System and method for control of multiple downhole tools

FIELD: oil and gas industry.

SUBSTANCE: multiple downhole tools can be driven between operating positions. Downhole tools are connected to a variety of multitapped modules, at that each multitapped module is connected usually to one or downhole tools. Control lines are connected to multitapped modules, and multitapped modules are capable to control downhole tool in bigger quantity than quantity of control lines. Each downhole tool is driven individually delivering pressure through one or several control lines.

EFFECT: facilitating control over multiple downhole tools.

23 cl, 25 dwg

 

The scope and level of technology

In many underground conditions, such as downhole conditions, downhole tools used to perform various procedures. For example, downhole tools may represent a different valves flow control, relief valves, flow regulators, packers, gas lift valves, sliding sleeves, and other downhole tools. Many of these downhole tools can be controlled hydraulically by the supply of hydraulic control lines that run down the borehole. Conventional downhole tools often depend on a dedicated hydraulic control line or lines laid to the specific tool located in the borehole. The number of downhole tools that are placed down the well, may be restricted by the number of control lines existing in the wellbore. The wellbore and/or the downhole equipment, such as packers, used in a particular application, may also impose limits on space or restrictions on the gasket compounds that limit the number of control lines. In addition, even in applications that allow you to add the line of control, with additional lines there is a tendency of slowing down the installation and increase the value from the system equipment down the hole.

Attempts have been made to reduce the number of hydraulic control lines required to perform certain related procedures well. For example, to limit the number of hydraulic control lines using multiplexers. However, multiplex systems are often based on the possibility of forming multiple pressure levels, which are interpreted in the descending well. In some specialized systems, the maximum number of downhole tools is limited by the number equal to the number of hydraulic control lines. In other attempts, developed valves with electric/solenoid control or specialized hydraulic devices and tools to respond to a sequence of pressure pulses that are fed down the well. However, many such systems have been very expensive and relatively slow acting.

Disclosure of inventions

In General, the present invention provides a system and method for controlling multiple downhole tools. Many downhole tools can be actuated between work positions. Downhole tools connected with many multidrop modules, with each multidrop module is typically connected to one or two wells is diversified instruments. Many control lines connect with multidrop modules, and the number of multidrop modules and attached downhole tools may be greater than the number of control lines. In addition, each of the downhole tool can be actuated individually, creating pressure through one or more control lines. This pressure can be created with the same pressure level.

Brief description of drawings

Below are some embodiments of the invention will be described with reference to the accompanying drawings, in which identical reference positions indicated similar elements and in which:

figure 1 - schematic view of the drive system for downhole tools in a variety of downhole tools and multidrop modules deployed in a wellbore, according to a variant implementation of the present invention;

figure 2 - schematic illustration of another example of a drive system for downhole tools according to a variant implementation of the present invention;

figure 3 - schematic illustration of one example of a multidrop module used in the drive system of the downhole tools according to a variant implementation of the present invention;

4 is a view multidrop module, shown in figure 3, but with a different flow pattern, with the according to yet another variant implementation of the present invention;

5 is a view multidrop module, shown in figure 3, but in another condition of operation, according to another variant implementation of the present invention;

6 is a table illustrating one example of a program multidrop module for individual actuation of a specific downhole tools according to a variant implementation of the present invention;

7 is a table illustrating another example of a program multidrop module for individual actuation of a specific downhole tools, according to a variant implementation of the present invention;

Fig is a schematic illustration of another example of a drive system for downhole tools, according to a variant implementation of the present invention;

Fig.9 is a schematic illustration of another example of a drive system for downhole tools, according to a variant implementation of the present invention;

figure 10 is a schematic illustration of one example of a multidrop module used in the drive system of the downhole tools, shown in Fig. 8 and 9, according to a variant implementation of the present invention;

11 is a view multidrop module, shown in figure 10, but in another condition of operation, according to a variant implementation of the present invention;

Fig - view megatv the underwater module, shown in figure 10, but in another condition of operation, according to a variant implementation of the present invention;

Fig is a table illustrating one example of a program multidrop module for individual actuation of a specific downhole tools according to a variant implementation of the present invention;

Fig is a table illustrating another example of a program multidrop module for individual actuation of a specific downhole tools according to a variant implementation of the present invention;

Fig is a schematic illustration of one example of a multidrop module with modular programmable locking mechanism according to a variant implementation of the present invention;

Fig - type multidrop module shown in Fig, but with a different flow pattern, according to another variant implementation of the present invention;

Fig - type multidrop module shown in Fig, but with a different flow pattern, according to another variant implementation of the present invention;

Fig - type multidrop module shown in Fig, but with a different flow pattern, according to another variant implementation of the present invention;

Fig - type multidrop module shown in Fig, but with a different flow pattern, according to odnoprotsentnuyu of the present invention;

Fig is a schematic illustration of another example of a multidrop module with modular programmable locking mechanism according to a variant implementation of the present invention;

Fig - type multidrop module shown in Fig, but with a different flow pattern, according to another variant implementation of the present invention;

Fig - type multidrop module shown in Fig, but with a different flow pattern, according to another variant implementation of the present invention;

Fig - type multidrop module shown in Fig, but with a different flow pattern, according to another variant implementation of the present invention;

Fig - type multidrop module shown in Fig, but with a different flow pattern, according to another variant implementation of the present invention; and

Fig - type multidrop module shown in Fig, but with a different flow pattern, according to another variant implementation of the present invention.

Detailed description

In the following description to facilitate understanding of the present invention sets out numerous details. However, specialists in the art should be understood that the present invention can be applied in practice without these details and that numerous possible options or modificationtime options for the implementation.

In General the present invention relates to a system and method of controlling downhole tools. Multidrop module deploys between the downhole tool and the control lines that stretch to the surface. Many downhole tools and related multidrop modules can be connected to the control lines, and for multidrop modules requires only one pressure level. The use of multidrop modules allows you to choose to activate one or more downhole tools from all deployed downhole tools. In addition, each multidrop module can't remember the last selection made on the basis of pressure applied down the hole on the control lines.

Regarding figure 1, there is shown one version of the drive system 30 of the downhole tools. The drive system 30 can be mounted together or otherwise connected with equipment 32 used in underground conditions, such as in downhole conditions. Equipment 32 includes, for example, downhole equipment, wells, or other equipment used in the barrel 34 wells, for example, in the trunk of an oil or gas well.

In the shown embodiment, the drive system 30 downhole instrumento which contains many downhole tools 36. Actuation of downhole tools 36 based on the flow rate of the fluid supplied to many control lines, for example, on lines 38, 40, and 42 controls. In this embodiment, used three control lines, and control lines stretched upwards, for example, to place on the surface. The number of downhole tools 36, which can be controlled independently, may be more or even much more than the number of control lines. Figure 1 is a downhole tool shown in dotted lines, represents one or more downhole tools in addition to other shows downhole tools.

Downhole tools 36 may operate fluid medium, such as hydraulic fluid flowing through one or more lines 38, 40, 42 control. In addition, depending on the application there are many downhole tools 36 may be a downhole instruments of various types and combinations of instruments. For example, downhole tools 36 may contain valves flow control, flow control, packers, gas lift valves, sliding sleeves, and other tools that can operate fluid medium, for example, hydraulic fluid medium. Figure 1 downhole tools 36 are shown as phuhlisani tools which bring into force, by means of feed of the two control lines. However, as shown in figure 2, the downhole tools 36 may also be a single-line tools.

As shown in figure 1, each line of the downhole tool 36 is connected with multidrop module 44, which may be located in a downstream hole near the corresponding downhole tool 36. In the embodiment shown in figure 2, a pair of single-line instruments can be connected to each multidrop module 44. Many multidrop module 44 controls the flow of the working fluid and hence, actuation of the respective downhole tools 36. In the shown embodiment, each of the downhole tool can be actuated individually by innings peer pressure supplied to the multidrop module 44, for example, according to one of the control lines. Each multidrop module 44 has a special programme is schematically shown in the diagrams indicated in figure 1 by the reference position 46. For example, each multidrop module 44 can be programmed to respond to and provide actuation of the corresponding downhole tool 36 when receiving a certain amount of pressure pulses. The amount of pressure pulses, for example, pulses peer pressure, can be detected and monitored by indexers, which, as explained in more detail below, are unique to specific multidrop module 44.

Regarding figure 3, there is shown one version of the multidrop module 44. In this embodiment, each multidrop module 44 includes a housing 48 containing a valve 50, such as a two-position valve that can be installed in the switched position and the position of the failure. For example, the valve 50 may be located inside the housing 48 for translational/sliding movement on the inner side 52 of the housing 48. The valve 50 is functionally associated with the indexer 54 through the piston 56. In this example, the indexer 54 includes a sleeve 58 indexer and interacting pin 60 indexer, which can be installed in the housing 48. The indexer 54 may be dip/x-stepper indexer with J-shaped groove, is programmed to transfer multidrop module 44 in the switched position for a given amount of feed pressure applied to the indexer 54 through line 38 to the control.

As shown, gasket 61 may be located around the piston 56 to form a seal with the inner surface of the housing 48. In addition, the return spring 62 may be located inside the building the sa 48 for actions against the valve 50 in the direction which is offset against the pressure applied to the indexer 54 and the piston 56 through line 38 to the control. For example, the valve 50 is displaced by the piston 56 when the supply pressure is supplied through line 38 management, and return spring 62 performs the reverse valve 50 in the opposite direction after the supply pressure is removed.

When pressure is applied to line 38 of the control piston 56 is moved to the spring 62 and compresses the spring. The stroke of the piston 56 is limited by the profile of the groove of the sleeve 58 indexer and interacting pin 60 indexer. When the pressure is released from line 38 to control the recoil spring 62 forces the piston 56 to move in the opposite direction. Again, the profile of the groove of the sleeve 58 indexer and interacting pin 60 indexer restrict the movement of the piston 56 and therefore determine its final position. Every time pressure is applied through line 38 to control the indexer 54 moves, making the next step. Depending on specific programs indexer, for example, the profile groove of the indexer, the valve 50 remains in its current position or shifted to another position. For example, the indexer 54 can be programmed by selecting the appropriate profile of the groove, so that the valve 50 in the position of "positives" in the first step, i.e. after the first the second pressure line 38 management and later remained in the position of "failure" on the remaining steps of the indexer. If the indexer 54 is x steps, when x podvedenych pressure, such as the filing of peer pressure line 38 to control the indexer moves throughout the profile.

Figure 3 the valve 50 is installed in the switched position that allows you to trigger the appropriate downhole tool 36. In this position the hydraulic energy can be transferred through a line 40 to the control via a multidrop module 44 and line 64 to actuate the downhole tool to actuate the downhole tool 36 in the first direction. For example, if the downhole tool 36 includes a valve, line 64 actuation may be an "open" line, which allows you to open the valve. When multidrop module 44 remains in this position, actuation, hydraulic energy is also transmitted through line 42 to control, via multidrop module 44 and the second line 66 to actuate the downhole tool 36 to bring the downhole tool 36 in the other working position shown in figure 4. If, for example, the downhole tool 36 includes a valve, line 66 actuation may be a "closed" line, which allows the valve to close. In some of the s variants of the implementation of the downhole tool 36 contains a volume of fluid, which will be refunded at the time of actuation. For example, actuation of the downhole tool 36 through line 64 actuation causes the flow of return fluid line 66 to actuate. Similarly, actuation of the downhole tool 36 through line 66 actuation causes the flow of return fluid line 64.

At the end of a specified or programmed quantity of feed pressure to the multidrop module 44 through line 38 to control the indexer 54 and multidrop module 44 are shifted in position failure, shown in figure 5. As shown, the indexer 54 through the piston 56 holds the valve 50 in the position in which regardless of the feed pressure applied on the control line 40 or line 42 control, prevents actuation of the downhole tool 36. The valve 50 remains in the position of the failure until such time as the proper amount of feed pressure is not applied on line 38 to cause the shift indexer 54 and therefore, the valve 50 back to the switched position shown in figure 3.

Each indexer can be uniquely programmed, for example, may contain a unique profile of the groove to match a given quantity of feed pressure required to move many of the outlet module 44 from the position of the trigger in the position of the failure and again in the opposite direction. The program indexer for each multidrop module is unique about the program indexer for other multidrop modules. In some embodiments, the implementation of each multidrop module has its own unique program. In accordance with this, each time in line 38 control creates increased pressure in the pressure supply, each multidrop module 44 moves to step with the help of an indexer 54. However, any resulting change of position of the particular valve 50 depends on a unique program or profile of the groove of its indexer. Indexers 54 different multidrop module 44 can be programmed to allow selection of one tool at a given time or more instruments in a given time. Of course, changes can be predicted on the basis of a predetermined program, for example the profile of the groove of each collet indexer.

For example, as shown in Fig.6, many multidrop module 44 can be programmed in a unique way. In this example, the first pressure supply in multidrop module 44 causes a shift of the first module in the switched position, while the second and third modules remain in a state of failure. The second pressure supply causes the second step indexers 54 in each of the m multidrop module 44, the resulting shift of the second multi-tap module in the switched position and the first and third multidrop modules in position failure. The third supply pressure supplied to the multidrop modules, is the reason that the first and second modules remain or move into the position of failure, while the third multidrop module goes into the switched position. However, in the case of a specific application you can use many different programs to shift multidrop modules between the provisions of positives and negatives. In addition, as shown in Fig.7, some or all of multidrop modules can be programmed to shift at the same time in the switched position or the position of the failure. In this example, the first pressure supply and the first step indexers 54 causes a shift of all shows multidrop modules in the switched position. As shown, subsequent pressure cause the individual transition multidrop modules between the provisions of positives and negatives.

As far as Fig. 8 and 9, it shows another variant of the drive system 30 of the downhole tools. In this embodiment, downhole tools 36 and multidrop modules 44 are controlled by a pair of lines 68, 70 management. Campocatino, each multidrop module 44 can be used to control the actuation, for example, one two-line tool, which is shown in Fig. Alternatively, multidrop modules 44 can be used to control the actuation of a single-line tools 36, such as a pair of single-line tools 36, managed each multidrop module 44, which is shown in Fig.9.

Example multidrop module 44, which can be used in the system of two control lines, shown in figure 10. In this embodiment, each multidrop module 44 and in this case includes a housing 48 in which is placed a valve 50. However, the valve 50 is a three-position valve having three different operating positions, including a first switched position, the second switched position and the position of the failure. If the downhole tool 36 includes a valve or similar device, the first switched position may be the position "open tool" and the second switched position may be the position of the closed tool. The three-position valve 50 on the movement associated with the indexer 54 through the piston 56. However, in this embodiment, the indexer 54 is a three-position indexer, such as three-position/x-stepper indexer with J-shaped p the zoom, able to move the valve 50 in three operating positions.

When the line 68 control down pressure, the piston 56 is moved to the spring 62 and compresses the spring. The stroke of the piston 56 is limited by the profile of the groove of the sleeve 58 indexer and interacting pin 60 indexer. When the pressure is released from line 68 management, return spring 62 forces the piston 56 to move in the opposite direction. And in this case the profile of the groove of the sleeve 58 indexer and interacting pin 60 indexer restrict the movement of the piston 56 and therefore determine its final position. Whenever the pressure down on line 68 control the indexer 54 moves, making the next step. Depending on specific programs indexer, for example, the profile groove of the indexer, the valve 50 remains in its current position or moves to the next position. For example, the indexer 54 can be programmed using the correct profile of the groove so that the valve 50 is in position "closed" tool in the first step, in the position "open tool" in the second step, and in the position of "failure" on the rest of the steps indexer relative to the profile of the indexer. If the indexer 54 is x steps, then x the application of pressure, for example, the filing of peer pressure in line 68 control the indexer moves to the window and the whole profile and then back to position "closed"tool.

Figure 10 valve 50 is installed in the first switched position, for example, in the open position of the instrument that provides the actuation of the corresponding downhole tool 36 in the first direction. In this position the hydraulic energy can be transferred through a line 70 to the control via a multidrop module 44 (partly via a flow channel 72 through valve 50 and line 64 to actuate the downhole tool to actuate the downhole tool 36 in the first direction, for example, to open the downhole tool. The return flow of fluid may be conducted through line 66 to actuate via multidrop module 44 and in line 68 management through additional flow channel 74. The check valve 76 is located along the additional flow channel 74 to allow movement of the return flow of the multidrop module 44 in line 68 of the control and at the same time, blocking reverse flow of fluid during the processing of the feed pressure in line 68 of the control.

After summing up the specified number of feed pressure to the multidrop module 44 through line 68 to control the indexer 54 and multidrop module 44 are shifted in position failure is shown figure 11. The indexer 54 through the piston 56 holds the valve 50 in the position the AI, which prevents actuation of the downhole tool 36 regardless of the pressure of the fluid supplied through the line 70 to the control. The valve 50 remains in the position of the failure until such time as the proper amount of feed pressure will be brought on line 68 control to cause the shift indexer 54 and, consequently, the valve 50 into the second switched position, for example, the closed position of the tool shown in Fig. In this position the hydraulic energy can be transferred through a line 70 to the control via a multidrop module 44 (via a flow channel 72 through valve 50 and line 66 to actuate the downhole tool to actuate the downhole tool 36 in the second direction, for example, for closing the downhole tool. The return flow of fluid may be conducted through line 64 to actuate, via multidrop module 44 and in line 68 management through additional flow channel 74.

And in this case, each indexer can be programmed with a unique profile of the groove, which corresponds to the specified number of feed pressure required to move multidrop module 44 between the two positions of operation and location of the failure. The program indexer for each multidrop module can be unique about the program indexer for other multidrop modules. In some embodiments, the implementation of each multidrop module can have its own individual program. In accordance with this, each time in line 38 management create an increased pressure by applying pressure, each multidrop module 44 moves to step with the help of an indexer 54. However, any resulting change in position of the valve 50 depends on a unique program or profile of the groove of its indexer.

For example, as shown in Fig, many multidrop module 44 can be programmed in a unique way. In this example, the first pressure supply to the multidrop modules 44 causes a shift of the first module in the first switched position, while the second and third modules remain in a state of failure. The second pressure supply causes the latter moves the indexer 54 in each multidrop module 44, resulting in the shift of the first multidrop module into the second switched position, while the second and third modules remain in a state of failure. The third supply pressure supplied to the multidrop modules, causes a shift of the second multi-tap module in the first switched position, while the first and third multidrop modules move or remain in a state of failure. The fourth pressure supply causes the displacement is their second multidrop module into the second switched position, while the first and third modules remain in a state of failure. The fifth supply of pressure causes a shift in the third multidrop module in the first switched position, while the first and second multidrop modules move or remain in a state of failure. Sixth applying pressure causes a shift in the third multidrop module into the second switched position, while the first and second multidrop modules remain in a state of failure. And in this case, all pressure can be performed at the same pressure level.

Similar to the first one shows a variant implementation in this implementation for a particular application are available on request many different programs to shift multidrop modules between a first switched position, the second switched position and the position of the failure. In addition, a number or all of multidrop modules can be programmed for simultaneous shift in the switched position or the position of the failure. For example, as shown in Fig, the first pressure supply and the first step indexers 54 cause a shift shown multidrop modules in the first switched position. The second pressure supply line 68 management leads to add the GU multidrop modules in the second switched position. Subsequent pressure can cause the individual transitions multidrop modules shown between the first switched position, the second switched position and the position of the failure.

In yet another embodiment, each multidrop module may contain a locking mechanism, which allows at any given time to perform selective conversion of all downhole tools in the default position, for example, in the closed position. The locking mechanism may be particularly useful in downhole drive systems, control line downhole tools.

On Fig generally shows one variant of implementation of the multidrop module 44 includes a locking mechanism 78. In this embodiment, multidrop module 44 contains two indexer 54 provisions, such as the indexer described with reference to figure 3, and the three-position valve 50, such as the valve described with reference to figure 10. For example, the indexer 54 can be used sleeve 58 indexer with J-shaped groove, which communicates with the pin 60 indexer. However, the locking mechanism 78 is able to block the sleeve 58 indexer with J-shaped groove at any point in time, when fed a given sequence of pressures. This allows any C is given time to move all downhole tools 36 in the default position, such as a closed position.

Locking mechanism 78 may have different configurations, designed to capture and hold the valve 50 in the position in which the flow of fluid through the multidrop module 44 to bring the downhole tool 36 at a desired position by default. However, in the shown embodiment, the locking mechanism 78 includes the locking mechanism 80 mounted in the housing 48 and has a plot, with the ability to slip posted on the enlarged section 82 of the piston 56. The valve 50 and the extended section 82 can be advanced along the locking mechanism 80 in the closed position of all instruments. When you move the enlarged section 82 along the locking mechanism 80 is compressed spring 84 of the locking mechanism.

Multidrop module 44 shown in Fig can move between the position of the actuation, for example, the position of the opening of the tool, the position of the unavailability, for example, the impossibility of opening tools, and a closed position of all instruments. The indexer 54 is used to selectively move the valve 50 between the first two work positions. For example, the indexer 54 can be used to move multidrop module 44 in the switched position, best shown in Fig. In this position fluid sidepod pressure can be brought on line 40 management and is directed through the valve 50 in line 64 of bringing actions for actuation, for example, the opening of the downhole tool 36. When reviewing the feed pressure line 38 to control the indexer 54 is moved to a specified number of steps to move the valve 50 and multidrop module 44 in the position of the failure shown in Fig. As described above, the indexer 54 is open at the end of the feed pressure, for example, filings peer pressure line 38 controls that move the piston 56 in one direction, while the return spring 62 causes movement in the opposite direction for step-by-step shift indexer 54 along its profile. In the position shown in Fig, the tool 36 cannot be actuated even if the fluid medium is supplied via the control line 40 and line 42 to the control. Moving through the valve 50 of any fluid supplied through line 42 control is blocked check valve 86.

However, all valves 50 many multidrop module 44 can move in the closed position of all instruments in the closing sequence of pressures. For example, line 42 management can be summed up pressure sufficient to impact on the valve 50 and the creation of the shift valve 50 to the left as shown by the arrow 88 in Fig. The check valve 86 prevents transmission of pressure to the downhole tool 36. When postupatel the m moving the valve 50 and the piston 56, the spring 84 of the locking mechanism will be compressed until while, as shown in Fig, the protruding portion 82 of the piston will not move a sufficient distance for the locking mechanism 80. While the spring 84 is compressed, two indexer 54 position is not moved. In addition, while the pressure in line 42 management is supported, in line 40, the control pressure is supplied to create a translational movement of the locking mechanism 80, which is held or fixed main piston 56 and the valve 50 in the closed position of all instruments. The piston 56 remains in this position while supported by the pressure in line 40 control. At this point, the pressure can be released from the line 42 control that allows fluid environment, in line 40 control under high pressure, to move the downhole tool 36 in the default position, for example in the closed position, shown in Fig. The ability to shift all multidrop module 44 in the closed position all of the tools allows you to simultaneously bring all downhole tools 36 to a predetermined position by default. In other words, the programmable valve position specified by the indexers 54, can be blocked to move all downhole tools 36 in the default position. If, for example, downhole tools 36 contain downhole valves, all cleanyou to be moved to the closed position at any time.

Another option multidrop module 44 shown in Fig. According to this variant in multidrop module 44 locking mechanism 78 is combined with the three-position valve and the three-position indexer 54. The three-position valve 50 in combination with the three-position indexer 54 allows the valve 50 and the multi-turn module 44 having a first switched position, for example, the open position of the tool, the second switched position, for example, the closed position of the tool, and the position of the failure. In addition, the locking mechanism 78 allows all valves 50 and all multidrop modules 44 in this drive system 30 downhole tools (for example, see figure 1) simultaneously to move to the default position. As described above, in the closing sequence of the pressure locking mechanism 78 is able to block the valve position determined by the indexers 54. For example, all downhole tools in the system 30 can simultaneously be moved to the closed position.

On Fig valve 50 and multidrop module 44 is installed in the first switched position, for example, open the device. In this position the hydraulic energy can be transferred through a line 40 to control, via multidrop module 44 and line 64 to actuate the downhole tool is to actuate the downhole tool 36 in the first direction. For example, if the downhole tool 36 includes a valve, line 64 actuation may be an "open" line, which allows us to open the valve. After summing up the specified number of feed pressure to move the indexer 54 corresponding to a specified number of steps the valve 50 and multidrop module 44 can move in the position of the failure shown in Fig. In this position, the valve 50 prevents actuation of the downhole tool 36 regardless of how the working environment is supplied tool, line 40 management or line 42 management. Additional feed or feed pressure in line 38 management encourages the indexer 54 to move the valve 50 into the second switched position, for example, the closed tool. In this position, fluid under pressure may flow through line 40 control multidrop module 44 and line 66 actuation to actuate the downhole tool 36, for example, closing the downhole tool 36, shown in Fig. Does the downhole tool 36 in the first switched position or the second position of the trigger, recoil fluids may be sent through the multidrop module 44 through check valve 86 and line 42 to the control.

In the latter embodiment, also provided is by the ability to simultaneously shift all of the valves 50 and all multidrop module 44 in the default position in any selected point in time when reviewing the sequence of pressures. If the drive system 30 downhole tools (for example, see figure 1) contains downhole tools, such as valves, for example, all valves can be closed at any desired time. To block programmable provisions of the instruments sufficient pressure down on the line 42 to act on the valve 50 and to cause the shift valve 50 to the left, shown in Fig. And in this case, the check valve 86 prevents transmission of pressure to the downhole tool 36. While maintaining the pressure in the line 42 to control the pressure down on the line 40 to cause the translational movement of the locking mechanism 80 by the way, according to which the main piston 56 and the valve 50 is held or fixed in position closing all of the tools shown in Fig. At this point, the pressure can be released from the line 42 to the control that will allow fluid under pressure in line 40 of the control to move the downhole tool 36 in the default position, for example, in the closed position, shown in Fig. Any return fluids are free to flow through line 64 to actuate, through the check valve 86 and line 42 to the control. All downhole tools 36 may be similarly and simultaneously closed or brought into position by default

Drive system 30 downhole tools (e.g., see Fig. 1, 2, 8 and 9) can be designed in a variety of configurations for use in various trunks wells and other underground environments. The number of multidrop modules may be larger or even much larger than the number of control lines used to control multidrop modules and their respective downhole tools. In addition, even if the number of multidrop modules greater than the number of control lines, multidrop modules and their respective downhole tools may be individually controlled by the feed pressure directed all multidrop modules at the same pressure level. Furthermore, the types and configurations of downhole tools 36 and multidrop module 44 may vary from one application to another (for example, see Fig. 3, 10 and 15). Components inside the multidrop modules can also be selected in accordance with the specified actuation for a given application or environment. For example, in a multidrop module can be used with valves of different types and indexers of various kinds. In addition to this locking mechanism can be designed in various forms, and various locking mechanisms can be used to hold the valves in position the research Institute of the block.

Accordingly, although the above describes only some embodiments of the present invention, specialists in the art should be understood that numerous modifications are possible without significant deviations from the ideas of this invention. Such modifications are assumed to be included in the scope of this invention defined in the claims.

1. System for use in a borehole, comprising: a variety of downhole tools, with each of the downhole tool may operate between the first working position and a second working position; many multidrop modules, with each multidrop module is connected with the corresponding downhole tool from a variety of downhole tools; and at least two control lines connected with many tap-ins, the number of downhole tools is greater than the number of control lines, and each of the downhole tool may operate individually specified number of signals peer pressure supplied to many tap-ins on individual lines control of the at least two control lines.

2. The system according to claim 1, in which at least two control lines are three control lines.

3. Si is theme according to claim 1, in many downhole tools contains many valves.

4. The system according to claim 1, in which each multidrop module contains the indexer, individually programmed for installation multidrop module in the switched position, allowing to actuate the downhole tool, and the position of the failure.

5. The system according to claim 1, in which each multidrop module is connected with one line of the downhole tool.

6. The system according to claim 1, in which each multidrop module is connected with a pair of single-downhole tools.

7. The system according to claim 1, additionally containing a locking mechanism to allow the closing of all of the many downhole tools at any chosen time.

8. System for use in a borehole, comprising: a variety of downhole tools and lots of multidrop modules, with each multidrop module is connected with the corresponding downhole tool to selectively enable actuation of the corresponding downhole tool when multidrop module switches in the switched position, each multidrop module contains an indexer is programmed to transition multidrop module in the switched position when you receive a specified share of the VA signal pressure, supplied at the same pressure level through individual control line, where the specified number is the individual regarding the number of signals of the pressure required to enable actuation of other downhole tools.

9. The system of claim 8, further containing a pair of hydraulic control lines connected with many tap-ins, the number of multidrop modules is greater than the number of hydraulic control lines.

10. The system of claim 8, additionally comprising three hydraulic control line connected to a lot of multidrop modules, the number of multidrop modules is greater than the number of hydraulic control lines.

11. The system of claim 8, in which each multidrop module contains a two-position valve connected to the indexer sleeve with the J-slot.

12. The system according to claim 11, in which a two-position valve is shifted between the actuation position and the position of the failure.

13. The system of claim 8, in which each multidrop module contains a three-position valve connected to the indexer sleeve with the J-slot.

14. The system of item 13, in which the three-position valve is shifted between the position of the actuation opening, the position of the quarter who were closing and the position of the failure.

15. The system of claim 8, in which each multidrop module is connected with a pair of single-line tools.

16. The system of claim 8, further containing a locking mechanism to allow the closing of all downhole tools at any chosen time.

17. The method including steps in which: connect many multidrop modules with many relevant downhole tools to control the actuation of the many downhole tools; connecting the at least two hydraulic control lines with lots of multidrop modules; selectively move each multidrop module in the specified operating States, summing a set number of innings peer pressure through at least one of the hydraulic control lines; and individually control multidrop modules in a larger number than the number of hydraulic control lines, connected to the multidrop modules, so that the greater the number of multidrop modules not depending on the number of control lines.

18. The method according to 17, in which the connection includes the connection line of the downhole tool, at least one multidrop module.

19. The method according to 17, in which the compound includes compounds is their single pair of downhole tools, at least one tap module.

20. The method according to 17, in which the electoral move involves the management of multiple multidrop modules with multiple indexers, each of which is programmed for individual matching a given actuation of a particular downhole tool.

21. The method according to 17, further comprising the use of a locking mechanism in each multidrop module for simultaneously closing all of the relevant downhole tools.

22. The method including steps in which: forms a set of multidrop modules so that each multidrop module has an individual indexer, which can be indexed by a signal pressure; programming each individual indexer, to allow actuation of the corresponding downhole tool at the end of a specified number of pressure signals associated with the respective downhole tool; signal pressure down the well into the well bore through a variety of hydraulic control lines and individually controlled downhole tools in a larger number than the number of hydraulic lines through selective feeding a specified number of pressure signals through individual guide is allicesia control line, United with many downhole tools to manage a variety of downhole tools.

23. The method according to item 22, further comprising the use of a locking mechanism in each multidrop module for simultaneously closing all of the relevant downhole tools.



 

Same patents:

FIELD: oil and gas industry.

SUBSTANCE: power supply unit of bottomhole telemetric system contains electric generator, bottomhole rotational motor, low-speed autosyn dynamotor which rotor is connected kinematically to shaft of bottomhole motor through magnetic coupling. At that magnetic coupling is made in a sealed housing together with autosyn dynamotor. Low-speed autosyn dynamotor operates at rotary velocity of bottomhole rotational motor.

EFFECT: improving reliability of power supply unit for bottomhole telemetric system and simplifying its design.

5 cl, 1 dwg

FIELD: mining.

SUBSTANCE: proposed method comprises determination of drilling column operating parameters and variation of downhole instrument operation mode depending upon said parameters. Note here that for data transfer to downhole instrument drilling column parameters are abruptly changes by preselected program to fix time intervals between sharp changes in drilling column working parameters with that fixed set of time intervals can be used for variation of downhole instrument operating mode.

EFFECT: simplified and reliable control.

FIELD: oil and gas industry.

SUBSTANCE: method consists in excitation of an electric current in a metal string in a well by means of a ground-based generator connected with one contact to surface part of the metal string and with the other contact to a receiving electrode on the well surface. Commutation of a dielectric insert dividing the metal string in the well into upper and lower parts is performed. Another string of metal pipes lowered to that well is used as the receiving electrode. Therefore, an electric circuit of a metal string in the well and a receiving electrode is formed, via which direct current stabilised as to the value is transmitted from the ground-based generator. Reception of information from the well working face is performed depending on modulation of the value of stress caused by commutation of the dielectric insert. As a ground-based generator there used is a source of stabilised direct current, and as a receiving electrode there can be used a metal string of the tubing.

EFFECT: improving reliability of information transmission from the working face via an electromagnetic communication channel and enlarging the application scope.

4 cl, 1 dwg

FIELD: mining.

SUBSTANCE: retaining device (13) inserted into a central channel of a drilling string component. The channel has the first diameter on at least a part of the central section of the drilling string component, and the second diameter near the ends of the drilling string component. The second diameter is less than the first diameter. The retaining device (13) comprises a lengthy body (14), forming at least partially a jacket for a transfer line. The lengthy body (14) has transverse dimensions less than the second diameter. Multiple arc elements (15) are arranged along the lengthy body (14). Arc elements are separate from the lengthy body and are attached to it.

EFFECT: arc elements are elastically bending for provision of their displacement through the second diameter and have the largest chord that is more than the first diameter in free condition for creation of an opportunity of expansion in the first diameter after stretching via the second diameter.

3 cl, 9 dwg

FIELD: physics.

SUBSTANCE: electrodes are separately exposed to the impact of periodically accumulated potential energy of a spring, which is generated by rotating screw pairs and abrupt (impact) release of energy when screw interaction of crests of the screw pairs ceases. The apparatus for realising the method is a drive structure having an output shaft which actuates the screw pairs. During forward rotation, the screw pairs open centralisers and elastically press the electric leads to the wall of the well casing, apply periodic action on the electrodes that are rigidly connected to the electric leads. The electric leads are cut into the wall of the well casing. Impact action occurs when screw interaction between the screw and nut, which is pressed by a power spring, ceases.

EFFECT: improved electrical contact between electric leads and a casing column.

10 cl, 4 dwg

FIELD: physics.

SUBSTANCE: disclosed is a seal assembly for an electrical logging probe, having a cylindrical housing, a plurality of dielectric inserts placed in the housing, a plurality of annular electrodes coaxially placed in the housing between the dielectric inserts and touching the end faces of the dielectric inserts with their end faces, an insulating means placed on the cylindrical housing for electrical insulation of the plurality of annular electrodes from the housing. According to the invention, each of the plurality of annular electrodes and dielectric inserts in contact with the annular electrodes have bevel end faces. The bevel end faces of the electrodes are interfaced with the bevel end faces of the dielectric inserts that are in contact with them. The seal assembly has a means of generating a compression force and fixing, which is in contact with the end face of the dielectric insert, placed distally with respect to said dielectric insert which is in contact with the cylindrical housing.

EFFECT: high containment of electric equipment of the probe from the external medium of the well and improved probing data.

12 cl, 5 dwg

FIELD: radio engineering, communication.

SUBSTANCE: disclosed is a method of transmitting measurement data by a cable-free telemetric system when drilling wells, involving encoding and transmitting information via a phase-shift keyed signal in form of a sequence of pulses, synchronising the signal and receiving the encoded information by a land receiver. One-time (initial) phase synchronisation of precision quartz-crystal oscillators of the transmitter of the bottom telemetric system and the land receiver is carried out by accumulating data on the transitioning of the signal through zero and one-time synchronisation of signals using a priori information on the bottom telemetric system at the current moment in time is also carried out. Prolonged stability of synchronisation of said oscillators is ensured by adjusting the phase of the quartz-crystal oscillator of the land receiver relative to the statistically determined transitioning through zero of the signal of the transmitter of the bottom telemetric system.

EFFECT: higher capacity of the communication channel and high noise-immunity thereof.

1 dwg

FIELD: oil and gas industry.

SUBSTANCE: system includes flexible tubing having a fibre optic conductor and a section with instruments. At that, fibre optic conductor is located in a cavity flush with outer surface of the section of flexible tubing equipped with instruments. Besides, the above cavity is curved. The system also includes a device for fixing the fibre optic conductor on the surface of the wall of flexible tubing, an adapter through which the above conductor passes to an internal fibre optic conductor, and a connecting coupling. The latter has the possibility of data transferring by means of contactless telemetry.

EFFECT: improving measurement efficiency of one or more parameters in the well along a certain zone of the well.

21 cl, 9 dwg

FIELD: electricity.

SUBSTANCE: method to transfer information from a well consists in the following: using a surface generator, electrical current is excited in a string of metal pipes, which generates electromagnetic field spreading in the rock of the well, which reaches the bottomhole area and creates the difference of potentials between the metal string and its isolated part. Receipt of information from the bottomhole is carried out depending on modulation of the voltage value required for stabilisation of the surface generator DC. The surface generator is a source of a stabilised DC. Besides, the surface generator is connected with one clamp to a surface part of the pipe string, and by the other one - to a grounded electrode that is remote from the well head. At the same time for transfer of information from the bottomhole the lower and upper parts of the string are closed or opened, changing the efficient value of conductivity between the grounding electrode of the current source and the metal string. When the key is closed, the specified efficient conductivity increases, and voltage on the current source clamps reduces and is recorded by a recording unit. By variation of the measured voltage the parameters of the drilled bed are decided.

EFFECT: increased reliability of information transfer from a bottomhole and expansion of its application area.

2 cl, 1 dwg

FIELD: measurement equipment.

SUBSTANCE: formation method of measurement data packages of a cable-free telemetric system during the well drilling involves coding of every four bits of information with a noise-like signal (NLS) with the length of 16 bits and information transfer by means of a phase-shift signal, packages of various types. The data measured in dynamics in the turbine drilling mode is transferred in S-O1-Z-O2-A-O3-"Г"-O4 packages consisting of synchronisation sending (S), diverter (O1), zenith (Z), diverter (O2), azimuth (A), diverter (O3), gamma background level ("Г"), diverter (O4). The data measured in dynamics in the rotary drilling mode is transferred in S-1-"Г"1-R1-"Г"2-R2-"Г"3 packages consisting of synchronisation sending (S), special NLS equal to one and serving for identification of the package type, gamma background level ("Г"1), formation resistance (R1), gamma background level ("Г"2), formation resistance (R2), and gamma background level ("Г"3). The data measured in statics is transferred with S-9-"Г"1-Z-R-A-"Г"2 packages consisting of synchronisation sending (S), special NLS equal to 9 and serving for identification of the packages type, gamma background level ("Г"1), zenith (Z), formation resistance (R), azimuth (A), and gamma background level ("Г"2).

EFFECT: increasing informativity of transferred parameters owing to increasing transfer frequency of logging parameters of gamma background and formation resistance.

4 cl

FIELD: oil and gas industry.

SUBSTANCE: device includes housing, electric motor, submersible pump with discharge end and intake device and ejector. According to invention device is equipped with housing that forms annular channel with the housing downwards discharge end and upwards ejector. Ejector is located in intake device and made as annular slot. At that ejector inlet nozzle is connected to discharge end of submersible pump through annular channel for the purpose of partial return of pumped oil. At ejector output, before the first pumping step, there is a mixing chamber providing possibility of gaseous phase dispersion and pressure increase.

EFFECT: possibility of increasing pump efficiency during operation with gas-containing mixture at increase of permitted gas content in mixture at the pump intake; possibility of periodical pumping-out of gas accumulated at small and even zero quantity of liquid phase.

3 cl, 2 dwg

FIELD: oil and gas industry.

SUBSTANCE: device contains a pump launched into casing string at pipe string with shank end underneath and connected to connecting tube; in the well there are two delivery channels, at that one channel is for oil delivery while the other one is for water delivery from stratum to the well. Channel inputs are located at different levels while outputs are directed to pump suction side. Shank end is equipped from outside with packer installed in casing string at the level of water-oil contact and radial holes of shank end are located higher than packer. At that below radial holes a hollow blind plug is inserted into shank end; connecting tube is inserted into the plug, at that tube can be moved along axis and fixed. However fixation of connecting tube in regard to shank end is made by split locking ring of circular section which is installed in inner groove of the hollow blind plug; this ring fixes the connecting tube in semicircular notches at outside surface of the tube. At that channel for oil delivery is formed by inner space of the casing string upwards packer, radial holes of the shank end and space between the shank end and connecting tube. Channel for water delivery is formed by inner space of the casing string downwards packer and inner space of the connecting tube. Inputs of both channels are located opposite perforated holes in water- and oil-bearing parts of stratum while outputs are directed to pump suction. Due to regulation of water and oil extraction the suggested device also allows preventing mixing of water and oil in process of their raising in the pipe string and producing of product that does not require subsequent separation into different phases; it also allows reducing probability of water-oil emulsion and paraffin deposition in result of fast transfer from water extraction to oil extraction.

EFFECT: ability of water and oil extraction regulation when level of water-oil contact changes in the well during operation process, producing product that does not require subsequent separation into different phases and probability of water-oil emulsion and paraffin deposition at inner surface of pipes.

3 dwg

FIELD: oil and gas industry.

SUBSTANCE: method includes packer installation above the production well bed, oil-water emulsion extraction from below-packer space by pump, descended at tube string, emulsion separation to oil and water in down-hole conditions, oil extraction from top part of above-packer annular space to oil pipeline, extraction of formation water and its pumping via water pipeline through injection wells into oil bed with undeveloped oil resources. Pump operation is provided in constant mode, oil-water emulsion is supplied through radial holes in tube string into above-packer annular space, where oil-water emulsion is separated. Water is extracted from above-packer annular space via subsidiary tube, the inlet of which is located below the level of water-oil contact, and its outlet is connected to the water pipeline fitted with flow metre. Oil extraction is additionally performed from tube string into oil pipeline, which is fitted with flow regulator and is connected to the subsidiary tube via bypass line, connected to the oil pipeline after flow regulator for water discharging into it at water pipeline repair works.

EFFECT: extension of scope of application due to the use of former production wells as well as actual watered production wells as water supply wells; efficiency increase due to elimination of pump station stops for pump station switching to oil displacement mode and for the time of water pipeline repair works.

1 ex, 1 dwg

FIELD: oil and gas industry.

SUBSTANCE: method includes use of de-emulsifying compound and pour point depressant (PPD). According to invention at bottom hole temperature up to 80°C both reagents are supplied together into pressure-actuated operating agent - gas. When bottom hole temperature exceeds 80°C, PPD is supplied to pressure-actuated operating agent and de-emulsifying compound is supplied into the product at wellhead. Note that water-soluble de-emulsifying compound is used for watered product of 40%, and for watered product of more than 60% there used is an oil-soluble de-emulsifying compound. Any of the said reagent types can be used in interval 40-60%.

EFFECT: increase of gaslift well operation efficiency via reduction of water-oil emulsion viscosity, obtaining non-hardening stream in well as well as in submerged pipeline due to high temperature use at bottom-hole and rational use of reagents depending upon the temperature at bottom-hole.

2 ex

FIELD: oil and gas industry.

SUBSTANCE: method provides for extraction of formation liquid by means of a bottom-hole pump from vertical production wells drilled so that a sump is formed. A cavity is created in lower part of a productive formation in each vertical production well. In addition, flat directional production wells are drilled, thus attaching the face of each flat directional well to the cavity of the corresponding production vertical well, and mouths of flat directional production wells are interconnected with atmosphere. Diameter of vertical production wells is larger than diameter of flat directional wells. Mouths of flat directional wells are located for example near mouths of neighbouring vertical production wells. Creation of the cavity is performed for example by water jet washing-out of rock by means of a special adapter with a side water jet nozzle, and filling of the cavity with filler is performed for example by gravel alluviation.

EFFECT: improving oil extraction from formations with high average number of permeable intervals and abnormally low formation pressure owing to enlarging the formation drainage zone and activation of formation liquid runoff by increasing the forces contributing to displacement of formation liquid.

4 cl, 3 tbl, 1 ex, 3 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: method of processing underground bed comprises injection of emulsion inverted solution in cased borehole cutting the bed to well killing. Said method comprises: oily continuous phase, nonoleaginous disperse phase and at least one bridging agent. formation contact with well killing solution and possibility for degradable material to degrade at least partially. Proposed method comprises: production of inverted emulsion for well killing including: oily continuous phase, nonoleaginous disperse phase and at least one bridging agent, injection of said solution in encased perforated borehole, production of filtration crust and its destruction to mallow the material to degrade. Proposed method comprises: production of inverted emulsion for well killing including: oily continuous phase, nonoleaginous disperse phase and at least one bridging agent. Placing the well killing solution in said borehole, formation of filtration crust and destruction of said crust whereat hydrolysis of degradable material destructs said crust.

EFFECT: higher efficiency, minimised bed damages.

25 cl, 2 tbl, 5 dwg

FIELD: oil and gas industry.

SUBSTANCE: method for optimising extraction from a well is proposed, in which an artificial lifting system in a well shaft is controlled, and multiple parameters of extraction on surface and in the shaft well are monitored. A well model with calculated data parameters is built. Then, measured data on working face and surface of the well is compared to the model data and reliability of the measured data is checked. After that, difference between measured data and modelled data is diagnosed, and operation of an artificial lifting mechanism is adjusted as per the above diagnostics results.

EFFECT: ensuring enlargement of analysis volume of a well and components of an extraction system for effective extraction optimisation as a whole.

FIELD: oil and gas industry.

SUBSTANCE: well is equipped bottom upwards with a tubing string ended with a packer, submerged pump, switch, two outer and inner annulus of the tubing string which are located concentrically, tubes with holes at the outer tubing string. The well is splitted over the productive stratum. The stratal product is delivered by the submerged pump in a cyclic mode "delivery-stop" from the productive stratum through the tubing string, the switch, tubular annulus between inner and outer tubing string, tubes and holes of tubes into tubular annulus between the production string and outer tubing string. Pressure is created and maintained in the upper pert of the well; it should not be less than oil degassing pressure and more than permissible pressure to the production string. Separation of the stratal product into oil and water is arranged in the upper part of the well. Completeness of separation is controlled by the duration of a half of the operation cycle of the submerged pump till stoppage and by the distance between switch and the tube with a hole. Oil is delivered to oil line. Water is supplied through the switch to inner tubing string and through the pipeline to an injection well by borehole-to-borehole water pumping and/or through tubular annulus between the production string and outer tubing string and tubing string with a packer to the stratum over the packer by borehole water pumping.

EFFECT: improvement of oil and water separation degree, increase in injection efficiency of separated water during borehole and borehole-to-borehole pumping of water.

1 ex, 1 dwg

FIELD: oil and gas industry.

SUBSTANCE: device contains a spherical body with at least one segment containing at least one section of throttle joints and one limiting. Stream is fed to the segment from the butt end, through side channels. Each input unit can be covered by a roller gate of the plug with thread which is input through the chamber body.

EFFECT: increasing oil recovery of the formation.

12 cl, 1 dwg

FIELD: oil and gas industry.

SUBSTANCE: method involves lowering to the well of a pipe string with a cable, control devices in the form of electric valves, pressure and temperature measuring sensors and with one or several packers isolating the borehole space. Sensors are used, the information from which is supplied to a measuring unit installed on the well head. Signals for opening and closing of control devices are supplied via the cable from the wellhead control unit. The product is lifted to the surface by means of a pump via inter-tube space. The well is built with a horizontal section passing in the formation with different permeability zones. Packers are installed in the horizontal section of the well, thus separating the formation zones with different permeability. The inter-tube space is isolated with a plug, above which there arranged one above another are upper and lower control devices arranged in a vertical shaft and equipped with measuring sensors. Zones with equal or similar permeability are interconnected with each other by being grouped in two flows interconnected with the borehore space and the input of the upper control device or the inter-tube space and the input of the lower control device. Outputs of control devices are interconnected with the pump inlet, and the value of opening of control devices is derived with frequency separation via one cable, via which parameters are picked up from measuring sensors, as per the readings of which the value of opening of each of the control devices is determined. Each control device is made in the form of an electric motor with a reduction gear, which are arranged in the housing, the rotating shaft of which is connected through a screw-nut connection to a pusher and a valve having the possibility of tight interaction with a seat, below which there arranged is a shell with an inlet in the form of channels, in which a compensating chamber with elastic walls is arranged, which is filled with lubricating liquid and interconnected with inner space of the pusher and sealed space located above the pusher.

EFFECT: enlarging manufacturing capabilities in wells with zones of different permeability, and reducing costs.

2 cl, 4 dwg

FIELD: oil and gas industry.

SUBSTANCE: needle valve for pressure gage contains a body (1) connected indirectly to rod (2) equipped with threaded seat (3) at one end. At that in the body (1) there is ball seal valve (10) of chevron-type, main bush (9). The latter one is connected to the body by means of a connecting element 12. Besides, the body (1) is connected by means of threaded joint to fastening element (5), which is connected by circular grooves and locking ring with rod (2). Besides body (1) is equipped with bleed-off valve (15).

EFFECT: improving accuracy of pressure gage readings, tightness, durability and reliability of design.

3 cl, 3 dwg

Up!