sections. Detectors and/or sources are mounted onto descending member made for passing through drill pipe string to engage inside tubular member when getting in coincidence with slot-provided sections. Descending member has modulator to conduct electric communication with surface in real-time scale and/or with remote well instrument. Assemblage of tubular member and descending instrument includes communication inductive members fro transmitting parameters of signal along radio channel. Descending instrument with replaceable end segment is used in method for measurement characteristics of formation for passing well through in different modes.

EFFECT: simplification; improved reliability; higher efficiency.

33 cl, 28 dwg

Description

The present invention relates, in General, to the study of deep earth formations, to devices and methods for transmitting and / or receiving signals through a metal tubular element and, in particular, to a device for placing a trigger tool.

Electrical resistivity logs and gamma-ray logs are among the two evaluative measurements most often performed in geophysical surveys in wells. Such measurements are used to detect and evaluate the properties of potential oil and gas zones in deep formations. In many wells, especially at a low cost of wells, only two measurements are performed, and at a higher cost of wells, measurements are performed on the surface and in intermediate sections.

These logging methods are carried out in various ways.

A downhole tool containing a series of transmitting devices and detectors designed to measure various parameters can be lowered at the end of a cable or wire rope. A cable that is attached to a mobile processing center of some kind on the surface is the means by which parametric data is transmitted to the surface. Using this type of wireline logging, it becomes possible to measure well parameters and formations as a function of depth, i.e. as the device pulls up the wellbore.

In some wells, when the drilling time is taken into account in the total cost, it is impossible to carry out logging, since wireline logging is too expensive. Bringing the parameters of the well to the necessary for wireline logging, installation of a tool lowered into the well on the cable and the time for lowering and pulling the tools lowered into the well on the wireline reduce drilling time. Horizontal or deviated wells are also characterized by increased cost and it is difficult to use tools related to the cable in them.

An alternative to wireline methods is to collect data on the operating conditions in the well during the drilling process. When collecting and processing such information during the drilling process, the driller can modify or adjust key stages of the drilling operation to optimize performance. The sequence of operations to collect data on operating conditions in the well and regarding the movement of the drill string with downhole drilling equipment and tools during drilling operations is known as the method of downhole research during drilling. Similar methods, aimed more at measuring formation parameters than at moving the drill string, are known as logging methods during drilling. As in the case of wireline logging, the use of logging tools during drilling and downhole exploration during drilling cannot be justified, due to the high cost of equipment and appropriate operation, since the tools are in the well for the entire duration of the drilling.

Logging during the tripping cycle is a cost-effective alternative to logging methods while drilling and downhole exploration while drilling. When logging during the tripping cycle, the "small" diameter tool is lowered into the well along the drill string at the end of the bit, immediately before the drill string is pulled. The trigger tool is used to measure the physical performance of the well when the drill string is removed or lifted from the well. During the ascent, the measured data is recorded as a function of time in the instrument memory. On the surface in the second set of equipment during the ascent, the bit depth is recorded as a function of time, and this provides the ability to compare depth measurements.

US Pat. No. 5,589,825 describes a logging method during a tripping cycle using a borehole logging tool configured to move along a drill string in a drill string sub. US Pat. No. 5,589,825 describes a sub having a window structure to enable signal transmission between a well logging probe enclosed in a housing and a wellbore. The window structure may be open or closed. The disadvantage of the proposed device is that when the window is open, the well logging probe is exposed to the rough and abrasive environment of the well, while fragments of cuttings can damage the well probe and jam the window structure. At greater depths, downhole conditions are gradually becoming more unfavorable. At depths from 5000 to 8000 m, temperatures of about 260 ° C and pressures of about 170 MPa take place. This enhances the destruction of the external or open elements of the downhole probe. Therefore, the design with the opening window is impractical in downhole conditions.

British Patent Application No. 2,337,546A describes a composite material structure enclosed within an extension cord to allow passage of electromagnetic energy during measurements during drilling operations. In this application No. 2337546A, an extension cord is described having grooves or recesses with embedded covers of composite material. The disadvantage of the device proposed in the application No. 2337546A, is the use of composite materials for the manufacture of integral parts of the extension cord. Fatigue loads (i.e. bending and rotation of the drill pipe) result from drilling operations. When the drill pipe undergoes bending or torsion, the shape of the grooves or grooves changes, which leads to destruction of the device due to stresses or to a deterioration of the seal. When the composite material and the metal must work mechanically as a whole, as described in the indicated application of Great Britain No. 2337546A, differences in the properties between the metal and the composite material of the caps is difficult to compensate for accordingly. Therefore, the increased tendency to fracture under extreme stresses and loads arising during drilling operations makes the implementation of the described construction impractical.

US Pat. Nos. 5,988,300 and 5,944,124 describe a tubular composite structure constructed for use in a drill string. In these patents, a composite structure is described, including a pipe combined with end fittings and connected to end fittings via an external winding. In addition to the high manufacturing costs, another drawback of this design is that the multi-part structure is more prone to failure under extreme stresses arising during drilling operations.

US Pat. No. 5,939,885 discloses a well logging device comprising a locating element provided with loop antennas and located inside an extender provided with slots. However, the device is not designed to perform logging operations during the tripping cycle. US Pat. Nos. 4,041,780 and 4,047,430 describe a logging tool that is pumped down into the drill string to obtain logs. However, to use the device proposed in the mentioned patents Nos. 4041780 and 4047430, it is necessary to lift the entire drill string from the well (to remove the drill bit) before any logging can be carried out. Therefore, in many cases of drilling operations, the implementation of the described device is not practical and cost effective.

US Pat. No. 5,560,437 describes a telemetry method and apparatus for performing measurements of downhole parameters. Said patent No. 5560437 describes a logging probe that is pushed into the drill string. The logging probe contains a sensor at one end, which is installed in a predetermined position in the hole available in a special drill bit at the end of the drill string. In this case, the sensor directly faces the well. The disadvantage of the device proposed in the aforementioned patent No. 5560437 is that the sensor is not protected from dangerous conditions of the well. In addition, the use of a small sensor protruding through a small hole is not practical when logging electrical resistivity.

US Pat. No. 4,914,637 describes a downhole tool configured to be deployed and lowered into a drill string from the surface to the desired location in the string. The modulator in the tool transmits the collected data to the surface. US Pat. No. 5,050,675 (assigned to this assignee) describes an apertured device comprising a probe with an inductive coupler for transmitting signals between a surface and a downhole tool. US Pat. No. 5,455,573 describes an inductive coupling device for downhole tools with a coaxial arrangement. In addition, methods for researching wells using slit pipes are provided. US Pat. No. 5,372,208 describes the use of sections provided with pipe slots as parts of a drill string to obtain groundwater samples while drilling. However, none of these proposed devices relates to measurements through a pipe or to signal transmission.

The technical result of the present invention is the creation of a simple and reliable device for logging during the tripping cycle and effective methods for detecting and evaluating the properties of potential oil and gas zones in deep formations, methods for transmitting and / or receiving signals through the earth formation, a method for measuring the characteristics of a deep formation with using an advanced device capable of logging during the tripping cycle; logging while drilling or measuring tool is lowered on a cable and methods of sealing the holes in the surface of tubular members used in the drilling operations.

This technical result is achieved in that the device for placing the trigger tool comprises a sub having an elongated body with tubular walls and a central hole, configured to form part of the length of the drill string and containing at least one section having at least one a gap formed in it so that the gap completely passes through the tubular wall to create a continuous channel for the passage of the signal, and means for creating a barrier to pressure between the internal nney side and the outer side of the tubular wall at the at least one slit disposed in the central opening, and a trigger tool, adapted to pass through the drill string and entering the central bore of the sub.

The walls of the elongated body can be made entirely of metal.

The section provided with slots may be made of non-magnetic material.

The means for creating a pressure barrier may include a sleeve located in combination with the slotted section.

The trigger tool may be adapted to be pumped through the drill string or moved on a cable in the drill string.

The trigger tool at one end may include connecting means adapted to remove the trigger tool from the sub opening.

The device may further comprise contact means located between the trigger tool and the wall of the Central hole and adapted to ensure the passage of electric current between the trigger tool and the specified wall when the tool is located in the Central hole.

The trigger tool may contain a permanent magnet.

The trigger tool may include a modulator for remote communication when the trigger is located in the sub.

The trigger tool may include means for storing data.

The trigger tool may comprise at least one antenna adapted to transmit and / or receive electromagnetic energy.

The sub may contain means for placing the trigger tool, configured to position the trigger tool inside the central hole so that at least one antenna of the tool is in alignment with the slotted section in the sub.

The sub can be adapted with the indicated means in the central hole to focus at least one antenna located on the trigger tool when it is located in the sub.

At least one antenna of the trigger tool may be surrounded by a screen having at least one slot formed therein.

The trigger tool may contain at least one cavity formed therein, adapted to accommodate the antenna.

The trigger tool may contain one source of gamma radiation.

The sub may comprise an eccentric means for securing the eccentricity of the trigger tool in the central hole when the trigger tool is located in the sub.

The trigger tool may include at least one gamma radiation detector.

The trigger tool may contain a neutron source.

The invention provides a method for transmitting and / or receiving a signal through an earth formation, in which a well is drilled in an earth formation using a drill string comprising a sub having an elongated body with tubular walls, at least one section having at least one a gap formed in it and completely passing through the tubular wall to create a continuous channel for the passage of the signal, and means for creating a barrier to pressure between the inner side and the outer side of the tubular wall, placed inside the center hole at least one slot, have a trigger tool inside the sub with a means for transmitting signals and / or with a means for receiving signals, place a trigger tool inside the sub so that at least one means for transmitting or receiving signals was combined with at least one section provided with slots in the sub and transmit or receive a signal through the formation, respectively, using means for transmitting signals or means for receiving signals als.

When transmitting or receiving a signal through a formation, it is possible to transmit a signal to another sub of the drill string or receive a signal from another sub of the drill string.

You can use the means for transmitting signals, configured to transmit electromagnetic energy, and the means for receiving signals, configured to receive electromagnetic energy.

It is possible to further establish the connection of the received electromagnetic energy with the specific electrical resistance of the formation.

The location of the trigger tool in the sub can be done when the sub is located on the surface of the formation.

The location of the trigger tool in the sub can be done by moving the trigger tool through the drill string to place it in the sub.

It is possible to further compare the received signal with the position of the sub in the well.

You can optionally telemetry data representing the received signal from a location remote from the sub.

You can optionally store data representing the received signal in a means for storing data in the trigger tool.

It is possible to receive or transmit a signal through the formation when the drill string is removed from the well.

The invention also provides a method for measuring the characteristics of the earth formation surrounding a well, in which a launching tool is used with at least one means for transmitting signals, or with at least one means for receiving signals, with an end means capable of receiving fishing a head or cable connection, place the trigger tool in the sub on the drill string to measure formation characteristics, use means to transmit or receive while passing the drill string with borehole, sub having an elongated body with a Central hole and including at least one slot formed in it, to provide a channel for the passage of the signal, and means for creating a barrier to pressure between the inner side and the outer side of the sub at least one cracks.

The location of the trigger tool in the sub can be done when the sub is located on the surface of the earth to measure formation characteristics during drilling.

It is possible to arrange the launch tool in the sub by moving the tool through the drill string to be placed in the sub to measure formation characteristics when the drill string is removed from the well.

Other features and advantages of the invention will become apparent from the following detailed description with reference to the drawings, in which:

figure 1 depicts a schematic view of a trigger tool according to the invention;

figa - section of the trigger tool according to the invention, while showing the antenna with the corresponding wiring and holes;

fig.2b is a schematic view of a shielding structure according to the invention surrounding the antenna of the trigger tool;

figure 3 is a schematic view of a tubular element provided with slots sections according to the invention;

figa and 4b depict schematic views of the trigger tool according to the invention, engaged inside the tubular element;

5 is a graph illustrating the relationship between the dimensions of the slots of the tubular element and the attenuation of transmitted electromagnetic energy;

6 is a schematic view of the trigger tool according to the invention in arrangement with a centralizer;

figa - section of a tubular element with a barrier to pressure according to the invention;

fig.7b is a section along the line aa in figa of the tubular element with three slots;

figa is a section of a tubular element with another configuration of the pressure barrier according to the invention;

Fig. 8b is a section along the line BB in Fig. 8a of a tubular element with three slots;

Fig. 9a is a sectional view of a trigger tool located in combination with a pressure barrier according to the invention;

fig.9b is a top view of the trigger tool and the pressure barrier shown in figa;

10 is a sectional view of a pressure barrier and a tubular member according to the invention;

11 is a sectional view of a tubular element provided with a slit with an insert, a seal and a locking sleeve according to the invention;

figa and 12b depict cuts and local cuts provided with a slit of the tubular section according to the invention with a conical slot and with a corresponding conical insert;

figa depicts a schematic view of a trigger tool and offset from the center of the antenna inside the tubular element according to the invention;

13b and 13c are schematic views of a trigger tool and an antenna surrounded by a focusing screen according to the invention, wherein the screening effect of magnetic and electric fields is shown;

Fig.14 depicts a top view of the shielding structure according to the invention, formed inside the hole of the tubular element;

Fig - schematic view of a shielding structure according to the invention, formed by a cavity inside the trigger tool;

FIG. 16 is a schematic view of a trigger tool according to the invention, including a modulator, and engaged inside a tubular member; FIG.

Fig is a schematic view of the layout of the trigger tool shown in Fig used for real-time radio communication with a remote downhole tool;

Fig. 18 is a schematic view of an arrangement of a trigger tool according to the invention for measuring porosity using nuclear magnetic resonance methods;

figa and 19b depict schematic views of the layouts of the antennas of the trigger tool according to the invention inside the tubular elements;

Fig.20 depicts schematic views of a tubular element and a trigger tool with inductive coupling elements according to the invention;

21 is a top view and a schematic view of a trigger tool and a tubular element with inductive coupling elements offset from the center according to the invention;

figa and 22b depict schematic views of inductive coupling elements according to the invention inside the trigger tool and the tubular element;

Fig. 23 is a sectional view of an inductive coupling element and a shield according to the invention mounted in a tubular element;

24 is a simplified diagram of an inductive coupler according to the invention;

25 is a flowchart illustrating a method according to the invention for transmitting and / or receiving a signal through an earth formation;

FIG. 26 is a flowchart illustrating a method according to the invention for measuring the characteristics of an earth formation surrounding a well; FIG.

Fig. 27 is a flowchart illustrating a method according to the invention for sealing a hole in a surface of a tubular member; and

28 is a flowchart illustrating a method according to the invention for sealing a through hole in a surface of a tubular member.

In the interest of clarity, not all features of embodiments of the present invention are discussed in this description of the invention. It should be noted that, although the development of any such embodiment may be complex and time-consuming, it is nonetheless a routine for the ordinary person skilled in the art to which this invention relates, benefiting from this disclosure.

The device according to the invention consists of two main parts, a trigger tool and an extension cord. Further, the extension cord will be called a sub.

1. Trigger tool

Figure 1 shows an embodiment of a trigger tool 10 according to the invention. The trigger tool 10 is an elongated metal mandrel of small diameter, in which you can place one or more antennas 12, sources, sensors (the terms sensor and detector are used interchangeably), magnets, a generator and gamma-ray detector assembly, a neutron generation and detection unit , various electronics, batteries, a downhole processor, a frequency generator, an output and read port, and a recording memory (not shown).

The trigger tool 10 does not have such mechanical requirements as the sub. Therefore, significantly lower mechanical restrictions are imposed on it. The trigger tool 10 has a landing gear (shank) 14 at the lower end and a fishing head 16 at the upper end. The fishing head 16 allows you to grab the trigger tool 10 and remove from the sub when using a known extraction tool, such as described in US patent No. 5278550 (assigned to this assignee). The advantage of the retrievable trigger tool 10 is to reduce the cost of the tools left in the well.

As shown in FIG. 2 a, each antenna 12 of the trigger tool 10 consists of a multi-turn wire frame placed in an epoxy composition 18 with fiberglass, located in the groove of the tight housing of the trigger tool 10 and sealed with pressed rubber material 20. The input 22 provides a passage for wiring the antenna 12 and goes into the inner hole 24 in the trigger tool 10. As is known from the technical field to which the invention relates, each antenna 12 can operate to receive or transmit electromagnetic system drove.

Antenna 12 emits an electric field in the azimuthal plane. Preferably, each antenna 12 is surrounded by a stainless steel shield 26 (similar to that described in US Pat. No. 4,949,045 assigned to this assignee), which has one or more axial slots 28 located around the circumference of the screen 26. FIG. 2b shows axial slots 28 distributed around the circumference of the screen 26. A short circuit of the screens 26 is carried out at the axial ends of the metal mandrel of the trigger tool 10. These screens 26 provide the possibility of the propagation of transverse electrical radiation and at the same time bl transverse magnetic and transverse electromagnetic radiation. In addition, shields 26 protect the antennas 12 from damage from the outside. The electronics and layout of the triggers of the trigger tool 10 are similar to those described in US Pat. No. 4,899,112 (assigned to this assignee).

2. Sub

Figure 3 shows an embodiment of a sub 30 according to the invention. The sub 30 has an elongated body with tubular walls and a central hole 32. The sub 30 does not contain any electronics or sensors and is completely metal, preferably made of stainless steel. It is part of the normal layout of the bottom of the drill string and during operation the bit is located in the drill string located in the well. Sub 30 has conventional threaded oilfield connections (male and female) at each end (not shown).

The sub 30 comprises one or more sections 36 with one or more axial slots 38 located throughout the tubular wall. Each elongated axial slot 38 extends completely through the tubular wall of the sub 30 and is preferably made with well-rounded ends. Stress modeling showed that rather long slots 38 can be formed in the walls of the sub 30 while maintaining the structural integrity of the sub 30. To minimize the bending moment acting on the slit (s) 38, voltage reducing grooves 40 can be made on the outer surface of the sub 30.

Each slit 38 forms a continuous channel for the passage of electromagnetic energy through the sub 30. The slots 38 block the transverse magnetic radiation, but allow the transverse electric radiation to pass, although with some weakening. The degree of attenuation by the transformer 30 of transverse electric fields depends on factors such as frequency, number of slots, slit widths, slit lengths, outer diameter and inner diameter of the sub, as well as the location and dimensions of the trigger antenna 10. For example, FIG. 5 shows the attenuation, introduced by the sub 30, measured at a frequency of 400 kHz, in the case of a 25-turn frame with a diameter of 44.45 mm, centered in the sub 30 with an inner diameter of 90.17 mm and an outer diameter of 171.45 mm, having one or two slots 38 of different lengths and width. As is clear from FIG. 5, adding slots 38 or making slits longer or wider reduces attenuation. However, in the case of only one or two slots 38, 12.7 mm wide and 152.4-203.2 mm long, the attenuation introduced by the sub 30 is only about 15 dB, which is sufficiently small for many applications.

During operation, the trigger tool 10 is pumped down and / or lowered along the drill string on the cable when the bit is finished and engaged inside the sub 30. As shown in FIG. 4a, the trigger tool 10 is received by the trigger shoe 42 inside the center hole 32 of the sub 30 Fig. 4b shows the location of the trigger tool 10 in the sub 30, in which each antenna 12, source or sensor is in alignment with the slot 38 in the sub 30. Preferably, the trigger shoe 42 also has a locking action e to prevent any axial movement of the tool trigger 10 after its engagement within the top sub 30.

6 shows an embodiment of the invention, including a centralizer 44, which serves to keep the trigger tool 10 centered and stable inside the sub 30, mitigate impacts and reduce the impact of the movement of the tool 10 on the measurements. To limit the movement of the trigger tool 10 and protect it from impacts on the inner wall of the sub 30, one or more centralizers 44 can be placed in the central hole 32. In addition, to ensure the stability of the position of the trigger tool 10, one or more spring leaves 46 can be installed extending from the centralizer 44. Spring leaves 46 are pressed to the trigger tool 10 when it is engaged inside the sub 30. To hold the centralizer (s) 44 in the sub 30, you can use more LT 48 with O-rings 50 while maintaining a barrier to pressure between the inner side and the outer side of the sub 30.

Alternatively, the centralizer 44 can be installed on the trigger tool 10, and not on the sub 30 (Fig.16). In this case, the centralizer 44 can be shaped so that it is retracted during the descent and opens when the trigger 10 is lowered into the sub 30. It will be appreciated that the centralizer 44 of other configurations known in the art to the invention can be used. .

The trigger tool 10 and sub 30 have electromagnetic properties similar to those of a coaxial cable, with the trigger tool 10 functioning as an inner conductor and the sub 30 functioning as an outer conductor of a coaxial cable. When using conductive drilling fluid, the coaxial cable introduces losses. When using a hydrocarbon-based drilling fluid, the coaxial cable has a slight attenuation. Within the sub 30 between the receiver and the receiver or transmitter and the receiver, parasitic coupling of antennas 12 may exist. As described above, the screens 26 surrounding the antennas 12 are grounded on the mandrel of the trigger tool 10 to minimize capacitive coupling between them or transverse electromagnetic radiation coupling. In addition, to weaken the coupling of the transverse electromagnetic radiation, electrical symmetry of the antennas 12 is provided. Centralizers 44 can also be used as contact means for forming high-frequency short-circuited circuits between the trigger tool 10 and the sub 30 to prevent stray communication. For example, to ensure a reliable short circuit between the trigger tool 10 and the sub 30, small gears with sharp teeth (not shown) can be mounted on the centralizers 44.

4.3. Pressure barrier

Since each slit 38 passes completely through the wall of the sub 30, a pressure barrier is used to maintain the differential pressure between the inner side and the outer side of the sub 30 and hydraulic integrity. There are various ways to create a pressure barrier between the inner side and the outer side of the sub 30 in the case of using slit sections 36.

Fig. 7a shows an embodiment of a pressure barrier sub 30 according to the invention. Inside the center hole 32 of the sub 30, a cylindrical sleeve 52 is mounted in a position aligned with the slot (s) 38. The sleeve 52 is made of a material that is transparent to electromagnetic energy. Suitable materials include the class of polyether ketones described in US Pat. No. 4,320,224, or other suitable polymers. One such material, called polyether etherketone, is manufactured by Victrex USA, Inc. from West Chester, PA. Cytec Fiberite, Greene Tweed, and BASF offer other suitable thermoplastic polymers. Another suitable material for use is the tetragonal phase of zirconia ceramics manufactured by Coors Ceramics of Golden, Colorado. Those skilled in the art to which the invention relates should understand that these and other materials can be combined to produce a suitable sleeve 52 for use.

Polyetherketone and polyether etherket can withstand significant pressure loads and can be used in harsh well conditions. Ceramics can withstand significantly greater loads, but they are not particularly resistant to impact. To increase the strength of sleeve 52, mixtures of polyether ether ketone or polyether ketone and glass, carbon or Kevlar can also be used.

In addition, a stopper 52 and a spacer 56 are introduced into the central hole 32 to support the sleeve 52, and they are designed to move and align it with the slots 38. The sleeve 52 is located between the stopper 54 and the spacer 56, which are made in the form of hollow cylinders mounted on one axis in the Central hole 32. Preferably, both parts are made of stainless steel. At one end, the stopper 54 is connected to the sleeve 52, and the sleeve 52 is mounted coaxially inside the stopper 54. When the pressure drop across the sub 30 increases during operation, the sleeve 52 takes up the load, isolating the sub 30 from the pressure in the gap region. The hydraulic integrity at the junction between the sleeve 52 and the stopper 54 is supported by a sealing ring 53. A seat “key” 55 is used to engage the sleeve 52 with the stopper 54 and prevents one part from turning relative to another (see the enlarged image in FIGS. 7a-1). The locking pin 57 passes through the sub 30 and is engaged with the free end of the stop 54 to prevent the stop in the opening 32 of the sub 30. In order to form a hydraulic seal between the stop 54 and the sub 30 in the grooves on the outer surface of the stop 54, o-rings are placed 59.

During operation, the inner sleeve 52 will likely experience axial thermal expansion due to high temperatures in the well. Therefore, it is preferable that the sleeve 52 can move in the axial direction when it experiences such changes in order to prevent curvature. The spacer 56 consists of an inner cylinder 60 inside the outer cylinder 62. A spring 64 at one end of the outer surface of the inner cylinder 60 creates an axial force that counteracts the outer cylinder 62 (similar to a car shock absorber). The outer cylinder 62 is connected to the sleeve 52 using a key 55 and an o-ring 53 at the junction described above and shown in an enlarged view of part of FIG. 7a (FIG. 7a-1). The spring strut 56 is important for unequal thermal expansion of parts. In the embodiment of FIG. 7a, a sub 30 is shown connected to other tubular parts by threaded oilfield connections 70.

For the purpose of illustration, in Fig. 7a, the sub 30 is shown with only one slot 38. In other embodiments, there may be several bushings 52 connected to other parts in the described manner to form individual pressure barriers over a number of slit sections 36 (not shown) ) In the case of such an arrangement, only two o-rings 53 are used on the inside of the sub 30 throughout the section with a gap structure. This minimizes the danger of slipping the o-rings 53 in the gap during assembly or repair. Fig. 7b shows a sectional view (along line AA in Fig. 7a) of the sub 30 in a configuration with three slots 38.

On figa shows another embodiment of a sub 30 with a barrier to pressure according to the invention. In this embodiment, the spring-loaded strut 56 supports the outer cylinder 62 adjacent to the sleeve 52, and the o-rings 68 are located in grooves on the outer surface of the sleeve 52, preferably on both sides of the slot 38. At one end, the stopper 54 is supported on the shoulder or protrusion 58, formed on the wall of the Central hole 32. On fig.8b shows a sectional view (along line BB in figa) sub 30 in the configuration with three slots 38.

In yet another embodiment of the pressure barrier according to the invention, a sleeve 52 made of polyetheretherketone or polyetherketone, or from a modification of these materials with glass, carbon or Kevlar as a filler, can be bonded to a metal insert (not shown), the insert containing sealing rings for sealing the sub 30, as described above. The metal insert may be installed inside the sub 30 as described above, or using fastening means or locking pins (not shown). The material of the sleeve can also be pressed or wound onto a carrier insert. In addition, to obtain additional strength, the fibers in the wound material can be oriented accordingly.

Fig. 9a shows another embodiment of a pressure barrier according to the invention. In this embodiment, the cylindrical sleeve 52 is held in alignment with the slot (s) 38 by the metal stopper 72. As shown, the stopper 72 can be made together with the corresponding slot 74 formed therein for signal transmission, or as separate parts (not shown) supporting sleeve 52 at the top and bottom. The axial movement or rotation of the stopper 72 within the sub 30 may be limited by any of several means known in the technical field to which the invention relates, including a locking pin mechanism or key device with a locking nut (not shown). In addition, as will be further described below, the slot 38 may be covered by a protective insert. During operation, the trigger tool 10 is located inside the sub 30 so that the antenna 12 is aligned with the slot (s) 38.

As shown in FIG. 9b, the stopper 72 is configured so that it extends inward and reduces the inner diameter of the sub 30 to limit the movement of the trigger tool 10. The mud flows through several channels or holes 76 in the stopper 72 and through an annular gap 78 between the trigger the tool 10 and the stopper 72. The stopper 72 actually acts as a centralizer to stabilize the trigger tool 10 and protect it from impact on the inner surface of the sub 30, reduce the intensity of the blows and increase reliability.

Figure 10 shows another embodiment of a pressure barrier according to the invention. The sub 30 is made with a factory connection 80 such that the sleeve 52 can be inserted inside the central hole 32. The sleeve 52 is made as described above and is provided with a hydraulic seal using o-rings 82 in grooves made on the outer surface of both ends of the sleeve 52. Axial the movement of the sleeve 52 inside the central hole 32 is limited by the stop protrusion 84 formed at one end of the two-component sub 30 and the end of the matched connection of the sub 30. Since the sleeve 52 is recessed into groove 86, made on the inner surface of the sub 30, this arrangement provides free passage of the trigger tool 10 of large diameter. In addition, this arrangement provides easy access to the sleeve 52 and to the slot (s) 38 for maintenance and inspection.

11 shows yet another embodiment of a pressure barrier according to the invention. The slot 38 in the sub 30 is three-stage, preferably with well-rounded ends. One of the steps has a support shoulder 90 for insert 92, and two other surfaces together with insert 92 form the configuration of groove 94 for the o-ring. The modified sealing ring consists of the sealing ring 96 itself, tensioned around the insert 92 at the corresponding step, and metal elements 98 located on opposite sides of the ring 96. Preferably, the metal elements are made in the form of closed loops.

As described above, the sleeve 52 can be installed inside the sub 30 together with one or more o-rings (not shown). As shown in FIG. 11, the sleeve 52 may also have a slot 100 extending through its wall to form a free channel for any incoming or outgoing signal. The sleeve 52 may have a corresponding slot 100 for each slot 38 in the sub 30.

In order to allow electromagnetic energy to pass through, the insert 92 and the sleeve 52 are desirably made from the dielectric materials described above. However, if the sleeve 52 is formed with a slit 100, the sleeve 52 can be made of any suitable material.

If the sleeve 52 is formed with a slit 100, the internal pressure in the sub 30 may push the insert 92 out. The supporting shoulder 90 accepts this load. As the internal pressure rises, the o-ring 96 advances the metal elements 98 against an extruded gap that effectively covers the gap. As a result, the space for extruding the o-ring 96 disappears. Since the metal is much harder than the material of the o-ring, it is not extruded at all. Therefore, the modified configuration helps to create a situation in which a soft element (O-ring) provides a seal, and a solid element (metal loop) prevents extrusion, i.e. there is a case of perfect compaction. In the event of a change in pressure direction, the sleeve 52 captures the insert 92 in the slots 38, preventing the insert 92 from being forced out.

Using the invention, other pressure barrier configurations can be implemented. One way is to use several separate bushings 52 connected to each other by other retaining structures and limited in movement by a differential pressure seal or device with a lock nut (not shown). Another method is to use an extended sleeve 52 (not shown) that spans several sections 36. Another method is to use a sleeve 52 attached to the outer surface of the sub 30 throughout the slit region, or to use a combination (not shown) of the internal sleeve and outer sleeve 52.

4. Inserts for crevices

Although slit sections are effective in fully open or non-blocking slots 38, the service life of the assembly can be improved by preventing penetration of gangue and fluids and erosion of slots 38 and insulating sleeve 52. To trap gangue and fluids from the outside and allow signals to pass through, slots 38 can be filled with rubber, epoxy with fiberglass or other suitable filler.

An embodiment of a sub 30 with a conical slit 38 is shown in FIG. 12a. As shown in FIG. 12b, the slit 38 is narrowed so that the outer window W ₁ is narrower than the inner window W ₂ . A wedge 88 of insulating material (for example, of an epoxy composition with fiberglass) is inserted into the conical slit 38. The wedge 88 may be secured to the sub with rubber. A layer of rubber surrounds the wedge 88 and secures it to the sub 30. In addition, the annular rubber layer can be pressed onto the inner and / or external surface of the sub 30 to seal the wedge 88 into the slit 38.

5. Designs of focusing screens

Measurements of the attenuation of the transverse electric radiation of a simple loop antenna 12, which passed through one slot 38 of sufficient size, showed that the transverse electric field is noticeably attenuated. However, this attenuation can be reduced by using a screen around the antenna 12 to focus the electromagnetic field into the slit 38.

On figa shows the antenna 12, consisting of 25 turns of wire on a coil with a diameter of 44.45 mm, mounted on a metal trigger tool 10 with a diameter of 25.4 mm, while it is located with a radial offset from the center inside the hole of the sub 30 with an inner diameter of 90 , 17 mm and an outer diameter of 171.45 mm, opposite the slit 38, and is centered vertically relative to the slit 38. The measured attenuation of the transverse electric field in the frequency range from 25 kHz to 2 MHz was almost constant and amounted to 16.5 dB.

As shown in FIG. 13b, the antenna 12 is located inside a thin screen 102 formed of a metal tube with a slit 104 of a width of 12.7 mm and a length of 152.4 mm aligned with the slit 38 in a sub 30 (not shown); for this case the same measurements were made. The antenna 12 was completely surrounded by a screen 102, excluding the open slot 104, and placed inside the sub 30.

The attenuation for this node in the same sub 30 was 11.8 dB, a decrease in attenuation of about 5 dB. 13b and 13c respectively show how the screen 102 affects the magnetic and electric fields. The attenuation introduced by the screen 102 itself is minimal.

On Fig shows another embodiment of the shielding design of the invention. In this embodiment, a cylindrical element 106 is inserted into the center hole 32 of the sub 30, which acts as a focusing screen surrounding the antenna 12 when the trigger 10 is engaged inside the sub 30.

On Fig shows another embodiment of the shielding design of the invention. The mandrel 10 has a machined pocket or cavity 108. A frame antenna 12 wound on a coil 110 made of dielectric material is mounted inside the cavity 108. The dielectric coil can be replaced with a ferrite core. With this configuration, the very body of the trigger tool 10 serves as a focusing screen. The hydraulic integrity of the trigger tool 10 is maintained by coating the antenna 12 with an epoxy composition with fiberglass, rubber, or other suitable material. The attenuation of the radiation of the loop antenna 12, having 200 turns on a coil with a diameter of 22.225 mm, was measured for this node, which was installed in the same sub 30 as described above. The measured attenuation was only about 7 dB. Specialists in the technical field to which the invention relates, it should be clear that in the cavity 108 of the trigger tool 10, you can place sources and sensors of other types.

6. Trigger / sub assembly

On Fig shows another embodiment of the invention. The sub 30 of the invention is connected to another tubular member 111 forming a drill string section. The trigger tool 10 includes an antenna 12, a shank 14 at the lower end and a fishing head 16 at the upper end. The shank 14 is placed in the trigger shoe 42 in the sub 30, which is used to combine the antenna 12 with the slotted section 36. As before, the trigger tool 10 contains various electronics, batteries, a downhole processor, a frequency generator, an output and read port, a storage device etc. (not shown) in a sealed enclosure. In addition, the trigger tool 10 may contain sources and sensors of various types, known from the technical field to which the invention relates.

6.1. Trigger tool with modulator

The trigger tool shown in FIG. 16 is also provided with a modulator 116 for transmitting a signal to the surface. As is known from the technical field to which the invention relates, a usable modulator 116 consists of a rotary valve that operates with a continuous longitudinal pressure wave in the mud column. By changing the phase of the signal (frequency modulation) and subsequently detecting these changes, a signal can be transmitted between the surface and the trigger tool 10. In this arrangement, the trigger tool 10 can be directed along the drill string to obtain measurement data (for example, electrical resistivity or gamma radiation level) related to the characteristics of the formation, and for transmitting such data to the surface in real time. Alternatively, all or some of the measurement data may be stored in the memory of the trigger tool 10 located in the well for subsequent sampling. In addition, the modulator 116 can be used to verify the correct location of the trigger tool 10 in the sub 30 and to control the measurement process. Those skilled in the art to which the invention relates should understand that modulator assembly 116 can be included in all embodiments of the trigger tool / sub according to the invention.

On Fig shows another embodiment of the invention. The sub 30 and triggers 10 according to the invention can be used to transfer data and / or instructions between the surface and the remote tool 112 located along the drill string. For purposes of illustration, tool 112 is shown with a drill bit box 113 at the bottom of drive shaft 114. Drive shaft 114 is connected to drilling rig motor 115 via an internal gear (not shown) and bearing section 117. In addition, tool 112 has an antenna 12 mounted on box 113 of the drill bit. The motor 115 rotates a shaft 114, which rotates the bit box 113, therefore, while drilling, the antenna 12 rotates.

In the arrangement of FIG. 17, the trigger tool 10 may be engaged inside the sub 30 on the surface or sent along the drill string when the sub 30 is in the well in the right place. After engagement, a radio link can be established between the antenna 12 of the trigger tool 10 and the antenna 12 in the tool 112, the signal passing through the slotted section 36. In this way, a real-time radio link can be established between the surface and the downhole tool 112. Those skilled in the art to which the invention relates, it should be understood that sensors and / or transmitting and receiving signals of other types of devices can be installed on remote instruments 112 of various types for communication with appropriate devices installed on the tool trigger 10.

6.2. Nuclear magnetic resonance detection

It is known that when a set of magnetic moments, such as hydrogen nuclei, is exposed to a static magnetic field, there is a tendency to orient them in the direction of the magnetic field, which leads to volume magnetization. By measuring the time required to rearrange the spin axes of the hydrogen nuclei, a quick non-destructive assessment of the porosity, characteristics of the moving fluid and the permeability of terrestrial formations is carried out. See: Timur A., Pulsed nuclear magnetic resonance studies of porosity, movable fluid, and permeability of sandstones; Journal of Petroleum Technology, June 1969, p. 775. US Pat. No. 4,717,876 describes a downhole nuclear magnetic resonance logging tool in which these methods are used.

The formation porosity can be determined from magnetic resonance data using a non-magnetic sub 30 shown in FIG. 18. The sub 30 may be made of ordinary high strength non-magnetic steel used in industry. As described above, the trigger tool 10 contains electronics, batteries, a central processor, a storage device, etc. Opposite permanent magnets 118 located in the trigger tool 10 create a magnetic field. A high frequency inductor 120 is mounted between the magnets 118 to form a magnetic field in the same region to excite nuclei in the vicinity of the formation. The design of the high-frequency inductor 120 is similar to that of the antenna 12 described above as a multi-turn loop antenna with a central tube for winding the wire and increasing mechanical strength. Preferably, the permanent magnets 118 and the high-frequency inductor 120 are located in the non-magnetic part of the sub 30, which has axial slots 38 with a pressure barrier (not shown) according to the invention.

In the case of a non-magnetic sub 30, a static magnetic field B _{0 of} permanent magnets 118 penetrates into the surrounding formation and excites nuclei in the surrounding formation. The inductor 120 in the trigger tool 10 creates a high-frequency magnetic field B ₁ that is perpendicular to B ₀ from the outside of the sub 30. The high-frequency inductor 120 is in alignment with the axial slit (s) 38 of the sub 30.

Magnetic resonance measurements during the hoisting cycle can be more complicated compared to propagating electrical resistivity measurements due to various factors, including the nature of the lower signal-to-noise ratio, permanent magnet shape factors, high-frequency inductor efficiency, high-quality antenna tuning, high electricity demand and lower logging speed.

6.3. Gamma radiation measurement

It is known that measurements of the passage of gamma radiation through a formation can be used to determine its characteristics, such as density. The interaction of gamma radiation in Compton scattering depends only on the particle density of scattering electrons. In turn, it is proportional to the bulk density of the formation. Known logging tools use detectors and a gamma radiation source, and the main mode of interaction is Compton scattering (see US Pat. No. 5,250,806, assigned to this assignee). In addition, measurements of formation characteristics based on gamma radiation are implemented in logging technology during the tripping cycle (see Logging while tripping cuts time to run gamma rays. Oil & Gas Journal, June 1996, pp. 65-66). The present invention can be used to carry out measurements based on gamma radiation, known from the technical field to which the invention relates, while it provides advantages in comparison with known methods of implementation.

The sub 30 of the invention has the structural integrity necessary to perform drilling operations, and also provides a low density channel for the passage of gamma radiation. 4b, this arrangement is shown to illustrate the implementation according to the invention of measurements based on gamma radiation. In this embodiment, the trigger tool 10 is provided with a gamma radiation source and gamma radiation detectors (not shown), known in the art to which the invention relates, and described in US Pat. No. 5,250,806. Antennas 12 in FIG. 4b should be replaced by a gamma radiation source and gamma radiation detectors (not shown).

In measurements of this type, two gamma radiation detectors are usually used. As is customary in the technical field to which the invention relates, gamma-ray detectors are placed on the trigger tool 10 at appropriate distances from the source. The slit sections 36 are also arranged appropriately to align with the positions of the source and detectors of the trigger tool 10. In measurements, calibration may be necessary to account for the rays propagating along the inner surface of the sub 30. As is known from the technical field of the invention, gamma radiation detectors can also be appropriately placed inside the trigger tool 10 to shield them from direct radiation from the source.

On Fig for illustration shows the layout of another variant embodiment of the invention using gamma radiation. In the case of a trigger tool 10 provided with the described assembly for measuring gamma radiation and eccentric with respect to slots 38, scattered gamma radiation will be more effectively captured in this arrangement and transmission losses will be reduced.

6.4. Electrical resistivity measurement

The invention can be used to measure the electrical resistivity of a formation using methods based on the propagation of electromagnetic waves that are known from the technical field to which the invention relates, including those described in US Pat. Nos. 5,594,343 and 4,899,112 (both assigned to this assignee). On figa and 19b shows two layouts of the trigger tool 10 / sub 30 according to the invention. A pair of centrally located R _x receive antennas is used to measure the phase shift and attenuation of electromagnetic waves. To determine the electrical resistivity by phase shift and electrical resistivity by attenuation, you can use the table of correspondence. The transmitting antennas T _x are located above and below the receiving antennas R _x , either in the arrangement shown in FIG. 19a, where there are two symmetrically arranged transmitting antennas T _x , or in the arrangement shown in FIG. 19b, where there are several transmitting antennas T _x above and below the receiving antennas R _x . The arrangement of FIG. 19a can be used to perform downhole measurements of resistivity by phase shift and attenuation with compensation for well parameters, while several spaced apart antennas T _x of FIG. 19b allow downhole measurements of phase shift and attenuation with compensation of well parameters at various depths research. Those skilled in the art to which the invention relates should understand that other arrangements of sources and sensors and algorithms or models can be used to study the formation and determine the characteristics of the formation.

7. Inductively coupled trigger tool and sub

On Fig shows other embodiments of the sub 30 and the trigger tool 10 according to the invention. The sub 30 contains one or more integrated antennas 12 for transmitting and / or receiving electromagnetic energy located on the outer surface of the elongated body. As described above, the antennas 12 are placed in an epoxy composition with fiberglass with rubber pressed over. In addition, the sub 30 has one or more inductive coupling elements 122 distributed over the tubular wall.

The trigger tool 10 has a sealed housing of small diameter, such as described above, which contains electronics, batteries, a downhole processor, a frequency generator, an output and read port, a recording memory device, etc., as well as one or more inductive elements 122 ties located along his body.

As shown in FIG. 21, the trigger tool 10 inside the sub 30 is offset from the center so that the inductive coupling element (s) 122 in the trigger tool 10 and the inductive coupling element (s) 122 in the sub 30 are in close proximity. As is known from the technical field to which the invention relates, coupling elements 122 consist of windings formed around ferrite cores. Inputs 124 connect the wires of the antenna 12 to the inductive coupling element 122 located in a small recess 126 in the sub 30. A metal screen 128 with vertical slots covers each antenna 12 to protect it from mechanical damage and, as previously described, provides the necessary electromagnetic filtering. Proper placement of the trigger tool 10 inside the sub 30 increases the effectiveness of inductive coupling. To shift the trigger tool 10 inside the sub 30 from the center, the positioning is carried out using the shank and trigger shoe (figa). Those skilled in the art to which the invention relates should understand that other off-center devices can be used to implement the invention.

As shown in FIG. 22 a, inductive coupling elements 122 have U-shaped cores made of ferrite. The ferrite core and the windings are enclosed in an epoxy composition with fiberglass over which rubber 131 is pressed and installed in a housing 130 of a communication element made of metal. The housing 130 of the communication element may be made of stainless steel or non-magnetic metal. Conventional o-rings 132 located around the housing 130 of the inductive coupler provide a hydraulic seal. Inductive coupling elements 122 in the trigger tool 10 can also be enclosed in an epoxy composition with fiberglass and rubber pressed on top of it 131. In addition, a thin cylindrical screen (not shown) made of polyetheretherketone or polyetherketone can be placed on the outer surface of the sub 30 for protection and safety of the housing 130 of the communication element.

During operation, there will be a gap between the inductive coupling elements 122 in the trigger tool 10 and in the sub 30, so that the coupling efficiency does not reach 100%. To increase the coupling efficiency and reduce the effects of pole mismatch, it is desirable that the surface area of the poles be as large as possible.

On fig.22b shows the gap 38 in the sub 30 with a length of 92.25 mm and a width of 25.4 mm The pole surface for this inductive coupling element 122 has a length of 27.94 mm and a width of 19.05 mm, providing an overlap area of 532.257 mm ² . This arrangement maintains high coupling efficiency and reduces the effects of moving the trigger tool 10 during drilling or tripping, changing the clearance between the inductive coupling elements 122 and changing the angular position of the trigger tool 10 relative to the sub 30. Another advantage of the long slot 38 is that it provides space for sealed bushings 124 in the housing 130 of the inductive coupling element.

In addition, if necessary, antenna tuning elements (capacitors) can be placed in this housing 130. Those skilled in the art to which the invention relates should understand that, in order to obtain the desired inductive coupling, holes of other configurations, such as circular holes shown in FIG. 20, may be formed in the walls of the sub 30.

Since in most cases the pressure inside the sub 30 will be 6.89476-13.78952 MPa higher than on the outside of the sub 30, the housing 130 of the inductive coupler must be mechanically held in place. On Fig shown that the screen 128 of the antenna can be used to hold in place the housing 130 of the inductive coupling element. As described above, the screen 128 has slots along the antenna 12, but in other places is made continuous. The solid part holds the housing 130 of the inductive coupling element and accepts the load in the event of a drop in pressure drop. In addition, paws (not shown) can be placed on the outer surface of the housing 130 of the inductive coupler to keep the housing from moving inward. On the inner surface of the screen 128 can also be threaded, while the threads will be engaged with the mating "teeth" (not shown) on the sub 30.

24 shows a simple equivalent circuit for an embodiment of an inductive coupler and transmit antenna according to the invention. On the side of the trigger tool 10, the current is I ₁ and the voltage is V ₁ . On the side of sub 30, the current is I ₂ and the voltage is V ₂ . The mutual inductance is equal to M, and the intrinsic inductance of each half is L. For the same number of turns in each half, this inductive coupling element is symmetrical. With the current direction I ₂ indicated in FIG. 24, the voltages and currents are related by the relations V ₁ = jωLI ₁ + jωMI ₂ and V ₂ = jωMI ₁ + jωLI ₂ . The antenna impedance is mainly inductive (L _A ) with a small resistive part (R _A ), with z _a = r _a + JωL _A. Typically, the inductive impedance is approximately 100 ohms, while the resistive impedance is approximately 10 ohms. To eliminate the inductance of the antenna, you can use a tuning capacitor (C), which creates an impedance on the side of the trigger tool Z ₂ = R _A + jωL _A -j / ωc ~ R _A. The ratio of the current supplied to the antenna to the current exciting the inductive coupling element, I ₂ / I ₁ = -jωM / (jωL + R _A + jωL _A -j / ωC). The inductive coupling element has many turns and a core with high magnetic permeability, so that L≫L _A and ωL≫> R _A. With a good approximation, I ₂ / I ₁ = ~ -M / L (the sign refers to the direction of current flow in Fig.24).

8. The implementation of the invention

As described above, the trigger tool 10 may be provided with means for storing data, for example, a conventional storage device and other means well known in the technical field to which the invention relates, or those that can be developed subsequently. These storage means can be used to transfer data and / or instructions between the surface and the downhole tool 10. The received signal data can be stored in the storage tool located in the well and subsequently read when the tool 10 is returned to the surface. As is known in the technical field to which the invention relates, time tracking data are stored on a surface in a computer (or other recording means) depending on the position of the sub in the well, so that stored data can be compared with the location of the sub in the well. Alternatively, as is known in the art to which the invention relates, data and / or instructions can be transmitted in real time between the surface and the trigger tool 10 using the telemetry method of transmitting logging / measurement data while drilling.

25 is a flowchart of a method 300 for transmitting and / or receiving signals through an earth formation in accordance with the invention. The method comprises the following stages: drilling a 305 well through the earth formation with a drill string containing a sub having an elongated body with tubular walls and at least one section having at least one slot made in it and completely passing through the tubular wall for the formation of a continuous channel necessary for the passage of electromagnetic energy, the engagement 310 inside the sub trigger tool, made with means for transmitting signals and / or receiving signals, the placement 315 trigger instrument within the sub in such a way that at least one means for transmitting or receiving signals is combined with at least one slotted section in the sub, and transmitting or receiving 320 signals through the formation, respectively, using means for transmitting or receiving .

On Fig shows a sequence diagram of the stages of the method 400 for measuring the characteristics of the earth formation surrounding the well, in accordance with the invention. The method comprises the following stages: using 405 downhole tools with at least one means for transmitting signals and with at least one means for receiving signals, using 410 downhole tools with end means capable of receiving a fishing head or cable connection, with using the fishing head on the tool, meshing 415 of the tool inside the drill string to measure formation characteristics using means for transmitting and receiving as the drill string passes with Vazhiny by cable connection on the tool attachment of a cable to the tool and suspending the tool within the borehole 420 to measure characteristics of the formation using the means for transmission and reception.

The method 400 shown in FIG. 26 may be implemented by a trigger tool 10 and sub 30 according to the invention. The trigger tool can be made with an end segment or a cover (not shown) to accommodate the previously described fishing head or cable connection. Together with the fishing head attached to the trigger tool, the tool can be used according to the disclosed embodiments. Together with the cable connection, the trigger tool can be used as a tool that is lowered into the well to a predetermined depth on a cable.

It should be understood that the following methods for sealing a hole or slot in the surface of a tubular member are based on open pressure barriers and slot inserts according to the invention.

On Fig shows a sequence diagram of the stages of the method 500 for sealing a hole in the surface of a tubular element having an elongated body with tubular walls and a Central hole. The method comprises the following steps: placing 505 in an opening of an insert having the shape of an opening, and applying 510 binder material to the insert and / or into the hole to engage the insert in the hole.

On Fig shows a sequence diagram of the stages of the method 600 for sealing a through hole in the surface of a tubular element having an elongated body with tubular walls and a Central hole. The method comprises the following steps: placing 605 in an opening of an insert having the shape of an opening, and placing 610 locking means in a tubular member to support the insert opposite the opening.

Although the methods and devices of this invention have been described as specific embodiments, it will be understood by those skilled in the art to which, without departing from the idea and scope of the invention, in the construction and in the step or sequence of steps of the methods described herein may be subject to change. For example, the invention may be implemented in an arrangement in which one trigger / sub assembly is provided with means for measuring a set of formation characteristics, including electrical resistivity, porosity, and density. Specialists in the field of technology to which the invention relates, it is understood that all such such changes are considered to be within the scope of the idea and scope of the invention defined by the attached claims.

Claims (32)

1. A device for placing a trigger tool, comprising a sub having an elongated body with tubular walls and a central hole, configured to form part of the length of the drill string and containing at least one section having at least one slot formed in so that the gap completely passes through the tubular wall to create a continuous channel for the passage of the signal, and means for creating a barrier to pressure between the inner side and the outer side of the tubular the walls of at least one slot located in the Central hole, and a trigger tool configured to pass through the drill string and enter the Central hole of the sub. 2. The device according to claim 1, in which the walls of the elongated body are made entirely of metal. 3. The device according to claim 1, in which the section provided with slots is made of non-magnetic material. 4. The device according to claim 1, in which the means for creating a barrier to pressure includes a sleeve located in combination with provided with slots section. 5. The device according to claim 1, in which the trigger tool is adapted for pumping through the drill string or moving on the cable in the drill string. 6. The device according to claim 1, in which the trigger tool at one end contains a connecting means adapted to remove the trigger tool from the hole of the sub. 7. The device according to claim 1, which further comprises contact means located between the trigger tool and the wall of the Central hole and adapted to ensure the passage of electric current between the trigger tool and the specified wall when the tool is located in the Central hole. 8. The device according to claim 1, in which the trigger tool contains a permanent magnet. 9. The device according to claim 1, in which the trigger tool comprises a modulator for remote communication when the trigger tool is located in the sub. 10. The device according to claim 1, in which the trigger tool comprises means for storing data. 11. The device according to claim 1, in which the trigger tool comprises at least one antenna adapted to transmit and / or receive electromagnetic energy. 12. The device according to claim 11, in which the sub contains a means for placing the trigger tool, configured to position the trigger tool inside the center hole so that at least one antenna of the tool is in alignment with the slotted section in the sub. 13. The device according to claim 11, in which the sub is adapted with the specified means in the Central hole to focus at least one antenna located on the trigger tool when it is located in the sub. 14. The device according to claim 11, in which at least one antenna of the trigger tool is surrounded by a screen having at least one slot formed in it. 15. The device according to claim 11, in which the trigger tool contains at least one cavity formed therein, adapted to accommodate the antenna. 16. The device according to claim 1, in which the trigger tool contains one source of gamma radiation. 17. The device according to claim 1, in which the sub contains an eccentric tool for securing the eccentricity of the trigger tool in the Central hole when the location of the trigger tool in the sub. 18. The device according to claim 1, in which the trigger tool contains at least one gamma radiation detector. 19. The device according to claim 1, in which the trigger tool contains a neutron source. 20. A method of transmitting and / or receiving a signal through the earth formation, in which a well is drilled in the earth formation using a drill string containing a sub having an elongated body with tubular walls, at least one section having at least one gap formed in it and completely passing through the tubular wall to create a continuous channel for the passage of the signal, and means for creating a barrier to pressure between the inner side and the outer side of the tubular wall, located inside the central a hole at at least one slit, have a trigger tool inside the sub with a means for transmitting signals and / or with a means for receiving signals, place a trigger tool inside the sub so that at least one means for transmitting or receiving signals was combined with at least one slotted section in the sub, and transmit or receive a signal through the formation, respectively, by means for transmitting signals or means for receiving signals. 21. The method according to claim 20, in which when transmitting or receiving a signal through the formation, a signal is transmitted to another sub of the drill string or a signal is received from another sub of the drill string. 22. The method according to claim 20, in which use is made of a means for transmitting signals, configured to transmit electromagnetic energy, and means for receiving signals, is configured to receive electromagnetic energy. 23. The method according to item 22, in which additionally establish a connection of the received electromagnetic energy with the electrical resistivity of the formation. 24. The method according to claim 20, in which the location of the trigger tool in the sub is carried out when the sub is located on the surface of the formation. 25. The method according to claim 20, in which the location of the trigger tool in the sub is carried out by moving the trigger tool through the drill string to place it in the sub. 26. The method according to claim 20, in which further comparing the received signal with the position of the sub in the well. 27. The method according to claim 20, in which additionally perform telemetry of data representing the received signal from a location remote from the sub. 28. The method according to claim 20, in which additionally storing data representing the received signal in a means for storing data in the trigger tool. 29. The method according to claim 20, wherein the signal is received or transmitted through the formation when the drill string is removed from the well. 30. A method for measuring the characteristics of the earth formation surrounding a well, in which a trigger tool is used with at least one means for transmitting signals or with at least one means for receiving signals, with an end means capable of receiving a fishing head or cable connection, place the trigger tool in the sub on the drill string to measure formation characteristics, use means to transmit or receive when passing the drill string, a sub having an extension a body with a central hole and including at least one slot formed therein to provide a channel for the passage of the signal, and means for creating a barrier for pressure between the inner side and the outer side of the sub at least one slot. 31. The method according to clause 30, wherein the location of the trigger tool in the sub is carried out when the sub is located on the surface of the earth to measure formation characteristics when drilling a well through the formation. 32. The method according to claim 30, wherein the trigger tool is positioned in the sub by moving the tool through the drill string to be placed in the sub to measure formation characteristics when the drill string is removed from the well.

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