Methods, systems and device for test on flexible tubing string

FIELD: engines and pumps.

SUBSTANCE: method involves introduction of common flexible tubing string to the well bore with annular space formed around flexible tubing string; activation of the device for separation of zones for isolation at least of one well bore zone; direction of test fluid medium to well bore through flexible tubing string to location place above the aforesaid zone; removal of outlet fluid medium from isolated zone and test fluid medium from flexible tubing string through annular space; measurement of characteristic of flow rate and pressure of outlet fluid medium during discharge.

EFFECT: isolation and test of separate zones without removing operating tubing string.

20 cl, 15 dwg

 

Scope

The present invention relates, in General, to the field of testing of formations bearing hydrocarbons, and, in particular, to methods, systems and devices useful for such operations.

The level of technology

The scope of flexible tubing has increased since its introduction in the oil industry in the 1960's. Its ability to pass through the pipe end and the variety of tools and technologies that can be used in conjunction with it, make its application very versatile, and this versatility is the basis of the present invention. Recent advances in flexible tubing pipe allow for operational management of downhole equipment, data measurement and isolation of the individual zones in the reservoir.

A typical device on the basis of flexible tubing includes ground equipment discharge column flexible tubing, wound on a bobbin, the method of descent flexible tubing in the wellbore and its rise from thence, and ground control device at the wellhead. During the coiling process flexible tubing undergoes plastic deformation when it comes off the reel and straightens injector for lowering into the well. Flexible tubing extends slightly under the action of differential pressure.

One typical way to test and assessed the Oia reservoir is a reservoir test on the pipe. Another way is a cable test. To optimize production and collector design the necessary information about the boundaries, the upper layer and reservoir permeability. Problems arise owing to the mixed stream.

Unfortunately, a formation test on the pipe requires the removal of existing elements of the completion and includes the cost of the installation software to move the individual sections of drill pipe. A formation test pipe also is not based on the operational data collection during the operation test. Cable test involves the need to plug the well for the transaction instrument cable that is undesirable, and the short interval that can be tested, it is often not enough.

There are a number of patents disclosing test collector using concentric flexible tubing. The produced fluid is returned to the inner layer and the fluid control hole is blown in the outermost layer of the concentric tubing. On the surface it is necessary to have a complex arrangement of valves and flow meters to maintain well control, when the formation fluid is diverted to ground technological equipment. The weight and cost of concentric flexible tubing limits its commercial application.

Still needed is a means and apparatus for testing and evaluation collectors without the involvement of existing equipment completion of the wellbore. Also the necessary methods and apparatus for testing and evaluation of individual zones in the reservoir, including the testing of those areas through which fluid normally does not flow in the absence of mechanized production. Required methods and apparatus that provides stable value of hydrostatic pressure in the area of the collector, as well as methods and apparatus for reliable moving formation fluid from the inside of the flexible tubing into the annular space around the flexible tubing at the same point above the column. You must also valve device on the ground or in other location between the surface and the base coil of flexible tubing, and the required data transfer valve device to determine what happens on or near the valve device.

The invention

Variant implementation of the present invention provides a method of testing a multi-zoned manifold when the flow of formation fluid from the wellbore. The method comprises the following steps: descent flexible tubing in the wellbore; activating device for separation zones to isolate at least one zone; providing a leak of the fluid from the isolated zone; measuring downhole flow and pressure of fluid from the isolated zone.

Another variant of implementation of the present invention provides for a method is spymania multispectral collector when the flow of formation fluid from the wellbore. In this embodiment, the method comprises the following steps: descent flexible tubing in the wellbore; setting the first isolation device to prevent leakage of reservoir fluid to the surface; activating the device for separation zones below the first isolation device for isolating the first zone; providing a leak of the fluid from the first zone; measuring downhole flow and pressure of fluid from the first zone; diverting fluid flow from the first zone in the annular space above the first insulating device.

Another variant implementation of the present invention provides a device for measuring formation fluid when flowing from the wellbore. The device comprises a flexible tubing, a dual system of swelling packers to isolate the area of the collector, and the dual system is transferred and posted a flexible tubing, the valve system ground control, which allows fluid pumped from the surface to flow into the annular space of the wellbore above the dual system of packers and in an area isolated dual system of packers, and allows fluid from the isolated zone of the reservoir to flow into the annular space above the dual system of the packers, and a measuring device for measuring the flow rate of the fluid tech is the future of the zone sandbox.

Various aspects of the invention and their combinations is clear from the following brief description of the drawings detailed description of the invention and claims.

Brief description of drawings

The way you can achieve the purposes of the invention and other desirable characteristics disclosed in the following description with reference to the accompanying drawings, which depict the following:

figure 1 depicts the scheme of the known device on the basis of flexible tubing used for processing operations of the well.

2 is a diagram of a known device for testing seam on the pipe used for processing operations of the well.

figure 3 - diagram of the known device cable tests used for the evaluation of reservoir;

4 is a diagram of the known operations of logging in production well used for testing of the collector, which allows you to return the hydrocarbons to the surface outside of the coiled tubing, artificial gas lift or without him;

5 is a diagram of the improvements of the known device shown in figure 4;

6 is a schematic side view, partially in section, of a communication system that uses a beam of optical fibers within a metal tube inserted into the coiled tubing, which transmit data, but not energy;

Fig.7 is a diagram of the device according to the invention, allowing R is sdelat coiled connector into two parts and component inserted between them;

Fig diagram of coiled testing system according to the invention, having a valve to drain the fluid, located between the surface and the base of the flexible tubing, downhole component with insulation and sensors, which mixes the fluid from the test zone with the fluid medium from the area above the test zone;

Fig.9 is a diagram of coiled test device according to the invention, having a valve to drain the fluid, located between the surface and the base of the flexible tubing and downhole component with valves and sensors for testing manifold, and located within a single system completion with gas lift and without him, which does not confuse the fluid from the zone of interest, with the fluid medium from other areas;

figure 10 - diagram of coiled test device according to the invention, having a valve to drain the fluid, located between the surface and the base of the flexible tubing, and plus downhole component with valves and sensors for testing manifold illustrating a test system from production tubing;

11 diagram of the test device according to the invention, which eliminates the need for intermediate discharge section, instead of which is provided by the device downhole sensors together is the communication system, capable of transmitting downhole data in real time during the test;

Fig diagram of the device according to the invention, capable of transmitting the data flow on the surface, the stream of produced fluid is diverted into the inner channel in the layout of the bottom of the drill string, and a flow meter based on the Venturi, and the data flow are transmitted to the surface; and

Fig diagram of the test method according to the invention, comprising the steps of descent of coiled tubing in the wellbore, providing isolation zones and selection of reservoir fluid from the isolated zone of the collector.

The accompanying drawings are not made to scale, illustrate only typical embodiments of the present invention and do not limit the scope of the invention, which allows for other, equally effective ways of implementation.

Detailed description

In the following description, numerous details are presented to facilitate understanding of the present invention. However, specialists in the art it is obvious that the present invention can be practiced without these details and that numerous possible variations or modifications of the described embodiments.

Under the "wellbore" refers to the internal pipe system completion. "Surface"if the e stated otherwise, means, in General, a location outside the borehole, at ground level or above and, in General, on the rig floor, although this notion to include other geographical position at ground level or above it. "Tube" or "tubing" means the pipeline or, in General, any round hollow device and in the field of oil well casing, drill pipe, metal pipe or flexible tubing or other similar device. Under "service well" means any operation designed to increase the yield of hydrocarbons from the reservoir, the lower output of the non-hydrocarbonaceous substances (if any) and both, comprising the step of pumping fluid into the wellbore. This includes the injection fluid in the injection well and extraction of hydrocarbon from the second wellbore. The pressurized fluid may be a composition to improve the performance zone, carrying hydrocarbons or may be a composition injected into other areas to lock their permeability or porosity. The methods of the invention may include the injection of fluid, for example, to stabilize sections of the wellbore to stop sand or injection of cement slurry into the well bore, in which case the pressurized fluid which may penetrate the completion (for example, down on the inner tube and then up out of the pipe in the annular space between the pipe and breed) and to ensure the mechanical integrity of the wellbore. Thus, when used herein, the terms "treatment" and "service" is broader than the term "intensification". Many options for use when the rock consists mainly of carbonates, one of the fluid may include acid, and increase the yield of hydrocarbons caused directly by increasing the porosity and permeability of the matrix rock. In other embodiments, applications, often in the presence of Sandstone, the stage may include adding to the fluid proppant or additional materials, so that the pressure of the fluid leads to the fracturing of the rocks, and into the cracks comes proppant in order to avoid closure of cracks. Details are described in most standard documents, maintenance of wells and well-known specialists in servicing wells, so here they are omitted.

Used herein, the term "PVP" and "blowout preventer" in General applicable to any system of valves in the wellhead that can be closed if the working crew loses control of formation fluid environments. The term includes ring the blowout preventer, the RAM promuovere the new bags, the cutting die Assembly of well control. Closing this valve or valve system (which is usually done remotely by hydraulic actuators), the team usually regains control of the well, after which you can begin the process of increasing the density of drilling mud until it will be possible to open PVP and to support the management of reservoir pressure. "The Assembly of well control" may contain a set of two or more PVP used to provide pressure control in the well. A typical Assembly can contain from one to six spot preventers and, optionally, one or two annular preventers. The typical configuration of the Assembly has the spot light at the bottom and the annular preventer on top. The build configuration preventers optimized to ensure maximum integrity, security and flexibility of adjusting the pressure in case of violation of well control. Assembly of well control can also include a variety of flanged joints, reducers and bends pipe to circulate the downhole fluid under pressure in case of violation of well control.

"Lubricator", sometimes referred to as a tube or cylinder lubricator provides a method and apparatus by which the tool is used on the nave is anyh fields virtually any length can be used in operations with bugtawhanna or docked tubing. In some embodiments, the implementation of the lubricator is used, allows you to mount the drive mechanism of the injector flexible tubing directly at the wellhead. The tool used in the oil field of any length can be mounted in a cylindrical reservoir with a closed end which is then installed on PVP. After establishing fluid communication between the injector and PVP, on the one hand, and the mouth of the well, on the other hand, by opening at least one valve, the tool used in the oil field is omitted from the reservoir into the wellbore, while the instrument remains in the wellhead near the first sealed dies, in PVP, which are then closed to grip and seal the instrument. Then the lubricator can be removed and the injector holder be placed over PVP and the mouth of the well. Column pipes up to clutch capture tool, and between the tubing and the tool set of fluid and/or electrical connection. Then the drive mechanism of the injector (already holding/attached to the string of pipe) can be attached to PVP or wellhead, and the first sealed die, exciting tool, OTC, and between STV is scrap wells and drive holder injector tubing is installed fluid communication. Removing and deleting components of the tool used in the oil field is carried out by performing the above steps in reverse order.

Under the "pressure system" means a ground device consisting of a pump, which may include electric or hydraulic power unit, commonly known as the power source. In the case of multiple pumps, they can be interconnected in series or parallel, and the power-carrying line may come from one or more pumps. The injection system may also include a mixing device for combining different fluid or mixing of solid particles in the fluid, and the invention provides for the use of downhole and surface data to change the parameters of the pumped fluid, and control operational mixing.

Under "ground-based data collection system" means one or more computers on the rig floor, with the possibility of connecting computers in a network and use the network of ground sensors. Computers and sensors can communicate over the wireless network. Some computers do not necessarily located on the rig floor, but the relationship with them can be done through a system of tie is. In some embodiments, implementation of the present invention, the communication line may end with the wireless transmitter in the wellhead and downhole data may be transmitted over the wireless link. Ground data collection system may have a mechanism combining well data with ground data and their subsequent display on the user console.

In illustrative embodiments of the invention in the data collection system can run programs consultants who give recommendations for changes in operating parameters on the basis of borehole data, or a combination of borehole data and surface data. Such programs consultants can also run on a remote computer. Indeed, the remote computer can receive data simultaneously from several wells.

The communication line used according to the invention, may have a length many times greater than their diameter or effective diameter (defined as the average of the largest and smallest size at any cross section). The line can have any cross section, including, but without limitation, circular, rectangular, triangular, any conic section, for example oval, lobed, etc. the Diameter of the communication line can be homogeneous or inhomogeneous on the length of the transmission line. T is pmin "communication" includes bundles of individual fibers, for example, bundles of optical fibers, bundles of metal wires and bundles containing metal wires and optical fibers. There could be other fibers, for example, reinforcing fibers, either in the core or distributed over the cross section, for example, polymer fibers. Aramid fibers are well-known due to its durability, one material based on aramid fibers known under the trademark "Kevlar". In some embodiments, the implementation of the diameter or effective diameter of the communication line may be 0.125 inch (0,318 cm) or less. In one embodiment, the communications link includes an optical fiber or a bundle of multiple optical fibers, making valid the damage of a single fiber. In the patent application U.S. No. 11/111,230 of the present applicant, entitled "Optical Fiber Equipped Tubing and Methods of Making and Using", filed on April 21, 2005, revealed one possible line of communication, in which incomedia tube is created by wrapping it around the optical fiber with subsequent laser prevarication tube to close the tube. The resulting design is referred to as fiber-optic tube, and it has high rigidity and is able to withstand fluid with high abrasion and corrosion ability, including hydrochloric and hydrofluoric acid. Fiber optic TRU the key is also available from K-Tube, Inc., California, United States. The advantage of fiber optic tubes such that they allow to directly attach the sensors to the bottom of the tube. The sensors can have essentially the same or smaller diameter than the fiber-optic tube that minimizes the probability of separation of the probe from the ends of the tube while moving. However, fiber-optic tube is expensive, and therefore, some embodiments of the invention provide for removing the sensors by means of reverse winding, so that the tube can be reused. Reverse winding can be operated by a ground-based system of data collection, but can also be a standalone device that is added at the end of process intensification.

In an alternative embodiment, the communication line may contain one optical fiber having ftorpolimernoj or other engineered polymer coating, for example, parylene coating. The advantage of this system is that its cost is quite low and it can be thrown away after each operation. One drawback is that it must withstand movement in the borehole and subsequent stages, which may include stage proppant. In these cases the implementation can be used long relief tube or pipe, sotiriadou is a very durable material, or material covered with well-known surface hardeners, for example, carbides or nitrides. The line will be served through this protective tube or pipe. The length of the protective tube can be chosen so that the fluid passing through the far end of the pipe was laminar. This length can be dozens of feet or meters, to the relief pipe can be placed in the wellbore. According to variants of implementation, where the communication line is unifiber, you may need to perceiving the device was very little. In these cases the implementation can use a device made by nanotechnology, which can be attached to the end of the fiber without significantly increasing the fiber diameter. On the lower end of the fiber, you can add a small envelope, covering a sensitive area, so that any change in outer diameter were very smooth.

1 shows a diagram, not to scale, of a variant of implementation of the known system, which is used to arrange the columns of the flexible tubing in the well. (The same components are denoted by identical positions on all figures, unless otherwise stated.) Figure 1 shows the flexible tubing 22, unwinding from the reel 20 by the injector 26 through the S-shaped elbow 24, as is known in the art. Device (not p is shown) can be provided in any number of positions, which can be useful when performing geometric dimensions of the flexible tubing. Flexible tubing 22 is unwound and can descend into the well, and stretched from wells, existing wells due to the ground control device well. Reservoir fluids can back up the annular space between the flexible tubing 22 and the wellbore (not shown in Fig.1).

Although flexible tubing useful for various purposes in the drilling site, mainly due to its ability to move fluids into the borehole and out of the well control can be challenging, especially in the so-called reverse flow situations, when the produced fluids may be able to flow up the tubing to the surface. In addition, the flexible tubing is subjected to plastic deformation during operation and often have defects such as pinholes. Concentric flexible tubing can be used to return the reservoir fluid to the surface, but it is associated with significant operational difficulties, including the safe draining fluid on the surface of the spool concentric flexible tubing on technological equipment.

In practice, if the formation fluids are needed on the surface, they are more likely to be transported through more durable tubing, such as used in the ode sampling layer on the pipe. In this case, as shown in figa-2B, the drill pipe is typically used to transfer the system to the packers. Figa and 2B, essentially identical to figa and 1B of U.S. patent No. 4,320,800 owner. The test interval of the well spuskaemsya column 10 drill pipe or tubing is supplied with a valve 11 reverse circulation any typical design, for example, like valve is illustrated in U.S. patent No. 2,863,511 issued to the holder of this invention. Suitable segment of drill pipe 12 runs between the valve 11 reverse circulation and Assembly 13 multiphase flow meter or test valve, which alternately opens and closes the reservoir interval to be tested. The preferred form of the Assembly 13 of the test valve is illustrated in U.S. patent No. 3,308,887, also issued to the author of the present invention. The lower end of the test valve 13 is attached to the valve 14 pressure relief, which, in turn, is attached to the holder 15 of the recording device, which concluded the burner pressure, similar to those shown in U.S. patent No. 2,816,440. The recorder continuously monitors the pressure of the fluid depending on the elapsed time during the test in the usual way. The holder 15 of the recording device attached to the upper end of the sub-filter 16,which receives and ejects the downhole fluid medium during operation of the pumping unit 17 for nadowli the upper packer, attached to the lower end of the sub-filter. The pump unit 17, which together with various other components of instrumental column generally includes inner and outer telescoping parts, and a system of check valves, designed to downhole fluids from moving under pressure during the upward movement of the outer part relative to the internal parts and absorbed through the sub-filter 16 during the downward movement. Thus, the number of vertical up and down movements of the deployed column 10 provides the action of the pumping unit 17 and the supply of fluid under pressure to inflate the upper packer, as described below.

The lower end of the pump unit 17 is attached to the valve 18 alignment and release of the packer, which can be activated upon completion of testing for equalizing pressure in the test interval of the well with the hydrostatic pressure of the borehole fluid in the annular space above the instruments and to ensure blowing off the upper packer element with the transition in its normal relaxed state. Of course leveling valve necessary to ensure the release of the packers to a tool string can be retrieved from the well. The valve 18 is attached to the upper end of the 19th dual inflatable packers, VK is causa in themselves the upper and lower inflatable packers 21A and 21B, connected to each other by various components, including an elongated intermediate sub 7. Each of the inflatable packer 21A and 21B includes an elastomeric sleeve, which is usually compressed, but can be extended outwards under the action of internal pressure fluid and to enter into tight contact with the surrounding wall of the wellbore. The length of the intermediate sub 7 is chosen so that during the test the upper packer 21A was above the upper end of the zone of interest, and the lower packer 21B was lower interval. Of course, when the packer elements are expanded, as shown in figa, the interval of the well between the elements is isolated or sealed from the rest of the wellbore, allowing the selection of fluid from the interval can be produced through the above tools and the drill pipe 12.

The pumping unit 23 rotary, which is functionally different from the upper pump unit 17 connected between the two packers and designed to supply fluid under pressure to the lower packer 21B to inflate the purpose of hermetic contact with the wall of the wellbore, the rotation of the pipe string 10, leaving the surface. The lower end of the pump 23 is attached to the intermediate exhaust valve packer 8, which allows you to blow the packer 21B in the end the test. The lower packer Assembly 21B, in the General case, a similar design to the upper Assembly 21A, and its lower end attached to the spring tool 25 for blowing off with the tool 9 of the friction clutch with the wall of the wellbore for preventing rotation that provides the rotational action of the pumping unit 23. The tool 25 can also include a valve that opens by the end of the test to ensure that the nipping element 21B.

If desired, the lower end of the tool 25 can be attached another holder 27 recording device and place in an appropriate channel to measure directly the pressure of the reservoir fluid in the isolated interval to provide a definition and a comparison with the pressure recording device in the upper holder 15 that it isn't clogged test channels and openings in the rock fragments and other during the test. In addition, although not shown in figure 2, it is obvious that the columns can include other tools, for example, Yas and protective tube, for example, between the Assembly of the test valve 13 and the pump unit 17 in accordance with the usual practice.

According figa column pipe 10 usually comes to the surface, where it hung for manipulation of the derrick D by means of conventional design, for example, vertl who ha S traveling block B and the cable C passes between the traveling block and crown block S' at the top of the derrick. On the fixed end of the rope sensor is installed, for example, a weight sensor for measuring the weight of the drill string and tools in the wellbore. The sensor output is fed to the indicator of weight W, which provides the operator of the drilling rig visual indication of the precise magnitude of the weight held by the rope and derrick at any time. The movable end of the Taurus passes to rig the winch, which is used in the usual manner for lifting or lowering the pipe as desired.

During the operation flow of the reservoir fluid, and allow flow between the packers and then to the surface through the drill pipe and out through equipment testing and production. Drill pipe is not easy to move during this operation from one zone to the next, as the individual joints of pipe cannot be removed from the column, not zagluchil pre-hole. The articulated section of the pipe cannot be winded, so its descent and ascent in the wellbore takes a long time.

Insulation tools can be quickly transported to the zone of interest, when the insulating packers are lowered on the rope or cable wire line. In this case, the reservoir fluid media are not allowed to return on Ernest due to the inability to maintain well control at haptically.

Figure 3 shows a diagram of the known device cable tests used for the assessment of the collector. Downhole flow measurement and pressure are used to obtain reservoir parameters, for example, the upper layer, the permeability and the length of the collector. Figure 3, not to scale, shows a view partially in section of a cable or wire line. Line 32 is typically wound on a drum 34, located at some distance from the wellhead 48. Typically, the operator seated at the operator's console 36. Line 32 passes through the pulleys 37 and 38 before it reaches the upper part of the lubricator or hydraulic seal 40. The lubricator or hydraulic seal 40 form a barrier pressure around the line 32 at the point of its entrance. The rest of shown items form an Assembly of well control, such as connectors 42 and 46, and PVP 44.

When there is sufficient pressure at the bottom hole reservoir fluids flow, flowing naturally into the wellbore and then to the surface. Flow characteristics of the reservoir can simply be determined by measuring at the surface or by dipping a well-logging tool for production wells in the well bore. However, some difficulty occurs when the pressure at the well bottom is not enough to exit the downhole fluid at Ernest. The hydrostatic pressure of the fluid in the wellbore restricts the flow of reservoir fluid into the wall of the collector or in the wellbore through the perforations. To overcome this hydrostatic pressure and selection of fluid from the well, is provided by the well-known technique of "mechanized production fluid through the discharge gas, usually nitrogen, into the wellbore to a depth sufficient to artificial lift downhole fluid to the surface.

Figure 4 shows one well-known method of artificial lift using the discharge of nitrogen, which is described in U.S. patent No. 3,722,589. This patent describes a device that allows you to pull the coiled tubing into the tube and which permits the output of formation fluid to the surface with the simultaneous production of performance measurement. The device may contain hydraulic logging tool for production wells operating in the backup mode. The instrument measures the flow rate and pressure of the fluid, as well as other parameters, such as viscosity, pH, etc. Logging tool for production wells is lowered into the area of interest on coiled tubing. No separation zones is impossible. Nitrogen or other fluid medium may be introduced through flexible tubing to the outlet resp is rtiu, some distance along the flexible tubing. Gas raises reservoir fluids and goes to some desired point on the tubing.

In this way, a flexible tubing, which is stored in a contiguous section of a pipe of small diameter on the reel, located on the surface. The tubing is inserted into the wellbore by means of well-known operations with flexible tubing using the tubing injector holder located at or near the wellhead. As soon as the remote end of the flexible tubing reaches the desired depth for injection of gas, begins relatively simple operation of the discharge gas through the flexible tubing to provide the desired mechanized production.

According to figure 4 in the bore 50 has one or more of the casings 51, forming the inner coating of the wellbore, as well as possibly other known necessary pipe, casing or tubing. Above the wellbore is the mouth 48 of the well, which may be of any shape and includes a well-known device for suspension of pipe in a well bore, valves and outlet openings, provided with valves. Over the mouth of the well is usually located PVP 42 or other device through which a string of pipe can be lowered without leakage or pressure from the well. Provided by the injector device 26 of tubing, and a curved direction of the Commissioner tubing 24. Injection device 26 is normally supported by the frame 54, and a flexible tubing 22 is typically stored on the reel 20, which can be mounted on the frame, adapted for transportation, or, as shown in figure 4, is installed on the truck 53, which allows you to transport it from one site to another. Liquid nitrogen can be pumped by pump 56 through the heater 57 to generate nitrogen gas of high pressure, which is then delivered to the pipe 55 to the flexible tubing 22 through the flange of the reel 20. The wellbore 10 in most cases contains a liquid having a level 60 in the well. To displace fluid from the well, the end 22a of the flexible tubing 22 is inserted into the wellbore using the injector 26 in a position slightly below the surface 60 of the liquid. When the lower end 22a of the flexible tubing 22 is moved down through the borehole, nitrogen gas is continuously or intermittently introduced with such speed, to clean and circulate all large volumes of liquid up from the well through the annular space of the pipe bore, for example, the casing 51. The liquid is pumped out through the outlet 63 wellhead. After removal of the fluid from the well into the reservoir 62 is formed depression in the bottom of the well. Perforations 61 of the casing are provided in a known manner, so there could be fluid communication with the call the torus 62.

Attempts were made logging flow in the wellbore to determine the various reservoir parameters during sampling fluid by the method of artificial lift using discharge gas through the flexible tubing. There were some difficulties in interpretation of the data. One owner of a patent has suggested that this is possibly due to the nature of the device used for such logging, teoretiziruya that the logging tool is usually mounted on the flexible tubing directly under the hole for injection of gas, exposed to bubbles of nitrogen formed in the downhole fluid passing through the impeller flowmeter logging tool. Another theoretical consideration is that hydrodynamic effects caused by the injection of gas in the fluid downhole, can lead to the formation of vortices, turbulence, etc. that can also have a negative impact on the accuracy of measurement, defined by the impeller flowmeter. In addition, due to the size of the pumping equipment is usually used in conjunction with flexible tubing, it is necessary to inject a relatively large volumes of gas through the device, a condition that is not conducive to getting the best data in combination with a logging tool for operation shall include wells, attached to the gas-injection tool to the flexible tubing.

Figure 5 shows the improvement of the known device shown in figure 4, disclosed in U.S. patent No. 4,984,634. This patent describes a gas-injection tool 70 having at least one hole 72 for the passage of gas, located in the General case at the lower end of the column flexible tubing 22 in the bore 50 with the casing 51 of the well. Due to the discharge gas, for example nitrogen, through the flexible tubing 22 into the well bore 50 through the opening 72 for the passage of gas fluids in the wellbore 50 artificially rise, flowing vertically in the borehole that is well known in the art. The lower end of the gas-injection tool 70 is attached to the adapter 75, which connects the gas-injection tool 70 and the connector of the first lug 76 wired cable. Wired line 74, which provides electrical connection between the surface and the tip of the cable that passes through the flexible tubing 22, the gas-injection tool 70, the adapter 75 and is connected to the electrical connectors in the first cable lug 76. Under the first cable tip 76 of the supporting strip 79 passes down to the second connector of the cable lug 77 and provides electrical connection between the first cable tip 76 and the second is m cable lug 77. The second cable lug 77 is attached to the logging tool 78 for production wells in accordance with standard procedures for wired connections logging. The logging tool 78 to production wells may register the flow of fluid flowing up the wellbore 50. Subject to the foregoing, the length of the strip 26 can be adjusted to the length that will meet both goals: prevent logging tool for production wells from the effects of gas injection and the possibility to regulate the flow of borehole fluid in the borehole 50 in relation to the gas flow through the flexible tubing and the outlet 72 of the gas-injection tool 70. In the General case, the length of the strip 79 varies between approximately 100 feet to 1000 feet or more (approximately from 30 to 300 m).

Figure 6 shows a schematic side view, partially in section, of a communication system that uses a beam of optical fibers within a metal tube inserted into the coiled tubing. Optical fibers transmit data, but not energy. Flexible tubing 22 with the holder of the optical fiber in the form of a pipe or tube 86, which is shown as a straight line. Tube 86 conducts one or more optical fibers 92 by a flexible tubing 22. It is shown that the tip 89 of the optical fiber has the four end of the optical fiber, and the second lug includes a sealing cartridge 93 and mechanical holder-seal 87, which in this embodiment is a fitting-based compression. This sequence of seals 87, 93 and wall plug with sealant (not shown) tightly attaches the housing 88 to the bracket 86 of the optical fiber. Optical fiber 92 may be loose and can be wrapped around the support rod 94 to the tip of the optical fiber during part of its length. Provides loop-through connector 96 to the naked optical fiber that insulates the holder 86 fiber from the wellbore treatment fluid in case of damage of the head flexible tubing or BHA. You can use a number of connectors 80A, 80B and 82. Connector 80B may be a sleeve with thread. Note that the path of fluid flow is provided through the flexible tubing 22, the connectors 80A, 80B and 82 and through the flexible tubing head 82, designated 98. The element 85 is used for protection and can be replaced with different components.

The communication system may be an electrical cable or optical fibers within a metal tube, such as shown in the above figa and 6B. The advantage of using tube containing optical fibers, is the fact that that the tube takes up less space inside the flexible tubing and creates less friction. In particular, the tube can be inserted into the flexible tubing to the production of works. In the case where the communication system includes an optical fiber, the pressure sensor may also be an optical pressure sensor. The light source, for example a laser, is part of a reel of flexible tubing, which activates the pressure sensor.

The characteristic of the present invention is a spread communication system beyond the point where the nitrogen comes out to a logging tool for production wells. In this case, measurements of flow and pressure of the reservoir fluid is available in real time, which is very attractive for the consumer. In one embodiment, this requires that the device have a lower communication system from a well-logging tool for production wells to the output of nitrogen, which may be provided with loop-through connector connection for transmission of data from the space directly under the valve of the nitrogen in place directly above it. Then the upper communication system transfers data from there to the surface.

A sign of the present invention is to provide a means for the deployment of the logging in a production well without having to plug the well before and after surgery. According to figure 5 there is a point 72 of the output in the flexible tubing, which nitrogen is blown; this means that problems can occur with well control. You want to insert the check valve over the hole 72 so that the nitrogen can be pumped through a flexible tubing, but reservoir fluids couldn't do it. An implementation option, shown in Fig.7, is a solution to this problem. Shows a coil of flexible tubing 20, which is wound around the upper part of the flexible tubing 22A. The upper coiled connector 102 connects the flexible tubing 22A with nesmachivaemym check valve 104, which, in turn, attached to the bottom of coiled connector 103, and, finally, to the lower part 22B of the flexible tubing. The last closed logging tool for production wells (not shown) and lowered into the well until the coiled connector 103 will not be at the level of the wellhead. Neutral fluid for killing, for example, brine, or water, is pumped into the flexible tubing to fill it up to this point. Dies are closed around the flexible tubing, and then coiled connector is divided into two parts. There are two barrier for well control: the flexible tubing and fluid for damping. The new device, for example device shut-off valve 104, can be added to the lower portion 22B of the flexible tubing. The new device can have an outlet for nitrogen and folding back the first valve above it. The upper coiled connector 102 is attached to the newly installed device. This Assembly can be safely lowered into the wellbore.

7 shows a diagram of the known device that provides separation of coiled connector into two parts, and the component is inserted between them. Although the type of connection is not shown, you can use threaded connections, connection type tensioner frame or other similarly valid connection type. One advantage is the provision of a check valve or other component due to the system, which can be delivered on a drilling rig in the form of two jointly wound coils. They uncoiled on the rig, and is inserted into the valve device, which allows you to expand the system under pressure.

Another characteristic of the invention consists in the improvement of the method and device to attach the lower communication system to the upper communication system during this process, also attach the pressure sensor.

The above-described device and system based on flexible tubing does not include a system of fractured zones, corresponding to the prior art is shown, for example, in figure 2 (a formation test pipe) and figure 3 (cable test). When there are multiple gaps in the current, difficult to isolate the contribution of each zone without any what about the no dissociation zones. In addition, the pressurized nitrogen can affect the data measured on the logging tool for production wells, for example, in the presence of a zone of absorption under a logging tool for production wells, in which case the pressurized nitrogen can come back instead of going out to the surface.

For this reason, methods, device and system according to the invention may contain instruments separation zone comprising a cuff or a non-inflatable packers for single operations and inflatable packers for operations through the tubing. A pair of such packers may be in the area of collector interest, and flowing the fluid up through the flexible tubing in the intermediate section of the branch. Used herein, the term "intermediate" means any convenient place between the base of the flexible tubing and the surface.

On Fig shows the separation zones. One of the main advantages of this system is the ability to provide an inflow from the test zone in the annular space and to ensure that the traditional management of produced fluid environments on the surface. On Fig shows a single application, in which the flexible tubing 22 is inserted into the casing 50. Flexible tubing 22 includes, in turn, the upper part is releasable, coiled connection 102, circulation in the area of the traditional valve or sub 110 land management (shown in circulation), constant nesmachivaemym check valve 111, dvuhchasovoj valve 112 and the lower part of the releasable, coiled connection 104. Also shown are three productive zones 130, 132 and 134 with the corresponding threads 123, 122 and 121. It is possible to provide an optical connector 113. Shown downhole shutoff valve 114 ground control, reverse valve 115 (which can be controlled hydraulic, electronic or optical means) and a pair of traditional packers 116 and 117. Between the packers 116 and 117 can provide a hole 118 to flow, and the holder of the measuring device 119, which may carry one or more sensors, and a semicircular nozzle 120, which may include an optional section.

Using these method, device and system includes the use of holes for circulation above the insulating packers. The test, known at the present time, is very difficult due to communication with the upper zones. This system depends on the test parameters, for example, do the upper zone of the negative impact on the test.

Hole 135 for circulation must be over the tools of disconnection, it is not necessary to expand the tube connector coiled flexible tubing, as the entrance to the annular space may be relatively small is the distance above the layout of the bottom of the drill string, but to interpret the results of the test will be much easier, if the output of the fluid in the annular space located above, for example, higher than all other zones of the collector.

To deploy this system may have positive isolation holes 135 for circulation during deployment. This can be achieved with the use of a ball valve type TIW. This system can be used in conjunction with a logging tool for production wells online data or save the data.

A variant embodiment of the invention shown in Fig, provides the possibility of testing the area of the collector, in which a valid influence of other zones in test area. An implementation option, shown in Fig also allows for selective circulation through the valve land management, so that fluids can circulate inside the flexible tubing into the annular space of the flexible tubing.

For a large number of multilayer reservoirs should be around the upper zone, so they do not affect the ground-based measurements of consumption, as in the embodiment shown in Fig. In such cases, can be useful ways to implement shown in figures 9 and 10. These options for implementation provide the necessary separation zones and bypass rubyhornet zones in order to avoid any influence of these zones. The main advantage of the embodiments shown in figures 9 and 10, is the ability to provide an inflow from the test zone in the annular space at a point over other areas, contributing, and, nevertheless, to ensure that the traditional management of produced fluid environments on the surface, which eliminates the need to send the produced fluids through flexible tubing to the surface. Figure 9 shows the single-variant implementation gaslift and without it, in which there is mixing of the fluid from the zone of interest, with the fluid medium from other zones.

Figure 10 illustrates the case where all productive zones 130, 132 and 134 are positioned inside the tubing 70, and the gas lift can be achieved through flexible tubing 22. In some applications of this variant of implementation, the injection of nitrogen into the bypass operational tubing may also provide a gas lift. In this embodiment, two lower packer 141 and 142 are inflatable packers flexible tubing, and a third packer 125 may contain conventional double packer (mechanically driven) tool cross flow. Optionally, a third packer 125 may be inflatable packer set in the casing pipe. All other components described above.

Methods, device and system according to the invention, contain the device isolation poser the Dean of the column. This device may contain elements of sealing "lip" type. But it depends on the test parameters, and whether you want to suppress the influence of the upper zones or to provide absolute isolation zone of interest.

The upper insulation system can be inserted in the middle of the column, so that the distance from the test zone to the upper border of the small impact zone could be up to 3000 feet (0,91 km). With this purpose you can use the system shell connectors flexible tubing, such as shown in Fig.7.

The deployment of the circulation system in the middle of the column can be done either by circulation in the borehole fluid to kill the well, or by installing internal insulation system during deployment of the flexible tubing into or out of the well. The latter contains a management system to prevent buckling, buckling and sticking due to differential pressure flexible tubing system due to the installation of the third packer.

Methods, device and system of the present aspect of the invention contain a reliable system of coiled and releasable connectors and selective circulation valve, which allows fluid media to circulate inside the flexible tubing into the annular space of the flexible tubing. The system is designed for centrifugal and flexible tubing under the circulation valve for deployment and/or removal from the well. System non-inflatable packer collar type can be used to isolate flow in the annular space flexible tubing under the circulation valve and another valve is operated in conjunction with the described system.

In other embodiments, implementation methods, device and system according to the invention may contain a replacement, if desired, the two most lower packers (single applications) hydraulic packers, so they can be left in the well during the test the pressure recovery, and then either remove or move the following, the overlying area to be checked.

Below are non-restrictive examples of systems according to the invention, which do not mix the fluid from the zone of interest, with the fluid medium from other zones.

The illustrative system includes a chamber connected to the overlap of the flexible tubing, in which position the connection of overlap is determined based on the greatest difference between the lower zone and the upper zone on the site or in the field. When downhole tools will be on the rig floor, you can install them on the end of the flexible tubing. Installed downhole tools include the following tools: connector flexible tubing; an optical connector (with hydraulic or electric drive, or with any libdspam drive), downhole shutoff valve ground control, reverse valve (hydraulic or electric drive or any other drive) (this valve can also be embedded in the upper packer), the upper packer (traditional dual packer for single use, inflatable dual packer for use through tubing); spacer tubes; one sub with fittings with optional bursting disc security holder measuring device, which can carry one or more sensors of the downhole pressure and temperature; the lower packer (traditional packer for single use, inflatable dual packer for use through tubing); the jet.

Then the flexible tubing is lowered into the well until the plot of the overlap will not fall below the stripper. At this point, the descent flexible tubing stops, wedge PVP and pipe dies are closed by flexible tubing and subjected to the tests, the pressure released, and the injector holder is separated from PVP flexible tubing. Between the injector holder and PVP that is installed in the upper part of the wellhead shall be equipped with sufficient number of struts.

After disconnection of the riser flexible tubing is lowered, until you find the splices. The connection is disassembled by means of threaded connections, connection type Natai the first frame or other similar connection built-in connector for the overlap. Then between the upper and lower halves dissociate coiled connector (top to bottom) you can attach tools, such as the following: sub circulation of land management; continuous double check valve; a bypass tool (can also be embedded in the upper bypass packer); the upper by-pass packer (traditional packer in a single-use or when you install inside the tubing in the application through the tubing; an inflatable packer when installed in a casing pipe in scenarios through tubing); and dvuhchasovoj valve.

You can then provide the connection of the riser with PVP and open wedge PVP and pipe dies. Then the flexible tubing can be lowered to the desired depth. When it comes to the required depth may be several processes. All instruments can be operated by hydraulic, electrical signals, fiber-optic signals or other signals. The General method is the same, although the specific operation vary slightly depending on the method of management tools.

1) first, it increases the pressure inside the flexible tubing to purge the bursting disc in the sub with fittings.

2) Then simultaneously set all of the packers.

3) Open reverse flow check valve and at the same time downhole shutoff valve.

4) PR is in the flowing well, until the flow rate becomes constant.

5) is Then closed shut-off valve ground control, and starts the test pressure recovery.

Downhole shutoff valve ground control and reverse valve ground control can perform the same function, so that to operate only need one of them. However, it is not necessarily, therefore, the method allows two separate components to perform these functions independently. Information pressure and temperature is recorded downhole measuring devices.

After testing, if necessary, you can perform recovery processing. For this purpose, the shut-off valve must be opened, and the downhole sub circulation must be closed. Then the fluid processing is pumped into the reservoir.

During phase well test may require the injection of nitrogen, which can open the circulation valve and pumping nitrogen to reduce the hydrostatic pressure in the borehole and leverage of the tested layer.

Upon completion of the testing of the first zone all the packers can be simultaneously removed, lift and re-install, after which you can repeat the process for other areas.

After all the tests reverse valve ground control is closed, and the flexible tubing, the latter is foreseen from the well, while disconnected coiled connector will not touch the stripper. At this point, the wedge PVP and pipe dies are closed, the pressure released, the riser is disconnected.

All the tools are disconnected. At this point reverse flow check valve maintains the pressure of the well.

Disconnected coiled connector connects the riser reattached, dies PVP open and flexible tubing is pulled from the well. The process is repeated until all of the tools will not be released from the well.

The above process is safe thanks to the use of the reversing valve, which again can be controlled hydraulic means, electrical means or optical means.

Figure 11 shows the scheme zoned test device according to the invention, which eliminates the need for intermediate discharge section. Instead, provide a device of the downhole sensors in conjunction with a communications system that can transmit downhole data in real time during the test. Alternatively, one or more downhole sensors and communication components can be integrated into the layout of the bottom of the drill string, as shown in Fig, discussed below. The main advantage of the described systems is that they do not require any system with the connection inside the flexible tubing. Information tests collector is in these variants of implementation through terrestrial device as in traditional testing wells. The method is based on the downhole valve device (valve 112), which ensures that at the moment only one zone gives the fluid in this ground the device.

With reference to figa and 6B described a reliable communication device that allows the use of flexible tubing for operations flow and reverse flow. The device can also be used to activate tools, well control and data downhole sensors. This leads to another variant of the invention, in which the use of the communication system allows you to eliminate coiled connectors. Instead, measurements and device trials are transported in a well on a flexible tubing, which uses sensors similar to those used in traditional cable operations described herein with reference to figure 3. To transmit energy in the borehole easier for flexible tubing, since the hydraulic energy is much more efficient method of moving large amounts of energy. This does not mean that hydraulic energy should be used exclusively for downhole applications on flexible tubing. For example, the device used by the om according to the present invention, there is a small battery to switch hydraulic valve. The position of this valve has a great influence on the discharge pressure at the wellhead during discharge, so the combination acts like a transistor: small energy actuates the valve, but the valve itself manages a large volume of fluid. Similarly, in the device used according to the present invention, batteries are used to control the valve, which determines investing fluid pumped from the surface, an inflatable packer (or a pair of such packers). In the inflate packer forms a hydraulic connection of flexible tubing to the surface area of the collector and provides a hydraulic isolation from the rest of the manifold. Then large amounts of fluid can be pumped from the surface in this area (for example, to intensify the rocks with acid), or, on the contrary, you can allow the reservoir to gush into the flexible tubing to clean from damage or sediment in the surrounding area of the wellbore. Batteries used according to the invention, may include primary cells, secondary (rechargeable) elements and fuel elements. Some sets of chemicals used in the primary elements include lithium/thionyl chloride [Li-SOCl2] lithium/sulfur dioxide [Li-SO 2], lithium/manganese dioxide [Li-MnO2], magnesium/manganese dioxide [Mg-MnO2], lithium/iron disulfide [Li-FeS2], zinc/silver oxide [Zn-Ag2O], zinc/mercuric oxide [ZnHgO], zinc-air, [Zn-air], alkali/manganese dioxide [alkali-MgO2], zinc/carbon for work in harsh conditions [Zn-carbon] and marked or cadmium/silver oxide [Cd-AgO]. Suitable batteries include Nickel-cadmium [Ni-Cd], Nickel-metal hydride [NiMH], lithium-ion batteries, etc.

On Fig shows a diagram of the device used according to the invention for data transmission flow to the surface. The flow of fluid from the reservoir 130 is given by the packers 141 and 142 in the inner channel in the layout of the bottom hole Assembly (BHA) 150, which is connected to flexible tubing 22 by the connector 151. Flow measuring element 152 on the basis of the Venturi or chopper is part of the bottom hole Assembly 150, and the data flow is transmitted to the surface using a wireless transmitter 154, which may also act through conductive or fiber optic connection.

On Fig shows a logical block diagram of the method according to the invention for testing one or several productive zones of the wellbore, comprising the following steps: increasing the pressure inside the flexible tubing to purge the bursting disc in the sub with fittings; completion of the installation of all of the packers; the opening of the reverse valve and downhole shutoff valve land management; zone wells gush until the flow rate becomes constant, and the optional injection of nitrogen for mechanized production; closing the downhole shut-off valve ground control; the beginning of the test pressure recovery; check pressure and temperature downhole measurement devices; determine necessary remedial treatment and if it is not required, repeat steps for other productive zones.

Methods, device and system according to the invention include a downhole valve mechanism control, which uses a small amount of power in the well to drain the fluid in different ways, and this valve is operated by control from the surface, or through fiber-optic lines laid from the surface or by other means, and fiber-optic line can also be used to convey information about the state of the valve and of the operating parameters (usually pressure and temperature, and possibly, pH, flow, etc). The valve can be placed over the device nadowli packers, together with fiber-optic device sending data pressure, flow and temperature at the surface. Then the dual packer device is inflated on icnam way providing hydraulic communication with the reservoir. Downhole fluid environments allow to flow from the annular space of the flexible tubing. To accelerate this annular flow of fluid you can use the pump. A check valve near the device nadowli packers can be activated so that fluid can flow from the valve into the annular space. This leads to a pressure drop on the dual packer, resulting in formation pressure provides a flow. The produced fluid contains potentially hydrocarbon, so it would be risky to allow it to flow on the inside surface of the flexible tubing, but thanks to valve mechanism, the hydrocarbon will instead pass through the valve into the annular space. On the surface of PVP around the flexible tubing safely removes circular flow in process equipment, for example, where it can flow through the testing equipment, which considers the properties of the hydrocarbon.

In this example, in the absence of perforations in the casing pipe above the dual packer data of ground-based flow meter can be combined with data from the downhole pressure to determine reservoir parameters, for example, the top layer, permeability and damage. In the presence of perforations above the dual packer, this is not possible, because the flow in this case measures also supplies the d all fluid flowing into the reservoir or from the reservoir through these perforations. The problem solves downhole flow meter, and its data can be transmitted to the surface via fiber line, wire line or wireless transmission. Vertolety the flow meter in the flow lines well suited to fiber-optic device as a rotating turntable alternately closes and opens a channel of a light beam by which the data arrives at the ground receiver. The greater the frequency of interruption of the light beam, the higher the speed turntables, and hence the measured flow.

For wells with very low pressure at the well bottom sometimes even the pumping of the annular space on the surface does not allow the wells to gush. In such cases, you can install a valve mechanism for pumping the nitrogen or other gas or mixture of gases through a flexible tubing. The gas flows in the annular space. Below the reservoir fluid will not be able to balance the hydrostatic pressure of the fluid in the annular space and will "climb" down the gas. This is a natural variation propagation implementation, shown in Fig.9, on the well test.

For more complex valve device it is possible to combine the above-described valve system with the existing system nadowli packers. Thus, in one position fluid medium (liquid sludge is gas) from the surface is directed into the wellbore, in another position fluid is directed to inflate the packers, and in the third position there is a direct hydraulic connection between the flexible tubing at the surface and the collector (for example, for injection of acid). When the valve diverts ground the fluid (gas) in the annular space, it can also allow formation fluid to flow through the packer in the annular space. It is possible to provide a fourth position which allows flow to pass directly through the tool on any unit under it. Ground-based data to be transferred may include temperature and pressure, possibly, the pressure in each of the holes in the flexible tubing, the annular space on the manifold, the manifold and below the packer.

Similarly, if the well has a single design, instead of inflatable packers can be used lip or a non-inflatable packers. Alternatively, the packer elements can be inflated directly by injection of fluid through a flexible tubing. In both cases, when the starting of the pumps will be separation zones, but the device non-return valve can be installed above the column flexible tubing to maintain the pressure below it. It may be more useful when using inflatable packers, because the flexible tubing at the bottom will be a closed system. As a result of leakage into the reservoir, can the t to require a continuous flow of fluid to maintain the cuff in an insulating state, that allows the use of non-inflatable (or hydraulic packers.

The migration of formation fluid to the area of the dual packer raises the important possibility that the district collector can afford to give the fluid until it reaches a state of stable equilibrium. The produced fluid will pass through the linear flow meter (for example, the flow meter based on the turntables or Venturi), and these data can be monitored in conjunction with downhole pressure to ensure steady state. At this point, the linear flow can very quickly stop and track data recovery pressure. This is a significant improvement compared to the test pressure recovery produced using drill pipe.

Although we have described only some illustrative embodiments of this invention, the experts in this field of technology can easily offer numerous modifications of the illustrative embodiments, which are not significantly go beyond the features of novelty and advantages of this invention. Accordingly, all such modifications are to be included in the scope of this invention defined in the following claims.

1. Test method multispectral collector when vytekayuschih fluid from the wellbore, according to which
enter a single column of flexible tubing in the well bore with the annular space formed around the flexible tubing;
activate the device for separation zones to isolate at least one zone of the wellbore;
send test the fluid in the wellbore through a flexible tubing pipe to the location above mentioned area, the extract produced by the fluid from the isolated zone and test the fluid from the flexible tubing through the annular space;
measured characteristics of the flow and pressure produced by the fluid during the flow.

2. The method according to claim 1, wherein the device for separation of zones comprises a pair of inflatable packers.

3. The method according to claim 1, which additionally divert the flow in the annular space above the device isolation zones.

4. The method according to claim 3, which additionally reduce the hydrostatic pressure in the annular space by the injection of nitrogen in the annular space.

5. The method according to claim 1, which additionally transmit downhole measurements to the surface.

6. The method according to claim 5, wherein the downhole measurements are transmitted to the surface via optical fibers.

7. The method according to claim 5, in which additional pump LM is bone formation treatment on the basis of borehole measurements.

8. Test method multispectral collector when the flow of formation fluid from the wellbore, according to which
enter a single column of flexible tubing in the well bore with the annular space formed around the flexible tubing;
install the first isolation device to prevent the location in the wellbore leakage of reservoir fluid to the surface through the annular space;
activate the device for separation zones below the first isolation device for isolating the first zone under the field;
provide a flow of fluid from the first zone through the flexible pump tubing;
measure downhole flow and pressure of fluid flowing from the first zone;
divert the fluid flow from the first zone to the annular space above the first insulating device for retrieval.

9. The method according to claim 8, which additionally inactivate the device isolation zones, move the device to the separation zone to the second zone and activate the device for separation zones to isolate the second zone.

10. The method according to claim 8, in which use of the device for separation of zones containing a pair of inflatable packers.

11. The method according to claim 8, which additionally reduce the hydrostatic h is then in the annular space by the injection of nitrogen.

12. The method according to claim 11, which additionally transmit downhole measurements to the surface.

13. The method according to item 12, wherein the downhole measurements are transmitted to the surface via optical fibers.

14. The method according to item 12, wherein additional pump fluid treatment layer on the basis of borehole measurements.

15. Device for testing of reservoir fluid when flowing from the wellbore that contains
a single column of flexible tubing;
the dual system of swelling packers to isolate the area of the collector, and the dual system is moved and situated flexible tubing pipe;
the valve system land management, ensuring the passage of fluid pumped from the surface into the annular space of the wellbore above the dual system of the packers, and in the area, isolated dual system of packers, and the passage of the fluid from the isolated zone of the collector in the annular space above the dual system of packers and
the measuring device is placed in an isolated area, to measure the flow of the fluid current to be extracted from the isolated zone, and the flow measurement is transmitted to the surface equipment via optical fibers passing through the flexible tubing pipe.

16. The device is in the on clause 15, in which the packers dual system of packers are inflatable packers.

17. The device according to clause 16, in which the valve system is additionally capable of passing injected from the surface of the fluid in a dual system of packers to activate the packers.

18. The device of clause 15, further containing a communication system for transmission of flow measurement at the surface.

19. The device according to p, in which the communication system includes an optical fiber.

20. The device of clause 15, further containing insulating means located above the dual system of packers.



 

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FIELD: oil-and-gas industry.

SUBSTANCE: invention relates to oil-and-gas industry and can be used in analysing fluid dynamics of gas medium at hydrocarbons deposits and subterranean gas storages. The proposed method comprises forcing gas medium indicator marks representing gas-filled micro granules with the dispersion degree of 0.5 to 0.6 into the bench through different injection holes and sampling from output holes. Note that indicator mark sampling is realised by forcing gas through sampling tube along with controlling gas passing time and the hole rate of yield, the sampling tube gas flow rate is determined from mathematical expression. The content of micro particles in indicator mark is determined from mathematical expression. The invention covers also the device to embody the above-described method.

EFFECT: continuous sampling, higher sampling efficiency and validity of results.

3 cl, 1 ex, 2 dwg

FIELD: mining.

SUBSTANCE: device contains receiving chamber for samples, pump, communicating with chamber, pressure measuring device, communicating with sample and optical analyser, optically connected with sample; device and analyser facilitate pressure drop in sample and determine pressure which provides extremum of light amount passing through sample.

EFFECT: preventing precipitation of hard substances and bubbling during sampling.

19 cl, 27 dwg

FIELD: oil and gas production, particularly well interior separation for reservoir isolation one from another.

SUBSTANCE: device comprises packing members with elastic collars and reaming members, seating tool connected to lifting pipes and having lower part telescopically put on technological pipe, anchor, well screen and check valve. Each reaming member except for upper one is connected to body of each next upper packing member from below through intermediate pipe or pipes. Lower packing member body is secured to support pipes. Well screen is included in support pipe and/or one or several intermediate pipes opposite to each reservoir to be developed or treated. Check valve is located over upper well screen. Reaming member is made as thrust secured to telescoping pipe. Thrust of upper packing member has inner cavity and is connected to upper telescopic pipe by shear members so that the thrust may slide with respect to the pipe in axial direction. Thrust sliding is limited by upper annular widened section of upper telescopic pipe arranged inside thrust. Anchor is located over upper packing member thrust.

EFFECT: possibility to operate in wells having non-calibrated inner diameter, increased air-tightness of well interior separation.

2 cl, 1 dwg

FIELD: hydrocarbon production, particularly for separately-simultaneous or alternate working fluid injection in one or several pools.

SUBSTANCE: plant comprises the first packer connected to flow string and lowered under upper pool, flow string disconnector arranged over the first packer and seat to receive retrievable check valve located between the first packer and flow string disconnector. Arranged below the first packer is the second packer, which creates packer section along with the first packer. The packer section includes at least two mandrels with seating units arranged therein, circulation valve and liquid flow turbulator. The seating units receive oscillator generator and removable valve or bridge plug. Turbulator is installed at lower edges of circulation orifices formed in casing pipe within the limits of oil pool to be developed. Number of packer sections included in the plant is equal to number of pools to be developed. The last packer section is between lower packer of next to last pool and one-way valve installed at flow string end.

EFFECT: possibility to optimize downhole plant parameters and to stimulate injection and/or fluid inflow simultaneously with plant installation.

8 cl, 1 dwg

FIELD: oil production, particularly devices to perform reservoir tests in wells, including that having opened bores.

SUBSTANCE: device comprises upper connection unit for device fixation on pipe string, upper and lower packers with sealing members, upper and lower movable rods provided with axial channels arranged inside packers and hollow filter installed between upper and lower packers. Axial channel of lower movable rod is provided with solid partition. Upper and lower movable rods are fixedly connected with each other in air-tight manner and provided with upper connection unit. Upper and lower rods may be displaced only in downward direction with respect to upper and lower packers. Sealing members of upper and lower packers are located between stops. Upper stop of lower packer is fixedly connected with lower stop of upper packer provided with balloon-type centrators through hollow filter. The balloon-type centrators are arranged from top thereof. One stop of each packer is made as hydraulic cylinder fixedly connected with packer and as annular piston cooperating with sealing member. Inner cavities of each hydraulic cylinder may cooperate with axial channels of movable rods over solid partition and may provide air-tight isolation thereof during movable rod displacement in downward direction with respect to packers. Upper movable rod is provided with radial channel sealed with packer and adapted to cooperate with ambient space through hollow filter during movable rods displacement in downward direction with respect to packers.

EFFECT: simplified structure, decreased costs of device production and increased operational reliability.

1 dwg

FIELD: packing devices for isolating shaft of wells during various technological operations.

SUBSTANCE: interval packer device contains longitudinally positioned upper and lower packers with sealing collar packing. Upper packer is made hydro-mechanical, lower packer - repression-depression action hydraulic packer. Positioned between packers is valve unit of two-side action, hydraulically connected to lower packer through in-pipe and annular spaces. It consists of hollow body with at least one radial channel and differential bushing with radials apertures positioned on the body and spring-loaded on both ends by means of reciprocal force springs. All packers are made so that each one of them may be used independently or in composition of other assemblies.

EFFECT: increased reliability of operation and expanded functional capabilities of devices.

4 cl, 13 dwg

The invention relates to a tool and method for injection of a sealing liquids, for example, what are the means for cementing oil-bearing layers of sand or chemical agent for stimulation with the aim of increasing its oil and liquid for rinsing wells feed her there in an excessive amount, inside geological formations surrounding an underground borehole

The invention relates to the oil industry, in particular to the means of preservation of reservoir properties reservoir

The invention relates to industries, a leading drilling for oil, gas and water

FIELD: packing devices for isolating shaft of wells during various technological operations.

SUBSTANCE: interval packer device contains longitudinally positioned upper and lower packers with sealing collar packing. Upper packer is made hydro-mechanical, lower packer - repression-depression action hydraulic packer. Positioned between packers is valve unit of two-side action, hydraulically connected to lower packer through in-pipe and annular spaces. It consists of hollow body with at least one radial channel and differential bushing with radials apertures positioned on the body and spring-loaded on both ends by means of reciprocal force springs. All packers are made so that each one of them may be used independently or in composition of other assemblies.

EFFECT: increased reliability of operation and expanded functional capabilities of devices.

4 cl, 13 dwg

FIELD: oil production, particularly devices to perform reservoir tests in wells, including that having opened bores.

SUBSTANCE: device comprises upper connection unit for device fixation on pipe string, upper and lower packers with sealing members, upper and lower movable rods provided with axial channels arranged inside packers and hollow filter installed between upper and lower packers. Axial channel of lower movable rod is provided with solid partition. Upper and lower movable rods are fixedly connected with each other in air-tight manner and provided with upper connection unit. Upper and lower rods may be displaced only in downward direction with respect to upper and lower packers. Sealing members of upper and lower packers are located between stops. Upper stop of lower packer is fixedly connected with lower stop of upper packer provided with balloon-type centrators through hollow filter. The balloon-type centrators are arranged from top thereof. One stop of each packer is made as hydraulic cylinder fixedly connected with packer and as annular piston cooperating with sealing member. Inner cavities of each hydraulic cylinder may cooperate with axial channels of movable rods over solid partition and may provide air-tight isolation thereof during movable rod displacement in downward direction with respect to packers. Upper movable rod is provided with radial channel sealed with packer and adapted to cooperate with ambient space through hollow filter during movable rods displacement in downward direction with respect to packers.

EFFECT: simplified structure, decreased costs of device production and increased operational reliability.

1 dwg

FIELD: hydrocarbon production, particularly for separately-simultaneous or alternate working fluid injection in one or several pools.

SUBSTANCE: plant comprises the first packer connected to flow string and lowered under upper pool, flow string disconnector arranged over the first packer and seat to receive retrievable check valve located between the first packer and flow string disconnector. Arranged below the first packer is the second packer, which creates packer section along with the first packer. The packer section includes at least two mandrels with seating units arranged therein, circulation valve and liquid flow turbulator. The seating units receive oscillator generator and removable valve or bridge plug. Turbulator is installed at lower edges of circulation orifices formed in casing pipe within the limits of oil pool to be developed. Number of packer sections included in the plant is equal to number of pools to be developed. The last packer section is between lower packer of next to last pool and one-way valve installed at flow string end.

EFFECT: possibility to optimize downhole plant parameters and to stimulate injection and/or fluid inflow simultaneously with plant installation.

8 cl, 1 dwg

FIELD: oil and gas production, particularly well interior separation for reservoir isolation one from another.

SUBSTANCE: device comprises packing members with elastic collars and reaming members, seating tool connected to lifting pipes and having lower part telescopically put on technological pipe, anchor, well screen and check valve. Each reaming member except for upper one is connected to body of each next upper packing member from below through intermediate pipe or pipes. Lower packing member body is secured to support pipes. Well screen is included in support pipe and/or one or several intermediate pipes opposite to each reservoir to be developed or treated. Check valve is located over upper well screen. Reaming member is made as thrust secured to telescoping pipe. Thrust of upper packing member has inner cavity and is connected to upper telescopic pipe by shear members so that the thrust may slide with respect to the pipe in axial direction. Thrust sliding is limited by upper annular widened section of upper telescopic pipe arranged inside thrust. Anchor is located over upper packing member thrust.

EFFECT: possibility to operate in wells having non-calibrated inner diameter, increased air-tightness of well interior separation.

2 cl, 1 dwg

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