Casing annular space pressure control system

FIELD: oil and gas industry.

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

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

35 cl, 6 dwg

 

The invention relates to a method and device for controlling the tightness of the injection and observation wells in the production of oil and gas and, in particular, to a method and apparatus for precision control of pressure and/or temperature in one or more annular spaces of casing wells in natural occurrence without disturbing the integrity of the well or wellbore.

The present invention allows for improved control and understanding of any changes in the pressure/temperature in the annular space of the casing of the well, since the proposed method and the device allow to distinguish whether the change in pressure and temperature fluctuations of the process or the external environment or hazardous leakage of pressure from the well. Thus, the present invention provides improved risk management and safety well, as well as the environment, allowing in advance to take any action necessary to prevent dangerous events. This can be done throughout the life cycle of the well.

Control the tightness of oil and gas wells is an important issue in the oil industry. These issues arise due to the huge costs associated with the production and operation of all types of oil is of Quain, but also because of the risks associated with security issues and protection of the environment. In the present description oil well is called the well of any type, drilled and equipped for the development or storage of hydrocarbons from underground formations. When oil wells are classified as combined wells, storage, Supervisory, operational, or injection wells.

The management of oil wells and access to them is provided through the wellhead. Accordingly, handling of the wellhead equipment and its configuration in the prior art provide a natural target structure for control and pressure control in the set of annular spaces surrounding the operating tube or well. The present invention can be applied to any oil wells, located, for example, on land, on the platform or on the seabed. However, for simplicity and unambiguous understanding of the present invention it is described on the example of the application of the standard oil well with standard mouth.

Control the tightness of the well becomes more important and more complex with more active use of closed or the surrounding annular space (i.e. the annular space And the production string or trubor the water to assist in the development wells. Have in mind that the well design is such that the annular space And is used as a pipeline for gas supply for the artificial lift product from the well. In such applications, the near annular space (annular space)surrounding the production well, no longer acts as a barrier and/or design security feature in traditional or well-known oil wells. Currently the annular space And integrated as part and element of the technological process of system development of the modern oil wells. This, in turn, forces designers wells to make "active" barrier annular space of the borehole at one or more degrees outwardly from the casing (for example, in the annular space b or C and so on).

The annular spaces of oil wells as the active component of the system of technological process, as described above, requires the revision of the security and integrity of the entire wellbore. Previously, it was relatively easy to measure and control the pressure and temperature in the near annular space oil wells, because access to the annular space And could be obtained through a wall of the housing of the wellhead equipment or through under ESCO columns. The annular space In, on the other hand, is more complex because it is physically ends more deeply inside the wellhead equipment and access to it is blocked and securely suspension of the corresponding casing. In fact, in existing designs there is no easy or direct access to the outer annular space (i.e. the annular spaces b, C, D) without the use of tools that can impair the tightness. This can be done by piercing the wall "barrier" (i.e., the wellhead housing, the suspension of the casing for receiving hydraulic access to control the pressure in the free space by placing the known device temperature sensor or pressure.

There are many patents related to measuring the pressure in the annular space of the casing of the well. One such system is described in document US 6513596 B2. The described system is essentially illustrative and shows the control system data well using sensors placed in the outer annular space of the design of the casing of the well. The system uses a non-Intrusive approach for measuring pressure and other parameters within a set of annular spaces, allowing you to save hermetically shall be well. The system includes sensors, placed in the annular space, which interact with the poll system, located outside or inside of the wellhead equipment. The document confirms that the sensors needed energy and communications to perform their functions, and lists of alternative power sources and communication methods without providing solutions to actual problems in the real application. This method is not considered as already applied in any oil well or in actual operation.

The document US 3974690 illustrates a method and apparatus for measuring pressure in the annular space of the well. This method is mechanically complex, as it includes a movable element, operating in the mode of the differential pressure sensor. Measuring sensor side is open to the measurand (i.e. the pressure in the annular space), while the other side of the sensor is opened to pressurize the pressure chamber. The movable element moves and stops when the pressure chamber is equal to the pressure in the annular space. The method uses an electric control cable for excitation and readout signals of the provisions of the above item. Control cable hung with special means in the centre of the pillar, and from there deduce from the well.

In-p is pout, mobile sensors are undesirable for use in oil wells, because they can break and cause damage in the well. Secondly, the cable coming out of the production casing is not conducive to maintaining required integrity of the design and safety of the well. Based on this fact, it is difficult to imagine how such a system can be used in practice for continuous monitoring of the tightness of the oil well, so such a system can only be regarded as preliminary or temporary measure.

The third patent illustrates the approach using a hydraulic connection or means of access. In the document US 4887672 described a system in which use hydraulic clutch, drilled from the inside of the holes and the respective discharge channels to control the tightness of the well. The orientation of the coupling must be performed before installation of the mouth, this clutch can be damaged easily. In addition, each channel discharge is prone to leaks and increases the overall security risk of a well.

Another appropriate approach discussed in the document EP 1662673 A1. It describes the method includes the magnetic saturation of the casing of the well or pipeline to create a "window" for local control of the magnetic field of alternating current for excitation is Oia sensor, located outside the casing. The described principle is not realistic due to the relatively high power consumption required for magnetic saturation of the casing of the well. Furthermore, the method requires a uniform speed of the current in the saturable material, which, in turn, will require optimum contact (evenly distributed contact resistance across the open field) applied to the electrodes. Due to the combination of open electrodes and high currents such systems are subject to rapid deterioration by galvanic reactions (oxidation/corrosion) inside the sealed system well. Thus, the method is not applicable for constant pressure control.

In one aspect of the present invention proposes a method and device for controlling pressure in a multitude of annular spaces of casing strings in the well. In certain applications it is necessary to control pressure in the outer annular space between the casing strings in the well to ensure its safe operation. Traditionally, control is carried out only in the annular space between the production column and the inner column (operational casing). In some applications of modern methods of development wells using traditional ring is the new space (annular space) as a functional element of the system of the technological process. Accordingly, there are new legal requirements and the relocation of the traditional barrier performance of the casing and sealing the well outside. The present invention describes a non-Intrusive way to preserve the integrity of the well and at the same time contributing to its security.

The second aspect of the present invention is that the pressure control is able to predict the future profile of the pressure/temperature annular space as a function of the load change. Typically, the load changes caused by fluctuations of the process or the environment that, in turn, causes changes in the pressure inside the sealed system well. Such changes are not inherently dangerous, and their ability to recognize improves the safety assessment of the well. As a result, obtaining data about the process and the environment in real time in combination with measurements in situ are important advantage over the prior art in that the present invention allows the control system to detect and respond to potential problems before they occur. In addition, it may be formed remote host sensors from many different sensors evaluation, which is s important to assess the condition and integrity of many systems wells, under the pressure.

In accordance with one aspect of the present invention proposes a wireless sensor unit (wireless sensor unit (WSU). Block WSU is a non-Intrusive monitoring system, integrity of the well. Feature block WSU is that it contains a host of sensors (sensor package, SP), controlling the pressure and temperature without breaking barriers for sealing the annular space of the casing of the well. Site SP depends on the specific application and consists of a set of high-precision pressure sensors and temperature performed on quartz crystals, and it generates output data on pressure, temperature, and the gradients (i.e. changing) temperature. In turn, the SP node is associated with an electromagnetic transceiver (Electromagnetic Transceiver, ET), which includes electrical circuits for bidirectional communication and collection of energy (power harvesting). Node SP and electromagnetic transceiver ET installed or integrated into the outer perimeter section of non-magnetic casing (Non-Magnetic Casing Section, NMCS), which is part of the design of the casing of the well (barrier).

Another aspect of the present invention is the power supply of the sensor (Sensor Energizer Unit (SEU), which is usually part of the pipe is equipped with a borehole or attached thereto. Unit SEU konfigurera the Academy to accommodate the wireless sensor unit. Unit SEU consists of three main elements. First and most important element of the block SEU is an electromagnetic coil (Electromagnetic Armature, EA), the second adjustable core (Adjustable Mandrel, AM), and third - cable adapter (Cable Adaptor, CA). Electromagnetic coil provides a combination of power supply and communication lines for the block WSU. The main transmission of the electromagnetic winding is carried out using a low-frequency induction or electromagnetic field that is picked up and converted by the block WSU into electrical energy. For optimum efficiency the opposite block WSU to a regulated core is connected to the electromagnetic coil, which improves the ability to "fine tune" to optimize the efficiency of the unit WSU by means of vertical adjustment. To the electromagnetic coil is also attached cable adapter (SA)connected to the control cable coming from the outside of the well. The control cable is fixed on the pipe well equipped standard cable clamps, and exits the borehole through her mouth in accordance with the prior art. Typically, the control cable is a single conductor pipe electric cable (Tubing Electric Cable, TES), which provides the power for the unit SEU, and the relationship between the unit SEU and control means (i.e. means and, located outside the well).

The electromagnetic coil may be attached to a regulated core (AM), which provides the freedom of its vertical adjustment/positioning block WSU. Freedom of vertical adjustment after installation on the production string allows operators involved in its positioning in the exact position adjacent to the block WSU in the well, without complexity "explode" to use a tube equipped with a well or production casing in the well. Thus, the adjustable core has a dual purpose: first, it provides the holder, support, and/or a protective device for an electromagnetic winding, and secondly, provides vertical adjustment to two basic elements of the present invention (i.e. blocks WSU and SEU) had the correct location relative to each other.

Depending on the extent of risk assessment unit SEU can also include a host of sensors (SP), is analogous to a node of the sensor unit WSU to improve more complex assessment of the integrity of the system under pressure.

In accordance with one aspect of the present invention proposes a device for controlling the pressure outside the casing of the wellbore, comprising: a wireless sensor unit (WSU), located outside section and a non-magnetic casing, these block WSU includes a sensor device for measuring pressure and/or ambient temperature, and the unit WSU can be installed or positioned at any height of the wellbore, and the power unit WSU is carried out by collecting energy, where the frequency of the induction signal is in the range 10-1000 Hz for deep penetration through the non-magnetic casing; an internal power supply of the sensor (SEU), which is placed inside the casing of the wellbore and used to power the unit WSU and therefore, the block SEU mounted on the drill pipe or structure is equipped wells with pipe thread that allows you to adjust its height position, and the unit SEU converts the power to DC power supplied through the cable from the surface, in an alternating electromagnetic field, which provides power for the unit WSU located outside of the casing; when this blocks SEU and WSU uses electromagnetic modulation to provide data exchange between the two components.

Unit SEU can be placed at a height equal to the height of the outer block WSU. In addition, the sensor can be mounted near the wellhead or tree structure of the wellbore. In block WSU may have two or more sensors, with each sensor unit WSU can be placed is on the outside of the casing of the wellbore without breaching wells under the pressure.

The pressure sensors preferably measure one or more parameters annular space that is available to them. The sensors can branch from block WSU and to connect to a shared bundle of electric wires mounted on the outer side of the casing. The wiring harness can be a solid or stranded downhole cable (TEC).

The device may also include one or more windings harvest energy distributed over a given section of non-magnetic casing, the block WSU may include a secondary power source or connect to it. This source may be a battery or downhole generator.

In addition, the block SEU may optionally include one or more sensors for measuring the parameters inside the casing of the wellbore or pipe on which it is mounted. These sensors can be an integral part of SEU or branch from block SEU and can connect to a shared electrical wiring harness or can be connected in a combination of integrated sensor and branched sensors. Mentioned the wiring harness can be a solid or stranded downhole cable (TEC).

The optional sensors measure one or more of the following characteristics: pressure, temperature, volume flow, flow velocity, the direction of flow, turbidity, composition, oil level, the interface water-oil, density, salinity, radioactivity, substitution, vibration, pH, resistance, sand content, conductivity, or any combination thereof. They can also measure one or more of the following structural characteristics of the casing of the wellbore or pipe: shock, vibration, inclination, magnetic properties, electric properties, the position of the drilling device or the orientation of the device is of a different type, and characteristics of the stress and tension or any combination of them. They may also measure one or more characteristics of the annular space or uncased wells on the outer side of its trunk, the characteristics can be selected from the following: pressure, temperature, resistance, density, pH, electromagnetic and/or electric fields, radioactivity, salinity, sound, speed of sound, thermal conductivity and other chemical or physical characteristics.

The device may also include means for receiving a response to the environment, which can be selected from the following: the source of magnetic fields, electrical fields, sound waves, pressure, temperature, wave shear force, as well as other actuators or fulfill the performance communications part of the in-situ process control, thus, Executive member or the Executive part is used in relation to the reservoir for the implementation of any of the above measurements.

The device may also include one or more of the following: noise reduction in displacement settings, because of the technological process of the well or the environment; prediction and correction of measurements due to gradients induced by the environment or system process well, to ensure the correct control in real-time integrity of the well under pressure, and condition.

The present invention also proposes a method of controlling the pressure outside the casing of the wellbore, including:

the installation of the wireless sensor unit (WSU), which includes the sensor, on the outer side of the nonmagnetic section of the casing of the wellbore;

the installation of the internal power supply of the sensor (SEU) within the casing of the wellbore at a height equal to the height of the accommodation block WSU, located outside the wellbore, the block SEU is used for power supply WSU and connection with them;

the power unit WSU by gathering energy, the frequency of the induction signal is in the range 10-1000 Hz for deep penetration through the non-magnetic casing;

the transformation of the power supply is permanent current supplied in unit SEU cable from the surface, in an alternating electromagnetic field, which provides power for the unit WSU located outside the casing;

the use of electromagnetic modulation to provide data exchange between blocks SEU and WSU.

Optional and preferred technical features of the device in accordance with the previous description is applicable to the method of the present invention and will be described in more detail below.

The above and other technical features and advantages of the present invention will be understood by specialists from the detailed description and drawings. Refer to the drawings in which identical elements are denoted by the same numerals.

Figure 1 presents a schematic representation of a control system pressure in the annular space of the casing of the well in accordance with the present invention for use in the management and assessment of risks in many applications related to oil wells.

Figure 2 shows an enlarged schematic representation of one aspect, shown in figure 1, illustrating a wireless sensor unit (WSU).

Figure 3 shows an enlarged schematic illustration of another aspect, shown in figure 1, illustrating the power supply of the sensor (SEU).

Figure 4 shows a simplified electrical wiring in the systematic diagram of the system control pressure in accordance with the present invention.

Figure 5 presents a schematic representation similar to figure 1 illustrating the use of multiple sensors on each side of the casing of the wellbore.

Figure 6 presents a diagram illustrating the network of sensors, branches off from one node.

The present invention relates to control the tightness of the annular space of the casing of the well under pressure. Controlled annular space is usually a barrier that is closest to the operating system wells and employee in order to avoid leakage and to increase the safety of operation. In particular, wireless sensor unit (WSU) 1 in the present invention is part of the design of the casing of the well of the main operational barrier 2 wells. Section 20 of the casing (see figure 2) block WSU 1 is made of a nonmagnetic material and contains the node 10 sensors, as well as many of electromagnetic transponders (11a-f). For the purposes of the present invention, the host of sensors configured to measure and control the parameters of the annular space 3 outside the main barrier operating system wells, as shown in figure 1.

Space 3, shown in figure 1, often also called the annular space, and the block 1 WSU is usually located near and below ustawa the structure or housing 4. Mouth structure shown in figure 5, indicating the soil through which they drilled a well, and figure 6, indicating the wellbore. Unit 1 WSU receives power wirelessly using block 9 sensor power supply (SEU) by electromagnetic means, that in the field of electrical engineering is also called the "gathering power" (see number 100 figure 4). Block WSU equipped with control circuits that provide bidirectional communication unit SEU 9. The above link is also carried by electromagnetic means.

Figure 2 depicts the main elements of one of the components of the present invention, which define the configuration of the wireless sensor unit 1. Unit 1 WSU consists of node sensors (SP) 10, an electromagnetic transceiver (ET) 11a-f and section 20 of non-magnetic casing (NMCS). A more detailed functional diagram and wiring diagram of the unit WSU 1 shown in the right part of figure 4 by the dotted line.

Refer again to figure 1. The second component of the present invention is the block 9 sensor power supply (SEU). Unit SEU 9 shown in more detail in figure 3 and is normally installed on the core 91 and is attached to section 94 of the production string. In this example, the production column 94 has an external thread 93, but it may have an internal thread. Thread 93 allows you to regulate the th position of the block SEU 9 in height so that to the height of the unit SEU 9 in the well to closely match the height of the unit 1 WSU. This ensures proper communication and optimal collection efficiency energy (designation 100 figure 4).

Power and communications for the unit SEU provide pipeline through an electric cable (TEC) 97, which is fixed on the operating column 7, and conclusions 72 and 73, usually extending through the holder 71 of the column (see figure 1). Unit SEU 9 may also contain the node 95 of sensors, which, in principle, can be the same as the node 10 of the sensor unit 1 WSU, but can be configured to read the inner annular space 8. Generally, the internal annular space 8 experts call the annular space of A.

Figure 3 and 4 power block SEU 9 serves installed on the rig floor unit 101 borehole interface (Downhole Interface Unit (DIU) through the cable 97 TES. Cable TEC 97 provides a link towards the well and out between blocks DIU 101 and the SEU 9. Typically, this communication is done through signals superimposed on the power supply, as the cable TEC 97 is a single core cable. Cable TEC 97 terminates in block SEU 9 cable adapter 96. Nutrition guide inside through the core 91 and serves on the electromagnetic winding (EA) 92. Detailed illustration of the internal electronic functional the x elements and wiring is shown in figure 4 to the left of the dotted line.

If necessary, the node 95 sensors (SP) can be configured to provide more data to assess the tightness of the controlled annular space under pressure. Node 95 sensors may be similar to the node 10 of the sensor unit WSU, however, alternatively, it may be a sensor of any type capable of providing data to improve safety and risk assessment specific wells. For example, the sensor 95 may measure one or more of the following characteristics: pressure, temperature, flow volume, flow velocity, flow direction, turbidity, composition, oil level, the interface water-oil, density, salinity, radioactivity, substitution, vibration, pH, resistance, sand content, conductivity and other chemical and physical characteristics.

As noted above, the electromagnetic coil 92 and the node 95 of the sensors can be mounted on the core 91. The core 91 serves simultaneously as a holder and as a protection of the mentioned elements, and also allows adjustment to match the vertical position or height of the block 1 WSU. Adjustment range according to the present invention is usually 0-50 cm, for example 10-40 cm and 25-35 cm, but can be widened or narrowed depending on the requirements of the freedom correctly what about the spatial explode for installation. The core 91 and operational column 94 can be made of magnetic material.

Figure 4 shows a simplified electronic circuit according to the present invention for explanation of the specialists of the internal architecture and operation of the system. In accordance with one or more blocks of the SEU 9 can be connected with a cable 97 management. In this drawing it is illustrated with optional cable TEC 98, leading to additional blocks SEU indicated by the numeral 28.

In a multicomponent system (i.e. with two or more blocks SEU 9) all blocks SEU connected to the cable 97 in a parallel configuration. Due to the relatively high energy consumption, the system works in such a way that at each moment of time only one active block SEU.

The active state block SEU addressed during the initial run through commands issued by the DIU block 101 on the rig floor. When the power supply unit DIU actively addresses one of the blocks SEU 9 on the line and makes it the active node of the system. To switch to another unit SEU, block DIU simply removes power from the line to reset or resume. The next power supply can be addressed to another unit SEU. When using such a mode of operation each time the food is served only on one unit SEU, the system is capable of R is to somati large number of blocks SEU on line without a significant voltage drop in the cable due to high load.

100 energy reached by the correct vertical alignment unit SEU 9 on unit 1 WSU. As noted above, this adjustment is provided by means of an adjustable core 91. The second technical characteristic of the present invention is the use of section 20 of non-magnetic casing, which provides deep penetration of low-frequency (50-1000 Hz) electromagnetic fields induced electromagnetic coil 92 (EA), and accordingly makes it "visible" to the electromagnetic transceiver (ET) 11 unit 1 WSU. The efficiency of energy transfer is low due to non-ideal conditions inductive coupling, however, tests show that the achievable ratio of about 20:1, which is sufficient for operation of the sensor node with low consumption in accordance with the present invention.

Let us consider figure 4, where the block SEU 9 consists of a source 21 of the power supply that provides regulated DC for electronic functional components of the unit. Unit SEU is controlled by the internal controller 25. After a call to transition to the active state, the controller interprets the address and, if it is addressed, includes internal generator 27 discontinuous modulation (modulating chopper oscillator, MCO). Generator MCO converts electrical energy into alternating magnetic floor is through the electromagnetic coil 92. Induced field has a frequency that allows electromagnetic waves, which are then collected electromagnetic transceiver (ET) 11a-f unit 1 WSU, to spread into surrounding structures. Generator MCO also provides modulation data 22 that is transmitted between blocks SEU and WSU.

Unit SEU has the modem 23. The main purpose of the modem is read and transfer data from/on line 97 power. However, the data 22 on the input and output unit SEU buffered and interpreted by the internal controller 25. Quartz sensors (for example, to determine the pressure at 29 and a temperature of 30) these units are managed by the relevant generators 26, while the output frequency of each quartz sensor is a function of the measured value. The frequency of the sensor is measured by the signal processor 24 and continuously served in the input buffer of the controller 25.

As for block 1 WSU, its internal electronic functional elements equivalent to the elements of the block SEU 9, except for rectifying bridge 31. A rectifying bridge converts the AC current induced local electromagnetic field in a constant voltage/current to the internal power supply WSU 1. Used electromagnetic principle experts call a fee of 100 energy. For the purposes of the present invention block WSU 1 where the n high-precision sensors 29 pressure and 30 temperature. In principle, the block WSU 1 may include a sensor node, which can contain any type of sensor, for measuring a variety of measured parameters to improve risk assessment in relation to the tightness of the system well.

Figure 1-4 shows a system comprising either a single sensor within a block SEU or two sensors - one in the block SEU, and the second block WSU.

Figure 5 shows the system shown in figure 1 and expanded to include a larger number of sensors on each side of the casing of the wellbore. For similar functional elements used the same notations as in figure 1-4. On the inner side branches, for example, sensors 95A, 95b and C from block SEU, and on the outer side branches, for example, additional sensors 10A, 10b, 10C from block WSU.

Figure 6 presents the corresponding diagram illustrating multiple sensors, networked and managed by a single node, and illustrating the cascading of sensors on both sides of the casing of the wellbore. Figure 6 shows the sensors that measure parameters uncased borehole, for example pressure, 29, 30, the resistance 32 and 33 of the partition phase oil/water.

1. Device for controlling the pressure outside the casing (2) of the wellbore, including
the wireless sensor unit (WSU) (1), located Sarug the section (20) non-magnetic casing and including a sensor (10) for measuring pressure and/or temperature of the environment, the block WSU (1) can be installed or positioned at any height of the trunk (6) wells, and the power unit WSU (1) is carried out using an Assembly (100) of energy, the frequency of the induction signal is in the range 10-1000 Hz for deep penetration through the non-magnetic casing (20);
internal power supply of the sensor (SEU) (9)placed inside the casing (2) of the wellbore and used to power the unit WSU (1) and communication (100) with him, and the unit SEU (9) mounted on the drill pipe or structures equipped with the well through a pipe (7)having a thread (93), which allows you to adjust its height position, and the unit SEU (9) converts the power to DC power supplied through the cable from the surface, in an alternating electromagnetic field (100), supplying power to block WSU (1)located outside the casing (2);
when this blocks SEU (9) and WSU (1) use of electromagnetic modulation to provide data exchange between the two components.

2. The device according to claim 1, in which the unit SEU (9) configured to be located at a height equal to the height of the outer block WSU (1).

3. The device according to claim 1 or 2, wherein the sensor (10) is installed near the wellhead or tree structure of the wellbore.

4. The device according to claim 1 or 2, in which there are two or bleedingcool (10) in block WSU (1).

5. The device according to claim 4, in which all sensors (10A, b, C) unit WCU (10) are located on the outer side of the casing of the wellbore without breaching the well under pressure.

6. The device according to claim 1 or 2, in which the pressure sensors (10A, b, C) measuring one or more parameters annular space (3, 8), which is available to them.

7. The device according to claim 1 or 2, in which the sensors (10) branches from block WSU (1) and connected to a common harness (97) electric wires mounted on the outer side of the casing (2).

8. The device according to claim 7, in which the harness (97) wire is a single conductor or multi-conductor downhole cable (TEC).

9. The device according to claim 1 or 2, comprising one or more windings (11a-f) harvest energy distributed over a given section of non-magnetic casing (2).

10. The device according to claim 1 or 2, in which the block WSU (1) includes a secondary power source or connected to it.

11. The device according to claim 10, in which the mentioned secondary energy source selected from the following: battery or downhole generator.

12. The device according to claim 1 or 2, in which the unit SEU (9) includes one or more sensors (95) for measuring the parameters inside the casing (2) of the wellbore or pipe (7), on which he is assigned.

13. The device according to item 12, in which the sensors (95) are an integral part of BC is ka SEU (9) or branches from block SEU (9) and connected to a common harness (97) electrical wires or represent a combination of integrated sensor and branched sensors.

14. The device according to item 13, in which the aforementioned harness (97) wire is a single conductor or multi-conductor downhole cable (TEC).

15. The device according to claim 1 or 2, in which the sensors measure one or more of the following characteristics: pressure, temperature, flow volume, flow velocity, flow direction, turbidity, composition, oil level, the interface water-oil, density, salinity, radioactivity, substitution, vibration, pH, resistance, sand content, conductivity, or any combination thereof.

16. The device according to claim 1 or 2, in which the sensors measure one or more of the following structural characteristics of the casing of the wellbore or pipe: shock, vibration, inclination angle wells, magnetic properties, electric properties, the position of the drilling device or the orientation of the device is of a different type, and characteristics of the stress and tension or any combination of them.

17. The device according to claim 1 or 2, in which the sensor measures one or more characteristics of the annular space or uncased wells on the outer side of the wellbore, the characteristics can be selected from the following: pressure, temperature, resistance, density, pH, electromagnetic and/or electric fields, radioactivity, salinity, sound, speed of sound, Talipova the face, as well as other chemical or physical characteristics.

18. The device according to claim 1 or 2, comprising means for receiving a response from the environment, and these tools can be selected from the following: the source of magnetic fields, electrical fields, sound waves, pressure, temperature, wave shear force and other Executive members or the Executive part of the in-situ process control, the Executive member or the Executive part is used in relation to the reservoir to support any of the above measurements.

19. The device according to claim 1 or 2, comprising one or more of the following: noise reduction in the offset parameters, the generated process well or the environment; prediction and correction of measurements due to gradients induced by the environment or system process well, to ensure the correct control in real-time integrity of the well and its status.

20. The method of controlling the pressure outside the casing (2) of the wellbore, including:
the installation of the wireless unit (1) sensor (WSU), comprising a sensor (10), on the outer side of the nonmagnetic section of the casing (20) of the wellbore;
installation of indoor unit (9) sensor power supply (SEU) within the casing colon is s (2) wellbore at a height, equal to the height of the block WSU (1)placed on the outside of the casing of the wellbore, the block SEU (9) is used for power supply WSU (1) and communication (100);
the power unit WSU (1) using the Assembly (100) of energy, the frequency of the induction signal is in the range 10-1000 Hz for deep penetration through the non-magnetic casing (20);
the power conversion DC power supplied to the unit SEU (9) cable (97) from the surface, in an alternating electromagnetic field (100)that provides power for the unit WSU (1)located outside the casing (2);
the use of electromagnetic modulation to provide data exchange between blocks SEU (9) and WSU (1).

21. The method according to claim 20, in which all sensors (10A, b, C) unit WCU (1) fix for permanent placement on the outside of the casing of the wellbore without breaching the well or barrier.

22. The method according to item 21, in which one or more pressure sensors (10A, b, C) measuring one or more parameters annular space that is available to them.

23. The method according to any of PP-22, in which the sensors (10) are not part of the block WSU (1), and were branched and connected to a common harness (97) electric wires mounted on the outer side of the casing (2).

24. The method according to item 23, in which the harness (97) wires represents the od of Ogilvy or stranded downhole cable (TEC).

25. The method according to paragraph 24, in which the sensors (10A, b, C) block WSU (1) are part of the sealed system of the wellbore (spray system) and sent to the external or outer side of the system casing of the wellbore or cemented to the external or outer side of the casing of the well.

26. The method according to any of PP-22, in which
one or more windings (11a-f) harvest energy distributed over a given section of non-magnetic casing (2);
mentioned section or strip (20) with non-magnetic windings of the casing provides the necessary security clearance for equipping a borehole or separation system during the descent of the drill pipe (suspension columns) in the mouth or tree wells.

27. The method according to any of PP-22, in which the block WSU (1) includes a secondary power source or connected to it.

28. The method according to item 27, which referred to the secondary energy source is selected from a battery or downhole generator to provide additional power required to support the collection of energy.

29. The method according to any of PP-22, in which the unit SEU (9) has at least one sensor (95) for measuring the parameters inside the casing (2) of the wellbore or pipe (7), on which he is assigned.

30. The method according to clause 29, in which the sensors (95) are an integral part of the unit SEU (9) or branches from block SEU (9) and connected to the ENES to a common harness (97) electrical wires or represent a combination of integrated sensor and branched sensors.

31. The method according to any of PP-22, in which the sensors measure one or more of the following characteristics: pressure, temperature, flow volume, flow velocity, flow direction, turbidity, composition, oil level, the interface water-oil, density, salinity, radioactivity, substitution, vibration, pH, resistance, sand content, conductivity, or any combination thereof.

32. The method according to any of PP-22, in which the sensors measure one or more of the following structural characteristics of the casing of the wellbore or pipe: shock, vibration, inclination, magnetic properties, electric properties, the position of the drilling device or the orientation of the device is of a different type, and characteristics of the stress and tension.

33. The method according to any of PP-22, in which the sensor measures one or more characteristics of the annular space or uncased wells on the outer side of the casing of the wellbore, and these characteristics can be selected from the following: pressure, temperature, resistance, density, pH, electromagnetic and/or electric fields, radioactivity, salinity, sound, speed of sound, thermal conductivity and other chemical and physical characteristics.

34. The method according to any of PP-22, which receive the response from the environment is by using one or more of the following tools: magnetic fields, electrical fields, sound waves, pressure, temperature, wave shear force and other Executive members or the Executive part of the in-situ process control, the Executive member or the Executive part is used in relation to the reservoir to support any of the above measurements.

35. The method according to any of PP-22, including one or more of the following: noise reduction in the offset parameters, the generated process well or the environment; prediction and correction of measurements due to gradients induced by the environment or system process well, to ensure the correct control in real-time integrity of the well and its status.



 

Same patents:

FIELD: oil and gas industry.

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

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

3 tbl

FIELD: electricity.

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

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

3 cl, 7 dwg

FIELD: oil and gas industry.

SUBSTANCE: suggested invention relates to the filed of directional well drilling, in particular, to methods of control for directional drilling. The invention suggests the method for drilling trajectory control for the second well passing in direct vicinity to the first well, which includes passing of the first electrode connected to the first conducting wire through the casing string; placement of the return grounded electrode in the surface soil; generation of time-dependent electric current in the first conducting wire and the first electrode and the second conducting wire passing towards the return grounded electrode; formation of an electromagnetic field around the casing string of the first well induced by passing of time-dependent electric current in the first conducting wire; drilling of the second well against the drilling trajectory parallel to the first well; measurement of the electromagnetic field formed around the casing string of the first well from the drilling rig in the second well; and control of the second well trajectory with use of the measured electromagnetic field. At that the first electrode passes to an uncased borehole section, beyond the farthest end of the casing string so that the first conducting wire passes along the whole length of the casing string in the first well. Besides, distance between the first electrode and the casing string end should be sufficient for prevention of current passing from the first electrode upwards, through the casing string of the first well towards the return grounded electrode.

EFFECT: improving accuracy of the drilling trajectory control and levelling of one well in regard to another well.

10 cl, 7 dwg

FIELD: mining.

SUBSTANCE: method consists in irradiation of rocks by fast neutron flow, radial probing of gas recovery reservoir by multi-probe modification of neutron method and/or complex of different-depth neutron methods and registration of data as well-logging records. Note here that measurement results are compared to reveal temporary cavity from availability on inversion in probe depth readings compared to larger-depth readings describing given gas recovery reservoir.

EFFECT: higher reliability and efficiency of detection.

7 dwg

FIELD: oil and gas industry.

SUBSTANCE: invention is related to survey of wells having large horizontal wellbores and it can be applied for delivery of tools. The device contains a logging cable with a propulsor made of a set of weights and the tool fixed at the end of the logging cable. The logging cable has a diameter as low as practicable in conditions of its breaking strength. Weights of the propulsor are made as balls, ellipsoids or short cylinders with spherical butt-ends having axial openings provided that weight move freely in regard to the logging cable axis. Weights of the propulsor are made with a diameter as big as practicable in conditions of their free movement in the well.

EFFECT: technical result lies in increase of transportation length (depth) for survey tools to horizontal wellbores up to 1000 m and more, reduction of friction against pipe walls, improvement in reliability and accident-free operation of the device.

4 cl, 2 dwg

FIELD: oil and gas industry.

SUBSTANCE: method envisages running-in of the flow string to the well and injection of the working fluid to pipes with measurement of its flow rate and an injection pressure at the well head. Before running-in the flow string is equipped with a multi-set packer with a liner and at running-in of the flow string the packer is set over the roof of the first production interval in the direction of the horizontal well (HW) drilling. The injection pressure for the working fluid is recorded at the well head when it stabilises, then the parker is broken and the flow string is run in further and the parker is set over the roof of the next production interval in the direction of the HW drilling. Then the working fluid is injected again. When the well-head injection pressure stabilises it is maintained equal to the injection pressure for the previous survey and the flow rate of the working fluid is recorded; at that breaking of the packer, running-in of the flow string, setting of the packer over roofs production intervals is repeated several times depending on quantity of production intervals in the horizontal well. At that the injection pressure of the working fluid during each survey is maintained constant and equal to the injection pressure recorded at the first packer setting over the roof of the first production interval in the direction of the HW drilling, then on the basis of recorded flow rate of the working fluid it is necessary to calculate quantity of the fluid absorbed by each production interval per time unit.

EFFECT: receipt of accurate data to issue a quantitative injectivity profile for hot horizontal wells.

2 cl, 1 ex, 3 dwg

Downhole modulator // 2515624

FIELD: oil and gas industry.

SUBSTANCE: group of inventions relates to a downhole modulator intended for use in a well. The device intended for the well contains an elongated body of the tool, expansible drill rods and a flexible valve membrane. The expansible drill rods are installed on the body so that they can be opened or closed. The membrane is fixed to the expansible drill rods; it is made so that it can slide in between folded and unfolded positions. The valve membrane contains the first convergent section with the first end of the first diameter and the second end of the second diameter. The first diameter is bigger than the second diameter and the inner well diameter. The first convergent section is connected to the expansible drill rods so that a part of the valve membrane is born against the well walls between the first and second diameters. The valve membrane is a tube and the diameter of its one end exceeds the biggest diameter to be sealed. The diameter of the second membrane end is less of the least diameter to be sealed. The above device intended for use in the well can be included into a modulator which beyond this device contains a valve for fluid pressure modulation in the filled well.

EFFECT: eliminating need of modulator being built-in into the well structure as well as elimination of need in a pump or a nozzle.

7 cl, 13 dwg

FIELD: oil and gas industry.

SUBSTANCE: method is implemented with means of emission source introduction, the source is capable to light the production string which is made with one section of transparent material and graduation lines marked at it, and with photographic registration and recording of panoramic images to the memory of the data processing unit. Measurements and photographic registration of experimental results are made in the synchronous mode.

EFFECT: providing observation of quantitative changes and improvement of visualisation quality for processes occurring in space and height of the production string and thus improvement in accuracy of results for gas-hydrodynamic experiments and reduction in time for their analysis.

6 cl, 2 dwg

FIELD: oil and gas industry.

SUBSTANCE: invention is related to oil industry and namely to monitoring and control for oil producer. The method for monitoring and control for oil producer with control of submersible pump parameters envisages monitoring of gas-liquid column parameters in the well in the area of submersible pump. To this end sensors are installed at the production string near the submersible pump. Results of measurements are delivered to the surface, processed and used for control of the submersible pump during oil recovery. At that monitoring of gas-liquid column parameters in the well is carried out at different levels, including position of dynamic level and its distance up to the submersible pump. The sensors are located at several fixed levels of the production string. Solid state batteries for self-sustained power supply are planned for installation at the production string. These capabilities and results are used for control of submersible pump capacity in order to maintain depression and parameters of gas-liquid column in the well corresponding to the balance between production rate of the formation or formations and recovery rate from the well at maximum permitted capacity of the pump.

EFFECT: improving production rate, oil recovery factor from the formation or several formations drained by the well due to direct measurement of gas-liquid column parameters at different levels, control of the submersible pump capacity and recovery rate considering the most favourable conditions for oil recovery.

13 cl, 2 dwg

FIELD: oil and gas industry.

SUBSTANCE: invention suggests procedure for survey of the multi-hole horizontal well that includes stages of bottomhole apparatus running-in to the well, performance of hydrodynamic research and removal of a geophysical tool from the multi-hole horizontal well. At that, before bottomhole apparatus running-in, at the head of the multi-hole horizontal well a hydraulic whipstock with drill out breakable cap, metering orifice and fixing breaking pin is installed at the lower end of the pipe string. The pipe string with the hydraulic whipstock is run in with simultaneous washing up to space of the surveyed side-tracking. Herewith in process of running-in the pipe string is equipped with kick-off valves. Then excess hydraulic pressure is created in the pipe string and the string is run in into the surveyed offshoot and excess pressure in the pipe string is increased till the breaking pin is destructed and the breakable cap is disconnected from the hydraulic whipstock. Then at the well head the bottomhole apparatus is connected to a rigid cable and the apparatus is run in into the pipe string until it leaves the string and appears in the offshoot. Thereafter fluid influx is stimulated from the stratum by gas injection to tubing-casing annulus through kick-off valves and hydrodynamic research is carried out in the surveyed offshoot by the bottomhole apparatus pushing up to the bottomhole. After hydrodynamic research the rigid cable with bottomhole apparatus from the pipe string and the pipe string with hydraulic whipstock are removed in sequence.

EFFECT: improving accuracy and efficiency of hydrodynamic research in offshoots of the multi-hole horizontal well.

2 dwg

FIELD: mining industry.

SUBSTANCE: invention can be used in case of gas-lift operation of wells equipped by free piston-type installations. Invention envisages stopping well, connecting tube space and annular space in wellhead, recording bottom zone and wellhead pressures in tube and annular spaces, and computing well operation parameters using inflow curve plotted according to differences of bottom zone and wellhead pressures. Volume of produced fluid is found from potential output of formation and from condition of output of free piston. When comparing these volumes, parameters of well are computed in the base of minimum volume value.

EFFECT: optimized well operation.

2 dwg

FIELD: oil and gas extractive industry.

SUBSTANCE: device has body placed in body of stream pump and has locking valve and axial channel for logging cable with fixed logging device. Device also has discharge valve. Device body has ports in middle portion, which connect middle hollow portion of device to displacement chamber for stream pump. In upper and lower portions of body of device upper and lower compactors are placed, limited by support elements on each side of the latter, respectively. Locking valve is mounted in lower portion of device and mated with inner space of tubing string and logging device. Axial channels of valves are eccentric and parallel to first channel of device, while discharge valve is provided with rod with its end prominent relatively to body of device.

EFFECT: broader functional capabilities, higher reliability.

4 dwg

FIELD: engineering investigations in building, particularly devices for determining deformation and strength properties of ground in well.

SUBSTANCE: device comprises probe (working tip), control-rod, pipeline, communication line, loading jig and measuring station. Probe includes hollow cylindrical body with bottom and cap filled with working liquid, elastic shell sealed from body bottom and top. Formed in non-fixed elastic shell area are perforations. Piston with rod is installed in upper part of hollow body above working liquid. Rod passes through cap in sealed manner. Rod is connected with control rod so that piston may move in axial direction. Formed above piston is cavity connected to pipeline. Hollow body has bottom in which air-tight plug is installed. Measuring device is made as linear piston displacement transducer. Through orifices are formed in hollow body wall near body bottom. Arranged from body outside are vertical or inclined grooves aligned with through orifices by lower ends thereof. Air-tight plug is provided with adjustable rest for restricting piston stroke.

EFFECT: simplified structure of probe and measuring devices, increased operational reliability and improved validity of obtained data.

2 cl, 1 dwg

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes performing a test pumping of liquid waste into absorbing well before operational pumping, while changing flow step-by-step. From equation of absorption base hydrodynamic parameters are determined for calculation of predicted coefficients of operation characteristics of absorbing well and reserve well. During operational pumping of liquid waste together with thermometry along absorbing well shaft, registration of actual pressures and flow on pump devices, actual pressures on mouth in tubing pipes of absorbing well, actual pressures on face are additionally registered in absorbing well as well as pressures on mouth in behind-pipe space, actual loss at mouth in behind-pipe space, actual loss of waste on mouth, actual positions of face well, upper and lower limits of absorption range from well mouth. In reserve well actual pressures on face are registered, as well as actual positions of liquid level from reserve well mouth, upper and lower limits of absorption range. Prediction coefficients are compared for operation characteristics of absorbing well and reserve well to actual coefficients. 9 conditions of hydrodynamic bed conditions at reserve well and absorbing well are considered during pumping of waste. Specific actions of operator on each condition are described.

EFFECT: higher reliability and trustworthiness.

1 ex

FIELD: geophysics.

SUBSTANCE: method includes lowering protective container to the well to portion of intensive curvature of shaft, which container is fixed at end of drilling pipes, lowering of geophysical device into protective container on lower portion of logging cable, delivery of protective container with geophysical device to pit-face by consecutive extending of drilling pipes column, lowering of upper portion of logging cable through remote-controlled compactor of logging cable fixed on branch of swivel, into drilling pipes, until electric contact to free end of lower portion of logging cable via detachable connecting sleeve, geophysical examining of shaft during raising of geophysical device together with drilling pipes with appropriate connection-disconnection of fixing ends of lower and upper portions of logging cable when screwing away each following drill stand. When examining wells having extensive steeply slanted portion of well shaft with zenith angle of 50-90, where lowering of upper portion of logging cable to electrical contact with free end of lower portion of logging cable via detachable connecting sleeve under its own weight is difficult due to friction at drilling column wall, forced lowering of detachable connecting sleeve is performed by feeding washing liquid under pressure into drilling pipes and concurrent adjustment of pressure in chamber of remote-controlled compactor of logging cable. Pressure in chamber of remote-controlled logging cable compactor is achieved to be close to pressure of washing liquid in drilling pipes, to provide for optimal speed of cable lowering and its pressurization, and after connection of detachable connecting sleeve to lower portion of logging cable during raising and lowering of drilling pipes, examinations of well are performed.

EFFECT: higher efficiency.

1 dwg

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes examination of exploring, product or force well, drilled in oil or gas saturated bed, in two stages. At first stage water is forced and water loss is measured. At second stage bed fluid is extracted and debits are measured on basis of oil or gas and water, and at both stages pit-face pressure is measured. On basis of measured parameters water level in production is determined, and volumes of extracted and forced water. Type of carbonate collector is determined on basis of dynamics of change of pit pressure at first and second research stages and change of relation of collected volume of extracted water to total volume of forced water during second stage, in time. For better identification of purely cracked and porous collector types, sampling and laboratory research of productive interval core is additionally performed, and results are taken in consideration during identification of carbonate collector type.

EFFECT: higher reliability.

2 cl, 6 dwg, 1 ex

FIELD: oil and gas extractive industry.

SUBSTANCE: device has measuring tank and tachometer generator and pressure and temperature sensors on it. It is mounted at distance of one tubing pipe from extracting pump, where pressure is higher than saturation pressure, i.e. in one-phase liquid flow, and serves as connecting sleeve. At distance of two tubing pipes from deep station in connection sleeve additionally mounted is sensor of liquid hydrostatic pressure. Measurement of base parameters characterizing production of oil and gas product wells, is performed directly in the well close to position of extracting pump. Device allows to perform systematical measurements of product parameters individually for each product well at all stages of deposit extraction. Use of deep stations for measuring parameters of oil and gas wells product excludes use of expensive and complicated switching execution mechanisms of automated group measuring plants.

EFFECT: higher efficiency.

1 dwg

FIELD: oil and gas extractive industry.

SUBSTANCE: during recording of pressure change pressure is measured at mouth at tubing column entrance and in inter-tubular space. Recording of pressure change is performed on basis of pressures comparison before and after stopping of well on basis of speed of pressure fall at mouth and in inter-tubular space after stopping of operation well and on basis of pressures comparison before and after well launch for forcing on basis of speed of pressure increase at mouth and in inter-tubular space after well launch. As criterion of pressurization estimation a calculated value of liquid flow, which enters and exits inter-tubular well space is taken.

EFFECT: higher trustworthiness.

1 ex

FIELD: geophysics.

SUBSTANCE: method includes measuring amplitudes of longitudinal acoustic wave on two working emitted frequencies of signal along casing column within given range. Amplitudes of longitudinal wave of acoustic signal are recorded along column at two frequencies (high Ahf and low Alf) and on basis of relation of these values, normalized by maximal values at portion of non-cemented column Avr (Ahf/Avr and Alf/Avr), separation of cementation defects by major types is performed (ring space, volumetric defect, mixed defect) and values of their openness are measured.

EFFECT: higher trustworthiness and higher precision.

2 dwg

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes lowering equipment into well and performing analysis during extraction of oil from oil beds. In accordance to invention after raising down-pumping equipment from the well liquid is replaced with degassed liquid, and research is performed during pumping in of degassed liquid into oil beds and extraction of degassed oil from oil beds, at the same time pumping is performed using exhaust gases under high pressure from moving compressor, and extraction of degassed oil - by letting exhaust gases out of the well. During that on basis of share of oil beds in total debit of product and extraction and on basis of face pressures during extraction and removal bed pressures of oil beds are determined together with their productiveness coefficient.

EFFECT: higher reliability and precision.

1 ex

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