Methods and devices for analysis of fluids in well

FIELD: measurement equipment.

SUBSTANCE: invention relates to analysis of the geological stratum fluids in the well for estimate and inspection of the stratum for the purposes of investigation and development of hydrocarbons production wells. The method and devices for analysis of stratum fluids in a well by way of separation (selection) of fluids from the stratum and/or borehole in the assembly for regulation of pressure and volume which is integrated into the flow line of the fluid analysis module and definition of isolated fluids characteristics. The required parametres may be deducted for stratum fluids in the static state and the undesirable stratum fluids may be drained and substituted with stratum fluids suitable for definition of characteristics or extraction of samples to the surface. The selected stratum fluids may be subject to circulation in the flow line circuit for definition of phase behaviour characteristics. Real time analysis of fluids may be performed under or almost under well conditions.

EFFECT: creation of method for analysis of stratum fluids in well by way of selection of fluids from the stratum and/or borehole into the analyser module flow line.

21 cl, 10 dwg

 

The technical FIELD

The present invention relates to the field of analysis present in the well fluids of the geological formation for evaluation and verification of the reservoir for the purposes of exploration and development wells production of hydrocarbons, such as oil or gas drilling wells. More precisely the present invention relates to methods and devices for separation (screening) of fluids and obtain characteristics of the isolated fluids in the well.

PRIOR art

Analysis of the fluid in the well is an important and effective research technology commonly used to assess the characteristics and nature of the geological formations containing hydrocarbons. While the exploration and development of oil fields include the analysis of the fluid in the borehole to determine the petrophysical and fluid properties of hydrocarbon reservoirs. Determining characteristics of a fluid is required to accurately assess the economic viability of hydrocarbon reservoir formation.

Usually in the hole in the collector layers is determined by a complex mixture of fluids, such as oil, gas and water. Located in the well fluids, also called reservoir fluids have characteristics, including pressure, temperature, volume, among other properties of the fluids, which determine the phase behavior of the various constituent elements of the fluids. To evaluate underground formations surrounding the wellbore, it is often desirable to obtain samples of formation fluids into the wellbore to determine the characteristics of fluids, including composition analysis, fluid properties and phase behavior. Drop the rope a research tool layer is disclosed, for example, in patents US 3780575 and 3859851, and the probe collector layer (RFT) and modular dynamic tester bed (MDT) from Schlumberger are examples of instruments sampling to extract samples of formation fluids from the wellbore for analysis at the surface.

Reservoir fluids under downhole conditions on the composition, pressure and temperature different from the fluid in the conditions on the surface. For example, the temperature inside the borehole can be in the range of 300F. When the samples are in the well fluids are transported to the surface, is the temperature change of the fluid with the accompanying changes in volume and pressure. Change fluids during transit to the surface can cause phase separation between the gaseous and liquid phases in the samples and the changing characteristics of the composition of the reservoir fluids.

Also known technologies to maintain the pressure and temperature of the samples extracted from the wells to get the samples on the surface, which is relevant to the comfort in the well formation fluids. In known systems, the samples in the borehole, are stored in a special chamber of the probe layer and transported to the surface for laboratory analysis. During transfer of the sample from the surface to the laboratory on the surface, the samples are often transferred from one flask or container for samples in another flask or container, such as a reservoir for transportation. Note that samples may be corrupted when you transfer from one vessel to another.

Moreover, the pressure and the temperature of the sample changes frequently during the delivery of samples from the location of wells in a remote laboratory, despite the technology used to preserve the samples under the conditions in the well. It is known that the transfer and transport of the samples of formation fluids they are damaged or deteriorate the formation of bubbles, precipitation of a solid phase in the sample, among other difficulties associated with the change of the characteristics of reservoir fluids for analysis on the surface and in the borehole fluid.

In addition, laboratory analysis in a remote location requires a lot of time. Issue analysis data sample is within a couple of weeks to months for the full analysis sample, which hampers the ability to meet the needs of users in real-time. Typically, the time interval is to get results, related to the analysis of formation fluids to the surface, is just a few months after the specimen was sent to a remote laboratory.

To address shortcomings in the analysis of reservoir fluids, carried out on the surface, the latest developments for analysis of fluid include technology characterization of reservoir fluids in the well or in the well bore. While the MDT may include one or more analysis modules fluids, such as analyzer composition of fluids (CFA) and the analyzer untreated fluids (LFA) from Schlumberger, for example, for analysis in the borehole fluid, select the tool, when the fluids are in the well.

In the analysis modules of the fluids in the well of the type indicated above, reservoir fluids, which must be assessed in the well, flow round the sensor module associated with the analysis module fluids, such as a module of the spectrometer, which analyzes the flowing fluid, for example, by infrared absorption spectroscopy. When this optical fluid analyzer (OFA), which can be located in the module analysis of fluids, can recognize the fluids circulating flow and to determine the amount of oil and water. In the patent US 4994671 disclosed downhole device containing the camera probe, a light source, specification of the Central detector, database and processor. The fluid flowing from the reservoir into the chamber of the probe, and analyzed by light direction on the fluid, the detection range of the past and/or reflected light, and processing of information (based on information in the database relating to different spectra), to determine characteristics of the formation fluids.

In addition, in patent US 5167149 and 5201220 disclosed a device for estimating the amount of gas in the fluid flow. Prism is attached to the window in a stream of fluid, and light is directed through the prism of the window. Light reflected from the surface of the window/flow of fluid under certain predetermined angles, detected and analyzed for the presence of gas in the fluid flow.

As described in patent US 5266800, tracking spectrum of optical absorption fluid samples obtained over time, provides the ability to determine when the most likely reservoir fluids than the mud filtrate, are flowing into the analysis engine fluids. In addition, as described in patent US 5331156 by measuring optical density (OD) of the fluid flow at certain intensities, can quantitatively determine the oil and water fractions of two-phase fluid flow.

On the other hand, samples, extracted from the wells analyzed in the laboratory on powernotebooks.com use of the pressure control unit and volume (PVCU), which operates at ambient temperature, and heating the sample fluid to reservoir conditions. However, there is a device PVCU, which would be capable of operating at high temperature well conditions. Traditional devices for changing the volume of fluid samples under the conditions of the wells using hydraulic pressure, but have one disadvantage in that it is difficult to precisely adjust the length of stroke and speed of the plunger when the conditions in the borehole due to changes in viscosity and expansion of oil, which are caused by extreme temperatures in the borehole. Moreover, at high pressures in the well is leaking oil in the annular seals that require additional maintenance of the device.

The INVENTION

The technical task of the present invention is to provide methods and devices for analysis of formation fluids into the borehole by means of a fluid from the formation and/or borehole in a flow line analysis module. In preferred variants of the invention, the fluids are selected using the control unit of pressure and volume (PVCU), which is integrated in a flow line, and the characteristics of the selected fluids are determined with the use of PVCU.

Mainly PVCU suitable for use in the well, and since proto is the Naya line and/or PVCU located in the well tool used for sampling formation fluids, unwanted formation fluids can easily drain freely and be replaced formation fluids that are suitable for determining the characteristics of the well. Another useful result is obtained through sampling of formation fluids according to the present invention, is that the analysis of pressure - volume - temperature (PVT) fluids can be carried out at or close to the conditions in the borehole using PVCU according to the present invention.

It is clear that there is a need for research in the borehole, which give accurate results there are products in accordance with the sampling in the well tool, such as the probe of the formation.

Analysis of formation fluids into the borehole, which is reliable and comparable to laboratory tests, fixes the problem of the destruction of a sample of formation fluid, caused by transportation to the surface.

The analysis in the hole eliminates the delay associated with the transfer of samples of formation fluids in a laboratory on the surface, provides results in real time at the location of the well.

Determining characteristics of a fluid, performed on the fluids, which are allocated from the reservoir or wellbore and are relatively stable, while in the static state, tends to be more the full-time, compared with the analysis in the borehole fluid, which are in the active state, i.e. flow through the borehole in the determination of their characteristics.

A sample of fluid taken from the flow line of the tool, compared with the sample fluid in the chamber of the sampling tool located in the borehole, has useful advantages as the selected fluid can be checked for quality and be replaced by others more accurately selected fluid, if the quality of the initial fluid was unsatisfactory for determining characteristics of a fluid. When you rinse line analysis module of fluids and to take a fresh layer of fluid for analysis, while the tool is in the borehole, whereas traditional camera and containers sampling may not have a means to drain the selected sample fluid and the teachings of another sample of the formation fluid when the tool is in the well.

The selection of fluid under conditions essentially similar conditions of formation or wellbore, provides significant advantages in the determination of fluid properties, because the definition of the point at which boiling takes less time when conditions in the well compared to laboratory conditions on the surface.

In preferred embodiments, the implementation of methods and devices for infusion is to him the invention of an instrument for use in a borehole provides a sampling of formation fluids from the formation or wellbore in a flow line of the tool. Mainly the flow line of the tool may include a control unit of pressure and volume (PVCU), which is integrated in a flow line, to change the pressure and volume of the selected formation fluids have been possible under the conditions of the well. Selected formation fluids can be analyzed by measuring fluid properties, such as composition, gas-oil ratio (GOR), BTU (British thermal units), density, viscosity, compressibility; determining the phase behavior of fluids, such as the pressure of the emergence of asphaltenes, point initial boiling point, dew point, and the measurement values of the pressure and temperature of the fluid.

In one of the embodiments of the present invention, the device for analyzing fluids in the borehole contains many devices, such as sealing valves that can be selectively controlled to stop and start the flow of formation fluids to at least sections of the flow line, and one or more sensors associated with the flow line of the device. In one of the preferred embodiments the unit PVCU includes a pump, for example, syringe-type, which is operatively connected with the flow line to the characteristics of the formation fluids collected in PVCU, could be varied by changing the volume of fluids.

In one of the preferred embodiments nastojasih the invention wireline fluid is withheld or withdrawn in a flow line through the sealing valves. Mainly, they can define the characteristics of the selected fluid. In one aspect of the invention, the optical sensor can measure the required properties of the fluid, such as hydrocarbon composition, GOR, BTU selected formation fluids. In another aspect of the invention is a device, such as sensor density and viscosity, can measure additional required properties of the fluid such as density and viscosity of the fluid. As another aspect of the invention, the sensor pressure/temperature gauge P/T) can measure the pressure and temperature of the fluid selected formation fluids.

Mainly PVCU can change the pressure fluid through the expansion of the volume of formation fluid within the flow line. In another aspect of the invention, the compressibility of the fluid can be measured using a variable volume or variable pressure, or can be determined by changing the density of the fluid or the level of optical absorption.

In another aspect of the present invention, the selected pressure formation fluid may be reduced to a certain pressure conditions that precipitated asphalt. For example, optical sensors can be used to determine asphaltene precipitation. A further reduction in pressure can cause gas components will be separated from the liquid phase. Example is, ultrasonic sensor and optical sensors can be used to determine the emission of gas bubbles.

If the stand-alone fluid is a gas condensate, when the fluid is at a certain pressure, condensate oil may come out of the gas condensate. For example, an optical sensor may be used to determine the condensate oil. Time-dependent properties can be monitored to determine the gravitational separation of phases. After completion of measurements of the selected sample fluid can drain freely in the drilling fluid, fresh layer of fluid to return to the flow line for flushing the flow line, and a sample of the formation fluid may be captured in the camera or flask sampling in borehole tool for transportation to the surface for laboratory analysis.

According to the invention, the analysis module fluid device characterization fluid includes a flow line to reservoir fluids flowed through the analysis module fluids. At least one selectively active device such as a valve and/or pump, in preferred embodiments of the invention may be provided for selection of a certain number of fluids in the flow line. At least one sensor is located on FR who offered line for measuring parameters of interest, related to the fluids in the flow line.

In preferred embodiments of the invention each of the first and second selectively operating device contains a valve. In other embodiments of the invention one of selectively operating device includes a pump, for example, the pumping, and the other contains the valve. Preferably the pump Assembly, such as a syringe pump of the type integrated with a flowing line, is provided for changing the pressure and volume of the isolated fluids.

One or more sensors, such as spectral sensor, optically connected to the flow line; fluorescent and gas sensor; a density sensor; a pressure sensor; a temperature sensor; the sensor bubbles/gas; based on MEMS (microelectromechanical system) sensor; an imaging unit images; a sensor resistivity; sensor chemical compositions; and scattering sensor, provided in the flow line to determine characteristics of the formation fluids in the flow line. In preferred embodiments, the implementation provided by the bypass flow line, and selectively operating the devices are designed for fluid bypass flow line. The circulation line connects the first end of the bypass flow line to the second end of the bypass flow line is, to selected fluids could be circulating in the circulation line and the bypass flow line by a circulation pump.

In one of the preferred embodiments of the invention one or more of the spectral detector, optically connected to the flow line; fluorescence detector and gas sensor chemical compositions; and sensor specific resistance is provided in the flow line to measure the required parameters of the fluid flowing through the flow line, and one or more of a density sensor; pressure gauge; measuring temperature; detector bubbles/gas; based on MEMS sensor, the shaper of images; and scattering detector is provided to measure the required parameters of the fluid in the bypass flow line.

According to the present invention, a method for determining well characteristics of reservoir fluids using in the well tool, containing the analysis module of the fluids in the flow line. How is that track at least the first required parameter related to the formation fluids flowing through the flow line; when a certain criterion for the first parameter of interest is satisfactory, restrict the flow of formation f is widow in the flow line through the work of dozens of selectively operating devices for separation of fluids at the site of the flow line analysis module fluids determine the characteristics of selected fluids through the one or more sensors in a flow line.

Other preferred embodiments of the method include determining characteristics of selected fluids by defining one or more fluid properties, including in one of the preferred embodiments by changing the selected pressure fluid by volume change of selected fluids before property definition or properties of the fluid, for example, one or more of the compressibility of the fluid, the appearance of asphaltene precipitation, point initial boiling point and dew point. Another preferred variant of the method includes the implementation of the selected circulation of the fluid in the closed loop flow lines and characterization of selected fluids, for example, by determining the phase behavior of selected fluids. Mainly time-dependent properties can be monitored to detect gravitational phase separation.

According to another variant implementation of the present invention proposed a tool for characterization of reservoir fluids located in the well in the reservoir oil. The analysis module fluid includes a flow line to reservoir fluids flowed across the it, with the bypass flow line and the circulation line connecting the first end of the bypass flow line to the second end of the bypass flow line, so that the fluids in the flow line can circulate under the action of the circulation pump. At least one sensor is located on the bypass flow line for measuring the required parameters of the fluid in the bypass flow line.

Additional advantages and features of the invention will be set forth in the following description.

BRIEF DESCRIPTION of DRAWINGS

Preferred embodiments of the present invention are explained below with reference to the accompanying drawings, on which:

Figure 1 depicts the layout of the device in the borehole according to the invention.

2 is a diagram of one of the embodiments of the system for analysis of formation fluids in a borehole according to the invention.

Figure 3 - diagram of one of the preferred embodiments instrumental columns with analysis module fluids containing the pressure control unit and volume (PVCU) for analysis of formation fluids in a borehole according to the invention.

4 is a diagram of one embodiment of the implementation of the analysis module of the fluid with the device PVCU for determining well characteristics of fluids through sampling of formation fluids according to the invention.

Figure 5 diagrams the device PVCU with a matrix of sensors in the module analysis of fluids according to the invention.

6 is a system diagram of the detector scattering device PVCU according to the invention.

7 is a block diagram of the sequence of operations of a method for determining well characteristics of formation fluids according to the invention.

Fig plot the change in the compressibility of the sample fluid according to the invention.

Fig.9 is a diagram of another version of the exercise device for determining well characteristics of fluids according to the invention.

Figure 10 - diagram of another version of the exercise device for determining well characteristics of fluids according to the invention.

A DETAILED DESCRIPTION of the PREFERRED embodiments

The invention is not limited to the specific disclosed forms. Rather, the invention should cover all modifications, equivalents and alternatives falling within the scope of invention, which is defined by the attached claims.

Below disclosed embodiments of and inventions.

The present invention is applicable to exploration and development of oil fields in areas where the analysis of fluids in the borehole using one or more analysis modules fluids, for example in modular dynamic tester bed (MDT) firm Schlumberger.

Figure 1 schematically presents a cross section working with the food according to the invention. A company car 10 is located at the location of the well that contains the wellbore or borehole 12 from the downhole tool 20, is suspended to the end of the rope 22. It is clear that instead of pull on the rope, the device could be used on draught line, collar logging while drilling, twisted piping systems or as hardware fixed or semi-permanent installation. The barrel 12 bore contains a fluid, such as water, mud filtrate, reservoir fluids, etc. Column 20 of the downhole tool and the cable 22 is designed for the utility vehicle 10, (Fig 1).

Figure 2 presents a sample implementation of a system 14 for analysis and sampling in the well formation fluids according to the invention, for example, if a utility vehicle 10 is located at the location of the wells. The system 14 of the wellbore contains a column of 20 downhole tool that can be used for analiza earth formations and analyzing the composition of fluids from the reservoir. The downhole tool 20 is suspended in the wellbore 12 to the lower end of a multiconductor logging cable or wire 22 wound on the winch 16. The logging cable 22 is electrically connected to the electrical system 24 control surface containing electronic equipment and systems, and less is key to the downhole tool 20.

The downhole tool 20 (Fig 3) includes an elongated housing 26, which houses the electronic components and modules, which are schematically shown in figure 2 and 3, to obtain the necessary or desired parameters from the column 20. Retractable Assembly 28 receiving fluid and a sliding element 30 of the anchoring tool placed on opposite sides of the elongated body 26. Assembly 28 receiving fluid provides selective overlapping or isolate the required sections of the wall 12 of the well bore to establish communication with the pressure or the fluid surrounding earth formation. Assembly 28 receiving fluid may be a module 29 single probe (figure 3) and/or module 31 of the packer (figure 3). Examples of downhole tools disclosed in the aforementioned US patents 3780575 and 3859851, and in US 4860581.

One or more modules 32 analysis of fluids is provided in the housing 26 of the tool. The fluids drawn from the formation and/or wellbore, flow along the flow line 33 through the module or modules 32 analysis of fluids, and then go through the hole of the module 38 pumping. Alternative reservoir fluids in the flow line 33 may be sent to one or more cameras 34 and 36 of the collection of fluids, such as cameras samples 1, 2, 3/4, or 6 gallons, and/or six mnogoatomnykh modules 450 cubic centimeters, for receiving and holding fluid received from the reservoir, for which transportirovki to the surface.

Assembly receiving fluids, one or more analysis modules of fluid channels and chambers of the collection, as well as other working elements of a column 20 of the downhole tool is controlled by electrical control systems, such as surface system 24 electric control (figure 2). Preferably, the system 24 electric control and other control systems located in the housing 26 of the tool include, for example, the processor to determine characteristics of the formation fluids in the tool 20, as described in more detail below.

System 14 according to the invention in its various embodiments implement preferably includes a control processor 40, associated with the column 20 of the downhole tool. Control processor 40 shown in figure 2 as element 24 electric control. Preferably the methods of the present invention is embodied in a computer program, which is processori 40 are, for example, the control system 24. During the work on the program is receiving data, for example, from the module 32 analysis of fluids through the tether cable 22 and to transmit control signals to the working elements of a column 20 of the downhole tool.

The computer program may be stored on the computer storage medium 42 that is associated with what recession 40, or it may be stored on an external is used by the computer storage medium 44, and is connected to the processor 40 for use as needed. The carrier 44 can be any one or more of the known storage media such as magnetic disk inserted in the drive, or optical read CD-ROM on the CD-ROM), or a human-readable device of any kind, including remote storage device connected via the public switched line telecommunications, or future storage media suitable for assignments and objectives described in materials of this application.

In preferred variants of the invention, methods and apparatus may be embodied in one or more analysis modules fluids tool probe reservoir company Schlumberger modular dynamic probe layer (MDT). The present invention mainly provides a tool for probe formation, such as the MDT, with enhanced functionality for determining well characteristics of fluids and sampling of formation fluids. The tool probe layer mainly can be used for sampling formation fluids and determining well characteristics of reservoir fluids.

Figure 4 shows a diagram of one of the preferred embodiments of the module 32 Ana is the study of fluids with the node 70 of the control pressure and volume (PVCU). In a preferred embodiment of the invention, the device 70 PVCU can be integrated in a flow line 33 of module 32. One or more sensors 11 (one sensor is shown schematically in figure 4) and the devices 52 and 54 (hereinafter also indicated as valves) to stop and start the flow of fluids connected with the flow line 33. For example, the devices 52 and 54 (figure 4) can be sealing valves containing electrically operated stepper motor with an associated plunger arrangement for opening and closing the valve. At the same time the devices 52 and 54 can be any suitable device flow control, such as a pump, valve or other mechanical and/or electrical device for starting and stopping the flow of fluids in the flow line 33. One or more devices 52 and 54 can be positioned in module 32 analysis of fluids or may be located in other related modules of the tool 20, such as module 38 pumping. As necessary for the implementation in practice of the present invention can be used in combination of devices.

The device 70 PVCU includes a pump 71, for example a syringe pump type. The pump 71 adjusts the volume of the formation fluid in the flow line 33 between the valves 52 and 54. The pump 71 contains an electric pulse motor 73 direct current (DC); screw 79 on a spherical support;Assembly 80 of the plunger and bushing with o-ring seal (not shown); connection 93 of the engine and screw on the ball bearing; bearings 77 screw on ball socket; and clutch 75, connecting the screw 79 on a spherical support with the plunger 80. Primarily the device 70 PVCU and the pump 71 is operable at high temperatures up to 200C. the Section of the flow line 33 with the inlet valve (e.g. valve 52) is directly connected with the pump 71 to reduce the dead volume of the isolated formation fluid. Using the location of the plunger 80 of the pump 71 along the same axial direction as the inlet segment of the flow line 33, the void volume of the isolated fluids is reduced, because the amount of fluid remaining in the flow line 33 from the previously selected samples of fluids affects the properties of the fluid subsequently selected fluids.

Flow line 33 may be branched into two directions, with one branch attached to the exhaust valve, and the other connects to the meter 64 pressure/temperature control characteristics of the pressure/temperature of fluids in the flow line 33. In the embodiment shown in figure 4, the pump 71, for example, contains the stepping/pulse motor 73 DC with gear mechanism to reduce the effect of free running, the screw 79 on the ball bearing, the arrangement 80 of the plunger and the sleeve, and the sensor 82 linear position, this ka is the potentiometer. To reduce the free running of the engine can be used gearbox gear 1/160, and for precisely controlling the position of the plunger 80 can be used stepper motor DC pulse of 1.8 degrees. The axis of the plunger 80 may be offset from the axis of the screw 79 on the ball bearing and the motor 73, so that the total length of the tool is minimized.

During operation, rotational movement of the motor 73 is transmitted to the axial displacement of the plunger 80 through the screw 79 on ball bearing guide with key 91. The volume change can be determined according to the value of displacement of the plunger 80, which can be measured directly by an electric potentiometer 82, for example, along with a precise and variable control rotation of the motor 73, with one pulse of 1.8 degrees. Electric pulse motor 73 DC can change the amount of fluid held in a flow line, through the motion of the plunger 80, attached to the motor 73, as control electronics, which uses the signals of the position sensor. Because the preferred embodiment of the invention includes a pulse motor and the position sensor high resolution work PVCU can be adjusted with a high degree of accuracy. The volume change is calculated by square conduct the displacement of the plunger, multiplied by the distance detected by the displacement sensor or linear position, such as a potentiometer, which is connected to the plunger. During the change of volume of several sensors, such as pressure sensors, temperature, chemical composition and density, can be measured properties of the sample fluid, located between two sealing valves 52 and 54.

When it is determined that flow through line 33 flow reservoir fluids that meet certain criteria, sealing the valves 52 and 54 are closed to capture fluids in PVCU 70 when the conditions in the well. The motor 73 may operate to change the volume of the isolated fluids. The position displacement of the plunger 80 can be measured directly by the sensor 82 of the plunger fastened by nut connections 95 and clutch 75 with the plunger 80, while the pulse input to the motor 73 precisely regulates the speed and distance of movement of the plunger 80. PVCU 70 is configured based on the desired operating characteristics of the engine, the required ambient conditions in the well, working time, reducer and step screw on ball bearing. After measuring characteristics of fluids completed sensors and measuring devices of the module 32, the plunger 80 is returned to its initial position, and the UE is UNITLINE valves 52 and 54 are opened, so PVCU 70 is ready for another operation.

Figure 5 schematically presents one of the preferred embodiments of the node 70 of the control pressure and volume (PVCU)containing a matrix of sensors arranged in the module 32 analyzing fluids according to the present invention. As shown in figure 2, the module 32 is connected in fluid flowing through the line 33 to the reservoir surrounding the wellbore 12 wells. In one of the preferred embodiments the device 70 contains two PVCU sealing valve 52 and 54 associated with the flow line 33. Valves 52 and 54 are positioned to regulate the flow of fluids in the segment of the flow line 33 and to isolate formation fluids in the segment of the flow line 33 between the two valves 52 and 54. According to variants of implementation of the present invention the valves, such as high-temperature high-pressure valves, suitable for use in the borehole, can be used to regulate the flow of fluids in the flow line 33. For example, can be used throttle and sealing valves.

One or more optical sensors, such as 36-channel optical spectrometer 56, connected by fiber-optic harness 57 with an optical element or a Refractometer 60, and/or the detector 58 fluorescence and gas can be installed on the flow line 33 IU the DN sealing valves 52 and 54. Optical sensors can mainly be used to determine characteristics of a fluid flowing through or held in a flow line 33. In patents US 5331156 and 6476384 and in the publication No. 2004/0000636 A1 discloses methods for determining the characteristics of the formation fluids.

The sensor 62 density and/or sensors 64 pressure/temperature can also be provided in the flow line 33 for measuring the density, pressure and/or temperature relative to the fluid in the segment of the flow line between the sealing valves 52 and 54. When the sensor density and/or viscosity, such as x-ray sensors, the sensors of gamma radiation, rod and wire vibration sensors, mainly can be used to determine characteristics of a fluid according to the options of implementing the present invention.

The sensor 74 resistivity and/or sensors 69 chemical composition can also be provided on the flow line 33 for measuring the electric resistance of the fluid and/or for the detection of CO2H2S, pH (hydrogen ion exponent), among other chemical properties in relation to the fluids in the flow line between the sealing valves 52 and 54. In the patent US 4860581 disclosed a device for analyzing fluids by means of measurements in the borehole pressure and/or electrical resistance f is widow.

Ultrasonic transducer 66 and/or microabrasions and microelectromechanical (MEMS) sensor 68 density and viscosity may also be provided for measuring characteristics of fluids flowing through or captured in the flow line 33 between the valves 52 and 54. In the patent US 6758090 and publishing 2002/0194906 A1 discloses methods and apparatus for determining the pressure point initial boiling point and based on MEMS sensors fluids, respectively.

System 76 scattering detector may be provided in the flow line 33 for tracking phase separation in the selected fluids through the detection of particles, such as asphalt, bubbles, oil mist from the gas condensate coming out of the fluids in the flow line 33. Figure 6 schematically shows a system detector scattering device 70 according to one of embodiments of the present invention. Mainly the detector 76 scattering can be used to track the phase separation by identifying point initial boiling point, as represented graphically in Fig.6.

The detector 76 scattering includes a source 84 of light, the first photodetector 86 and, not necessarily, the second photodetector 88. The second photodetector can be used to assess the intensity fluctuations of the source 84 light to confirm that treason is s or decrease in intensity due to the formation of bubbles or solid particles in formation fluids, which are investigated. The source 84 of light can be selected from a halogen source, an LED (light-emitting diode, LED), laser diode, among other known light sources suitable for the present invention.

The detector 76 scattering also includes high-temperature element 90 sampling of high pressure with Windows, so that light from a source 84 of the light passes through the reservoir fluids flowing through or held in a flow line 33, on the photodetector 86 on the other side of the flow line 33 from a source 84 of light. Suitable optics 92 may be provided between the source 84 of light and a photodetector 86, so that the light from the source 84 of the light is collected and directed to the photodetector 86. By selecting the optical filter 94 may be provided between the lens 92 and the photodetector 86. Since the effect of scattering depends on the particle size, i.e. the maximum for wavelengths that are similar to or smaller than the size of the particles, by selecting the appropriate wavelength using an optical filter 94 is possible to obtain data on the sizes of the bubbles/particles.

The pump Assembly 71 (figure 5), such as a node syringe pump can be installed on the flow line 33 to regulate the volume and pressure of fluids held in the flow line 33 between the valves 52 and 54. System 72 forming the image is of Ajani, such as CCD, charge-coupled devices) CCD camera, may be provided on the flow line 33 for forming the spectral image to determine characteristics of the phase behavior of fluids in the borehole, as disclosed in pending application No. 11/204134 for the grant of a U.S. patent, with the same priority as the present application.

Figure 7 presents a flowchart of the operational sequence of the method, one of practicelink methods according to the present invention for the analysis and sampling of fluids in the borehole and the formation of interest return results based on the definitions in the borehole characteristics of fluids. When work begins module 32 analysis of fluids (step 100 figure 7), the probe 28 is drawn from a tool of the column 20 for contact with the reservoir. Module 38 involves pumping wireline fluid in a flow line 33 (step 102) and drains it into the mud. Module 32 analyzes the level of contamination of the sample and phase separation (step 103), while the fluid flows inside the flow line 33. In the patent US 5266800 disclosed are methods of distinguishing between the fluid containing the original oil drilling fluid and the reservoir oil samples.

After the pollution has reached a level, which is defined as a sufficiently low to determine the characteristics of the individual who Idov and/or collection of the sample, for example, pollution from about 0% to about 10%, and the fluid in the flow line 33 is confirmed as a single phase, two sealing valve 52 and 54 are closed, so that the layer of fluid is isolated or captured in the flow line 33 between the valves 52 and 54 (step 104). Sensors and measuring devices 32 may be drawn for measurement of fluid properties such as density and viscosity of the formation fluid collected in the flow line 33 (step 105), as well as pressure and temperature (step 106) formation fluid.

The pump Assembly 71 may be operated to change the selected pressure of the fluid in the flow line 33 (step 108). The sensor device 32 can be implemented to track and record the compressibility and phase behavior of selected fluid, such as the onset of asphaltene precipitation, point initial boiling point (steps 110 and 112).

System 72 forming video images, such as a CCD camera, can be used to monitor the deposition of asphaltenes, emission of bubbles and separation of liquid from gas condensate. Shaper 72 images can be used to measure changes in the volume of precipitated asphaltenes, when fluid pressure is reduced.

After completion of measurements of the selected sample fluid can drain freely in the drilling fluid (step 114). A fresh layer of fluid can be involved in PR is the exact line for flushing flow line (step 116). A sample of the formation fluid may be captured in podhodjashuju chamber or flask sampling in borehole tool for transportation to the surface for laboratory analysis (step 118).

On Fig chart presents changes in the compressibility of the sample fluid. The compressibility of the fluid is calculated based on the initial volume, the changed volume and reduced pressure. Thus the compressibility of the fluid held in the flow line can be calculated at a reduced pressure and an increased volume of fluid, derived from the displacement recorded by the displacement sensor, or position, such as a potentiometer 82.

Figure 9 schematically shows another preferred variant implementation module 32 analyzing fluids according to the present invention. The device 70 includes the bypass flow line 35 and the circulation line 37, communicating the fluid through the main flow line 33 with the formation surrounding the wellbore. In one of the preferred embodiments the device 70 includes two sealing valve 53 and 55 associated with the bypass flow line 35. The valves 53 and 55 are positioned to regulate the flow of fluids in the segment 35 bypass flow line of the main flow line 33 and to isolate formation fluids in the bypass flow line 35 between TLDs what I valves 53 and 55. The valve 59 may be placed in the main flow line 33 for controlling the flow of fluid in the main flow line 33.

One or more optical sensors, such as 36-channel optical spectrometer 56, connected by fiber-optic harness 57 with an optical element or a Refractometer 60, and/or the detector 58 fluorescence/refraction can be installed on the bypass flow line 35 between the valves 53 and 55. Optical sensors can mainly be used to determine characteristics of a fluid flowing through or held in the bypass flow line 35.

The meter 64 pressure/temperature and/or the sensor 74 resistivity can also be provided in the bypass flow line 35 for measuring the electric resistance, pressure and/or temperature of the fluid in the bypass flow line 35 between the sealing valves 53 and 55. The sensor 69 chemical composition may be provided for measuring characteristics of fluids, such as CO2H2S, pH, among other chemical properties. Ultrasonic transducer 66 and/or sensor 68 density and viscosity can also be provided for measuring characteristics of fluids flowing through or captured in the bypass flow line 35 between the valves 53 and 55. The pump Assembly 71 may be set to about the full line 35 for regulating the volume and pressure of formation fluids, held in the bypass flow line between the valves 53 and 55. Shaper 72 images, such as a CCD camera, may be provided in the bypass flow line 35 for forming the spectral image to determine characteristics of the phase behavior in the well fluids isolated in it.

System 76 scattering detector may be provided in the bypass flow line 35 for detecting particles such as asphalt, bubbles, oil mist from the gas condensate, which are isolated from fluid in the bypass flow line 35. The circulation pump 78, for example a gear pump or pump Sanchez, may be provided in the circulation line 37. Since the circulation line 37 is flowing contour line of the bypass flow line 35, the circulation pump 78 can be used for circulation of fluids that are selected in the bypass flow line 35, in the circuit formed by the bypass flow line 35 and the circulation line 37.

In variants of the implementation depicted in figure 4 and 5, after formation fluids isolated or captured in the flowing lines 33 through valves 52 and 54, further flow of fluids in the flow line 33 is stopped. However, in some cases, it may be undesirable on travlemate the fluid flow in the main flow line 33, as if the valve in the main flow line 33 was put out of action, work must be stopped to replace the defective valve. To take action, which stops fluid flow in the main line 33 is not preferable to determine characteristics of the fluid, is provided by the bypass flow line 35 by a variant of the implementation of figure 9, and the sensors and the measuring device module 32 analysis of fluids located in the bypass flow line 35. In the embodiment of the invention (Fig.9) flow of fluids can be stored in the main flow line 33, even after layer fluid was selected in the bypass flow line 35. Alternatively, the valve 59 may regulate the flow of fluid in the main flow line 33.

The measurement accuracy of the phase behavior improves, if an isolated sample of the fluid in the bypass flow line 35 is exposed to the circulation line of a closed loop. Accordingly, the bypass flow line 35 closes the circuit through the circulation line 37, and the circulation pump 78 is provided in a closed circuit flow lines 35 and 37, so that the formation fluids in the bypass flow line 35 may be subjected to circulation, for example, during the characterization phase behavior.

Figure 10 schematically presents another predpochtitel the hydrated version of the implementation module 32 analyzing fluids according to the present invention. The device 70 is similar to the variant of implementation of figure 9 with the bypass flow line 35 and the circulation line 37 in the message to the fluid through the main flow line 33 with the formation surrounding the wellbore. The device 70 figure 10 contains two valves 53 and 55 associated with the bypass flow line 35. The valves 53 and 55 are positioned to regulate the flow of fluids in the segment 35 bypass flow line of the main flow line 33 and to sample formation fluids in the bypass flow line 35 between the two valves 53 and 55. The valve 59 may be placed in the main flow line 33 for controlling the flow of fluid in the main flow line 33.

The device 70 (figure 10) is similar to the device of figure 9, except that one or more optical sensors, such as 36-channel optical spectrometer 56, connected by fiber-optic harness 57 with an optical element or a Refractometer 60, and/or the detector 58 fluorescence/refraction, installed on the main flow line 33 instead of the bypass flow line 35, as in Fig.9. Optical sensors can be used to determine characteristics of the fluids that flow through the main flow line 33, as the dimensions of the optical sensors require a stand-alone static fluid. Instead of the layout depicted in figure 9, the sensor 74 unit is about resistance and the sensor 69 chemical composition can also be provided in the main flow line 33 in the embodiment, figure 10, to get the measurement of electrical resistance of the fluid and chemical measurements in relation to the fluids flowing through the main flow line 33.

The meter 64 pressure/temperature can be provided in the bypass flow line 35 to obtain measurements of pressure and/or temperature relative to the fluid in the bypass flow line 35 between the valves 53 and 55. Ultrasonic transducer 66 and/or sensor 68 density and viscosity can also be provided for measuring characteristics of fluids flowing through or captured in the bypass flow line 35 between the valves 53 and 55.

The pump Assembly 71 can be installed on the flow line 35 for regulating the volume and pressure of fluids held in the bypass flow line between the valves 53 and 55. Shaper 72 images, such as a CCD camera, may be provided in the bypass flow line 35 for forming the spectral image to determine characteristics of the phase behavior in the well fluids. System 76 scattering detector may be provided in the bypass flow line 35 for detecting particles such as asphalt, bubbles, oil mist from the gas condensate coming out of the fluid in the bypass flow line 35. Mainly the circulation pump 78 can the t to be provided on the circulation line 37. Since the circulation line 37 is flowing contour line of the bypass flow line 35, the circulation pump 78 can be used for circulation of fluids, which are isolated in the bypass flow line 35, in the circuit formed by the bypass flow line 35 and the circulation line 37.

The ends of the flow line 33 extending from the module 32 analysis of fluids, can be connected with other modules in the tool probe layer, for example with CFA and/or LFA. The fluid extracted from the formation and/or wellbore, flow through a flow line for analysis of fluids in the borehole by means of interconnected modules. When working in the well tool 20, the valve device 70 is normally open. Sensors and meters, located on the flow line can be selectively enabled for tracking characteristics of the formation fluids through the flow line.

Mostly the methods and apparatus according to the present invention have two approaches for the characterization of reservoir fluids. One concerns the analysis of flowing fluid, and the second concerns the analysis selected or trapped fluid. The data analysis of the flowing sample may be provided to the user on the surface, but can also be used for correction and/or determine the action the reality of the data analysis of selected fluids.

When it turns out that the fluid flowing through the flow line, is a single phase, i.e. the reservoir oil or water, or gas without phase separation, and the level of contamination of the fluid is confirmed as unchanged and is at a certain level for the purpose of analyzing the properties of the fluid, the valves 52 and 54 in the flow line 33 (figure 4 and 5) are closed, and the sample fluid is collected or captured in the flow line. After wireline fluid isolated segment of the flow line, the fluid properties, such as composition, GOR and BTU can be measured, for example, an optical spectrometer. In patents US 5859430 and 5939717 disclosed method and device for determination of GOR and composition analysis.

The density sensor can measure the density of the isolated formation fluid. MEMS, for example, can measure the density and/or viscosity, and meter P/T can measure pressure and temperature. The sensor of the chemical composition to identify the different chemical properties of formation fluids, such as CO2H2S, pH, among other chemical properties.

The pump Assembly attached to the flow line, may increase the volume of the sample fluid, i.e. in the flow line fluid pressure is reduced. When the pressure drop is a consequence of the phase transition, time-dependent signals can be generated in the sensors as gravity which include phase separation, as further discussed in Asphaltene Precipitation from Live Crude Oil, Joshi, N.B. et al., Energy&Fuels 2001, 15, 979-986 (asphaltene Precipitation from crude oils, Josie NB and others, Energy&Fuels, 2001, t.15, SCR-986). Thus by monitoring properties of the sensors with respect to time can be observed gravity separation.

In addition to the methods described above, the compressibility of the isolated fluid can be measured by using a density sensor, an optical spectrometer and pump. Pressure fluid can further be reduced, so that the phase behavior of a fluid, such as the emergence of asphaltene, point initial boiling point, the dew point can be measured by the spectrometer, a fluorescence detector and gas and ultrasonic transducer.

In other preferred embodiments, the implementation of the present invention (figures 9 and 10) module 32 analysis of fluids can be one of the modules in the sequence of interrelated modules of the tool probe layer, such as MDT firm Schlumberger. When the well starts work with the tool probe layer, the probe 29 (figure 3) is extended from the tool 20 and is attached to the reservoir (build 28 figure 2). The tool 20 retrieves the layer of fluid, which passes into the chamber of the probe under pressure, to measure formation pressure. After the analysis under gallerieswired, module 38 pumping (figure 3) is included to draw formation fluid into the main flow line 33 (figures 9 and 10) and for drainage of formation fluids into the wellbore, i.e. in the drilling fluid surrounding the tool 20 in the wellbore. Sensors and devices located on a flow line, such as a spectrometer, a fluorescence detector, sensor, resistivity sensor, D/V, track changes in the level of pollution in the reservoir fluids, which flow along the flow line. When the levels of contamination of fluids reach a certain level, and phase fluid is confirmed as a single phase, in this case, the valve 59 main flow line module 32 is closed, and the valves 53 and 55 bypass flow line is opened, so that the layer of fluid flowing in the bypass flow line 35 to replace the previous fluid in the bypass flow line 35. The valves 53 and 55 bypass flow line is then closed and valve 59 to the main flow line 33 is opened, so that the layer of fluid is collected or captured in the bypass flow line 35 between the valves 53 and 55.

Upon selection of the formation fluid in the bypass flow line 35 can be measured characteristics of the isolated formation fluid, such as density, viscosity, chemical composition, pressure and temperature. Circulating us is 78 can be included for circulation or mixing of the formation fluid in the bypass flow line 35. The pump Assembly may be included to increase the amount of formation fluid in the bypass flow line 35, so that the fluid pressure is decreased. The detector scattering, US-Converter and/or a CCD camera can be used to measure point initial boiling point of the selected formation fluids.

During the analysis of pressure - volume - temperature (PVT) selected formation fluids or after the PVT analysis is completed, a sample of formation fluid may be captured in one or more chambers of sampling, such as 34 and 36 (figure 3), for analysis at the surface. Then, the tool 20 can move to the next point in the reservoir.

In the known methods and device sample formation fluid is drawn into the well, and then transported to the laboratory on the surface for analysis. You need a special camera or container sampling to maintain the pressure and temperature of the sample under the conditions in the well, in order to avoid damage and deterioration of the sample of the formation fluid. Moreover, analysis of the sample in the laboratory on the surface different from the conditions in the well, causing unpredictable and unacceptable changes in the analytical data and erroneous results derived from the analysis of reservoir fluids.

The present invention eliminates the need for specialized camera DL the storage and analysis of reservoir fluids. Flow line located in the well tool probe of the formation through which formation fluids flow during normal operation in the well tool, mainly can be used for sampling formation fluids to determine characteristics of a fluid in the borehole. Moreover, the same flow line can be used to change the conditions of the fluid for measurement of additional fluid properties and phase behavior of the isolated fluids.

The preceding description has been presented only to illustrate and describe the invention and some examples of its implementation. Many modifications and variations are possible in light of the above doctrine.

Preferred aspects were chosen and described to best explain the principles of the invention and its practical application. The preceding description is intended to provide opportunities for other professionals in the art to best utilize the invention in various embodiments and aspects and with various modifications that are possible for the intended practical use. It is implied that the scope of the invention defined by the subsequent claims.

1. Device for determining characteristics of a fluid in a borehole containing
Odul analysis of fluids which contains:
a flow line for directing fluid extracted from the formation, through the analysis module fluids, having a first end for entry fluid and a second end for outputting fluid from the analysis module fluids
first selectively active device and a second selectively operating the device, installed on the flow line branch (selection) a certain amount of fluid at the site of the flow line between the first and second selectively operating devices; and
at least one sensor located on a plot of flow line between the first and second selectively operating devices for measuring the required parameters of the fluids in the flow line.

2. The device according to claim 1, characterized in that
at least one of the first and second selectively operating device contains a valve.

3. The device according to claim 1, characterized in that
one of the first and second selectively operating device includes a pump, and the other of the first and second selectively operating device contains a valve.

4. The device according to claim 3, characterized in that
the pump module is pumping device characterization of fluids in the well.

5. The device according to claim 1, characterized in that
the analysis module fluids further comprises pumping node, integrated in p is otocol line and designed to change the pressure and volume of selected fluids.

6. The device according to claim 5, wherein the pump Assembly includes a pump syringe type.

7. The device according to claim 1, characterized in that the at least one sensor comprises multiple sensors.

8. The device according to claim 1, characterized in that the at least one sensor selected from the group consisting of one or more spectral sensors, optically connected to the flow line, fluorescent and gas sensor, density sensor, pressure sensor, temperature sensor, sensor bubbles/gas based on MEMS sensor, shaper image, sensor, resistivity sensor chemical composition and scattering sensor.

9. The device according to claim 1, characterized in that
the plot flowing lines for fluid contains a bypass flow line, the first and second selectively operating device mounted on the bypass flow line for sampling fluids
the circulation line connecting the first end of the bypass flow line to the second end of the flow line, so that the fluid located between the first and second selectively operating devices, can circulate in a closed loop formed by the circulation line and the bypass flow line, the analysis module fluids further comprises a circulation pump for circulating flue what s in a closed loop circulation line and the bypass flow line.

10. The device according to claim 9, characterized in that at least one sensor includes one or more sensors selected from the group consisting of a density sensor, pressure sensor, temperature sensor, sensor bubbles/gas based on MEMS sensor, shaper images and scattering sensor, at least one sensor is designed to measure the required parameters of the fluid in the bypass flow line;
while the analysis module fluids further comprises:
one or more sensors selected from the group consisting of a spectral sensor, optically connected to the flow line, fluorescent or gas sensor, sensor chemical composition and sensor resistivity installed on the flow line and designed to measure the required parameters of the fluid flowing through the flow line.

11. The method of determining well characteristics of reservoir fluids using in the well tool, containing the analysis module fluids containing a flow line for the flow of fluids through the analysis module fluids, namely, that
monitor at least the first required parameter of reservoir fluids flowing through the flow line when the specified criterion for the first interesting is th parameter is satisfactory, restrict the flow of fluids in the flow line by selectively control the first operating device and a second selectively operating device analysis module fluids for separation (selection) of formation fluids at the site of the flow line analysis module of fluids between the first and second selectively operating devices and define the characteristics of the separated (selected) fluid through the one or more sensors on the flow line between the first and second selectively operating the device.

12. The method according to claim 11, characterized in that
when determining the characteristics of the isolated fluids define one or more fluid properties of selected fluids.

13. The method according to item 12, wherein when determining one or more properties of the fluid change the selected pressure of the fluids for which changes the volume of the isolated fluids before define one or more fluid properties.

14. The method according to item 13, wherein the additional monitoring time-dependent signals in one or more sensors on the flow line to detect gravitational separation of the isolated fluids.

15. The method according to item 13, wherein the one or more properties of the fluid, determined after a change in pressure of the fluid, use one ilible parameters from the group consisting of compressibility of the fluid, the appearance of asphaltene precipitation, point initial boiling point and dew point.

16. The method according to claim 11, characterized in that it further
when determining the characteristics of the isolated fluids are isolated circulation of fluids in the closed loop of flowing lines.

17. The method according to item 16, characterized in that when determining the characteristics of the isolated fluids determine the phase behavior of the isolated fluids by circulating fluid in a closed loop.

18. The method according to 17, characterized in that when determining the phase behavior of the isolated fluids monitor time-dependent properties of the sensor for the detection of gravitational phase separation.

19. Tool for characterization of reservoir fluids located in the bore in the reservoir oil, containing the analysis module fluids, which contains a flow line for directing fluid extracted from the formation, through the analysis module fluids, having a first end for entry fluid and a second end for outputting fluid from the analysis module fluids
moreover, the flowing line contains:
the bypass flow line and the circulation line connecting the first end of the bypass flow line to the second end of the bypass flow line, so that the fluid can circulate in circulation the second line and the bypass flow line,
while the analysis module fluids further comprises a circulation pump for circulating the fluid in the circulation line and the bypass flow line,
at least one sensor located on the bypass flow line for measuring the required parameters of the fluid in the bypass flow line, and
first selectively active device and a second selectively operating the device, installed on the flow line branch (selection) a certain amount of fluid in the bypass flow line between the first and second selectively operating the device.

20. The tool according to claim 19, characterized in that
at least one sensor includes one or more sensors selected from the group consisting of a density sensor, pressure sensor, temperature sensor, sensor bubbles/gas based on MEMS sensor, shaper images and scattering sensor, with at least one sensor is designed to measure the required parameters of the fluids collected in the bypass flow line, the analysis module fluid additionally contains
one or more sensors selected from the group consisting of a spectral sensor, optically connected to the flow line, fluorescent or gas sensor, sensor chemical composition and sensor specific resistance, set the on flow line for measuring the required parameters of the fluids, flowing through the flow line.

21. The tool according to claim 20, characterized in that
at least one of the first and second selectively operating device contains a valve, the analysis module fluids further comprises pumping node, integrated in a flow line, to change the pressure and volume of the isolated fluids.
Priority: 29.04.2005 and 15.08.2005 - all claims.



 

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16 cl, 2 dwg

FIELD: oil-and-gas production.

SUBSTANCE: sampler, consisting of system of fluid sampling, includes sampling valve and storage of fluid sample, electrohydraulic system. Electrohydraulic system is implemented as logical for fixation and unlock of sampler in well, which includes electric motor, connected to pump, which is connected to the first distributor through return valve, with filter, with safety valve and with the second distributor, connected to valve of sampling and storage of fluid sample, and also to the first, to the second, to the third and to the fourth sensor - pressure limit switch, the first distributor is connected parallel to head end of the first hydraulic ram, of the second hydraulic ram and the third hydraulic ram, stocked cavities of which are connected to third distributors, hydraulic accumulator, to the fifth sensor - pressure limit switch and to the fourth distributor.

EFFECT: reliability enhancement of sampler operation, improvement of automation of sampling and extension of capabilities.

1 dwg

Depth sampler // 2360109

FIELD: mining.

SUBSTANCE: depth sampler consists of ballast chamber, of actuator with module of control, of main and additional sample taking chambers equipped with medium-separating pistons, hydro-resistors and valve units. Each medium-separating piston is equipped with a compensating tube, which connects under-piston cavities of sampling chambers between them. Also hydro-resistor is assembled at the end of each tube.

EFFECT: simplification and upgraded efficiency of operation of units of device, decreased dimensions of sampler, improved quality of separation of taken samples, and validity of measured information.

1 dwg

FIELD: physics, measurements.

SUBSTANCE: proposed set of inventions relates to oil product, particularly, to getting and analysing the samples of in-place fluid medium. The proposed method comprises the steps that follow. First, optical density data on fluid medium sample is obtained for, at least, one-colour channel, water channel or a set of optical channels by measuring wavelength optical density with the help of fluid medium analyszer, and, at least, in one channel of fluid medium component to determined the fluid medium composition or properties with the help of fluid medium downhole sampler furnished with optical pickup. The colour absorption function is defined based on optical data for fluid medium sample in, at least, one colour channel. The part of optical density subject to color absorption, absorption in water in, at least, one aforesaid channel of fluid medium component. The electronic system designed to refine the data on the fluid medium sample incorporates an input device, memory coupled with input device and memory.

EFFECT: accurate data on fluid medium sample resulted from elimination of colour, water and scattering effects.

25 cl, 13 dwg

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes picking a sample of bed fluid under pressure by means of pump. Sample of fluid is then compressed by moveable piston, actuated by hydrostatic pressure in well through valve. Compressed sample of bed fluid is contained under high pressure inside the chamber with fixed volume for delivery to well surface. Moveable piston is in form of inner and outer bushings, moveable relatively to each other. At the same time several tanks for picking samples from several areas may be lowered into well with minimal time delays. Tanks may be emptied on well surface by evacuation pressure, to constantly provide for keeping of pressure of fluid sample above previously selected pressure.

EFFECT: higher reliability.

6 cl, 14 dwg

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