RU2351757C1 - Methods of measuring oil well yield and device for implementation of this method (versions) - Google Patents

Abstract

FIELD: oil and gas industry.

SUBSTANCE: invention refers to oil extracting industry and can be implemented for measurement of yield of two-phase three-component oil-water mixture flowing from wells for each component separately. The device consists of a gas separator with a product selector and a float connected with a gate on a gas line uniting the gas separator and a valve with a collective line via a volume and weight flow meters. The gas separator is also connected to an emergency capacity and to the collective line through a gravitation separator with a siphon product selector, the volume and weight flow meters and the valve by means of a liquid line. The gate is equipped with a bypass turning the compensation capacity and the valve on. There is a block for calculation, yield assessment, registering and analysis of measurement results. The valves are designed with their end positions fixation and with capability to open the flow above the minimal. The method consists in separating a gas phase from a liquid one, in measuring the consumption and calculating the density, in two-stage separation of the liquid phase: preliminary in the process of accumulation and finally in gravitational separation of random drops of oil after throttling into components. Then alternate selecting of portions of each component is carried out. Also duplicated measurement of components consumption is performed with calculation of their density. On base of measurements well yield is assessed for each component separately together with production rate evaluation.

EFFECT: facilitating high accuracy and quality of yield assessment with protection of device from rapid increase of gas phase pressure when gas bubble comes in from wells.

16 cl, 10 dwg

Description

The invention relates to the oil industry and can be used to measure the flow rate of a two-phase three-component oil-gas mixture from the wells, for each component separately, and to protect the metering device from a sharp increase in the pressure of the gas phase in the event of a gas "bubble" from the well. The device can be used both to measure the flow rate of one well, and a group of wells at the assembly point "bush".

A device for measuring the flow rate of wells (RU; patent for the invention No. 2199662, C2 dated 05/29/2001; ЕВВ 47/10) containing a gas separator with a nozzle for the selection of separation products (product sampler) and a float connected to the valve on the gas line communicated through the product sampler liquid and through the gate gas lines with a common line, including also a liquid meter, a spring-loaded valve with a stem, a valve seat, a washer made of magnetic material, mounted on the stem and located between the ring magnets installed in the magnet gadgets rigidly attached to the body, interacting with the washer when moving the rod, and fixing it in extreme positions, a throttle installed in the passage section of the valve seat and rigidly connected to the rod of the latter.

The method for measuring flow rate is that in a constant process of separation, the oil-gas mixture from the well is divided into two phases (separation products): gas and oil-liquid liquid; then, in a constantly repeating measurement cycle, the following operations are successively performed: the gas phase is discharged into a common line, and the liquid phase is accumulated until it reaches a predetermined level, as a result of which the gas phase discharge is closed and accumulated until a predetermined pressure drop of the gas phase in the gas separator and the medium in total lines, and, as a consequence of this, then the liquid phase is discharged by a portion of a predetermined value through the product sampler into the common line, its flow rate is measured and the gas phase discharge is opened.

The disadvantages of the known device and method are:

- measurement of the flow rate of only one two-component phase of the mixture - liquid, the flow rate of the gas phase is unknown;

- the design does not provide protection against a sharp increase in the pressure of the gas phase in the gas separator when a gas "bubble" comes from the wells, this leads to a sharp increase in the differential pressure of the gas phase in the gas separator and the medium in the common line, which negatively affects the accuracy of the meter .

A device for measuring the flow rate of wells (SU; auth. Certificate. No. 1530765, A1 dated 12/23/1989; ЕВВ 47/10) containing a gas separator with a nozzle for the selection of separation products (product sampler) and a float associated with a gas line damper in communication with a common line through the liquid sampler and through the damper with gas lines, which also includes liquid and gas meters, a pneumatic valve connected to the gas line with a stem on the liquid line, made with the possibility of installing it in two extreme fixed positions, etc. this device is equipped with an additional membrane valve installed on the gas line, parallel to the damper, with a stem, also configured to be installed in two extreme fixed positions, and a throttle in front of it upstream, the submembrane cavity of the additional membrane valve being connected to the gas line up to the throttle, and the supmembrane cavity connected to the gas line after it and the throttle.

The method of measuring the flow rate of wells and protecting the device from a sharp increase in the gas phase upon the arrival of a gas "bubble" from the well consists in the fact that in a constant process of separation the oil-gas mixture is divided into two phases (separation products): gas and oil-liquid liquid; and then, in a constantly repeating measurement cycle, the following operations are sequentially performed: the gas phase is dumped into a common line, its flow rate is measured, and the liquid phase is accumulated until it reaches a predetermined level, as a result of which the gas phase discharge is closed and accumulated until a specified pressure drop in the gas phase is created in the gas separator and the medium in a common line, and, as a consequence of this, then the liquid phase is discharged by a portion of a predetermined value through the product sampler into a common line, its flow rate is measured, and at the same time, according to the cause of the discharge of the liquid phase, the discharge of the gas phase is opened, in addition, with a sharp increase in the pressure of the gas phase, in the case of a gas bubble coming from the well, the additionally received portion of the gas phase is discharged into the common line through an additional membrane valve, regardless of the level of the liquid phase, until the restoration of a given differential pressure of the media.

The known device and method have several disadvantages:

- the unreliability of the device due to the presence of a membrane valve, which has substantially limited resources and mechanical strength, and impulse tubes connecting the membrane cavity of the valve with the gas and common lines. The tubes are constantly filled with condensate, which freezes at low ambient temperatures, as a result of which the valves cease to function.

- the unreliability of the locking devices of the valves, which include contacting pairs of parts interacting with each other with the application of significant contact stresses, which causes accelerated wear and failure of the contact surfaces and ultimately leads to a malfunction of the device as a whole;

- only the flow rates of two phases are measured: liquid, two-component mixture and gas, but this is clearly not enough for a qualitative assessment of well productivity. It is necessary to measure the flow rates of the components of the liquid two-component phase: a mixture of oil and water.

These device and method are the closest in technical essence and the achieved results of the claimed invention.

To measure the flow rate of the components of a liquid two-component phase, it is necessary to divide the liquid phase into components, select them individually, individually, and measure the flow rate of each.

A well-known pumping unit (SU; auth. Certificate No. 1211460, A dated 02.15.1986; F04D 13/10) comprising a pump installed in a production casing of a well equipped with a packer on a tubing string and co-located with the latter additional casing pipes, forming two annular cavities of the liquid phase sediment in the gravitational field (gravitational separator), the pump inlet and the device for selecting the liquid phase separation products (product separator) installed in it in the form of a magnetic switch action-crystal for alternately both messages with reception cavities and the pump cavity with the production string below the packer, connected with the membrane, a hole built into an additional pipe string.

The method of dividing the borehole products into components (separation products) and selecting them in turn consists in the fact that the formation is fed into the annulus of the separator by reservoir pressure, in which it is separated into components by the sludge method in the gravitational field and the sampler is taken out of the annular cavity one by one, sequentially, by components: first a component of high density, then low density; and serves the pump through the pump string, and the associated gas is removed by ventilation of the production string.

Known installation and method have the following disadvantages:

- the hydraulic diameters of the annular cavities are limited in size, this reduces the efficiency of the separation of products into components by the method of sludge in the gravitational field with a large flow rate of the well, due to the fact that a significant flow rate of the products in the cavities does not contribute to sludge; already settled components can mix;

- the presence of moving elements in the magnetic flow switch is the main reason for its low reliability in conditions of high paraffin content in the product. This is due to the high probability of locking the switch and its leak due to the fouling of moving elements with a layer of paraffin.

A well pump input device is known (SU; patent No. 1782294 A3, dated 15.12.1992; F04D 13/12), comprising a means for selecting liquid phase separation products (product collector) in the form of two supply pipes, the inputs of which are located at different levels and directed to opposite the sides are vertical, and the outputs are communicated with the pump inlet through a connecting device made in the form of a tube having lower and upper U-shaped sections, the last of which is connected to the pump inlet by the upper point.

The well complete with the device is the capacity of the sludge mixture of oil and water to separate them in a gravitational field with a device for selecting separation products placed in it, i.e. gravity separator with a product picker.

The method of operation of the gravitational separator with the product sampler is that the well products are fed to the separation site and divided into components (separation products): oil and water; in the well cavity - the gravity separator - by sludge and then through the product sampler they are pumped out one by one, and the selection of one component by the selection of the other is carried out by creating conditions that violate the hydrostatic equilibrium of the mass of the replaced component in the input device by hydrostatic pressure, due to the difference in component densities, displacement the interface between the components in the separator cavity by a predetermined value relative to the connecting device: above the oil from the device yayut up and replaced with water, more water is taken up until the interface is not displaced following the connecting device, then replacing the hydrostatic head of water down the device and replace it with oil and more oil is taken until the interface is not above the shift device. Selection changes are fast. The device, by analogy, acts as a relay, without intermediate stops, switched from one extreme fixed position to another only with the maximum displacement of the interface relative to the device up or down.

The device and method have disadvantages:

- the diameter of the well is limited in size, this reduces the efficiency of the process of dividing products into components by the sludge method in a gravitational field with a large flow rate, due to the significant flow rate of the products in the well cavity, which does not contribute to sludge; already settled components can mix;

- the actual dimensions of the connecting device along the length make it difficult to use it in ground installations. This is explained as follows: as is known from the technical literature, the density of oil reaches 93% of the density of water, while the viscosity of oil exceeds the viscosity of water by 40 ÷ 100 or more times. To ensure the efficient operation of the food sampler, it is necessary that the hydraulic resistances of the inlet pipes with the complementary parts of the connecting device to the point of connection with the pump inlet pipe are equal. But this is possible with equal diameters and a significant difference in the viscosity of water and oil in only one case, if the length of the pipe facing down into the water is many times the length of the pipe facing up into the oil. Otherwise, the dynamic pressure of the water flowing up the nozzle, facing down into the water, will exceed the hydrostatic pressure created by the insignificant difference in the densities of oil and water, and only water will enter the pump inlet. The device will not work properly. In addition, the hydrostatic head should be comparable in magnitude with the hydraulic resistance of the nozzles, which can be done with a slight difference in the density of oil and water only by significantly increasing the height of the hydrostatic columns of the liquid, i.e. the length of the nozzles. As can be seen from the description of the known invention, the length of the device product sampling reaches 70 meters, which is unrealistic for use in ground installations.

- the equality of the diameters of the device and the pump inlet leads to the fact that the dynamic pressure of the fluid flow initiated by the pump affects the hydrostatic pressure, which, in turn, negatively affects the process of changing the oil selection to water selection and vice versa.

The known device and method are closest in technical essence and the achieved results of the claimed invention.

An object of the invention is to increase the accuracy, quality and reliability of measuring the flow rate of an oil well, for each component of its products separately, by increasing the efficiency and quality of separation of the oil-gas mixture and oil sludge, duplicating measurements and effectively protecting the metering device from a sharp increase in gas phase pressure in the case of income from the well of the gas "bubble".

The technical problem of a method for measuring the flow rate of oil wells, including the continuous process of separating the oil-gas mixture into components (separation products), containing first the separation of the gas phase from the liquid dispersion of the mixture stream and the inertial effect on the gas stream, then the separation of the liquid phase into oil and water by the sludge method in gravitational field, and a repeating measurement cycle, including sequentially: discharge of the gas phase into a common line with simultaneous measurement of its flow rate, accumulation of the liquid phase to a given ur a ram and, as a result of this, blocking the discharge of the gas phase, accumulation of the gas phase up to a predetermined pressure difference between it and the medium in the common line and, as a result of this, discharge of the liquid phase by a portion of a given value into the common line while measuring its flow rate and opening the discharge of the gas phase , as well as maintaining the pressure of the gas phase within the specified limits by dumping it into a common line and dumping a portion of the gas phase, additionally received from the well with a gas "bubble", regardless of the level of accumulation of the liquid phase, is solved according to the image The fact is that the instantaneous volumetric and mass flow rates of the gas phase are measured and its density is calculated, the liquid phase is preliminarily separated during its accumulation, as a result of which individual drops of oil are associated into separate integrated clusters, then throttled and fed to gravity separation, where it is finally separated for oil and water, integrated into the layers, which are alternately selected, separately and sequentially measure their instantaneous volumetric and mass flow rates, and reset the total portion of the set value a common line, while their densities calculated for identification by the liquid density during production registered, and residues of the gas phase, separated out by throttling discharged after measuring its flow into a common line. In addition, the pressure of the gas phase is maintained within predetermined limits, in the event of an emergency receipt of its additional portion, by displacing the accumulated liquid phase into the emergency reservoir with subsequent return, and the additional portion of the gas phase is discharged into the compensating reservoir and into the common line. In addition, measurements of the costs of liquid phase separation products are duplicated during their alternate selection, by separately and sequentially measuring their instantaneous density, identifying the liquid by density and determining the relative content, based on the measurement of oil and water in the total portion, counting the number of dumped total portions oil and water of a given value in the accounting period of time, calculating the average values of them, oil and water, volumetric and mass flow rates, and finally compare the results of measuring the flow rate with both methods obami then analyzed the results of comparison and make a conclusion about the stability of the value of the allowable flow rate measurement error for corrective action.

The technical problem according to option I of the method for measuring the flow rate of oil wells, including the continuous process of separating the oil-gas mixture into components (separation products), first containing the separation of the gas phase from the liquid dispersion of the mixture stream and the inertial effect on the gas stream, then the separation of the liquid phase into oil and water by the method sludge in a gravitational field, and a repeating measurement cycle, including sequentially: discharge of the gas phase into a common line with simultaneous measurement of its flow rate, accumulation of the liquid phase before of this level and, as a result of this, overlapping the discharge of the gas phase, accumulation of the gas phase up to a predetermined pressure difference between it and the medium in the common line and, as a result, discharge of the liquid phase by a portion of a given value into the common line with simultaneous measurement of its flow rate and opening of the gas discharge phase, as well as maintaining the pressure of the gas phase within the specified limits by dumping it into a common line and dumping a portion of the gas phase, additionally received from the well with a gas "bubble", regardless of the level of accumulation of the liquid phase, it is agreed about the invention by measuring the instantaneous volumetric and mass flow rates of the gas phase and calculating its density, the liquid phase is pre-separated during its accumulation, as a result of which individual drops of oil are associated into separate integrated clusters, then throttled and fed to gravity separation, where they are finally separated its oil and water, integrated into the layers, which are alternately selected, separately and sequentially measure their instantaneous density, a total portion of a given value is dumped into the total They identify the liquid by density and determine the relative content based on the measurement of oil or water in the total portion, calculate the number of discharged portions of a given amount of oil and water in the reference time period and calculate the average values of them, oil and water, volume and mass flow rates, and the residues the gas phase released during throttling is discharged after measuring its flow rate into a common line.

In addition, the pressure of the gas phase is maintained within predetermined limits, in case of emergency receipt of its additional portion by displacing the accumulated liquid phase into the emergency capacity with subsequent return, and the additional portion of the gas phase is dumped into the compensating capacity and into the common line.

The technical task according to the second variant of the method for measuring the flow rate of oil wells, including the continuous process of separating the oil-gas mixture into components (separation products), containing first the separation of the gas phase from the liquid dispersion of the mixture stream and the inertial effect on the gas stream, then the separation of the liquid phase into oil and water by the method sludge in the gravitational field, and a repeating measurement cycle, including sequentially: discharge of the gas phase into a common line with simultaneous measurement of its flow rate, accumulation of the liquid phase to of this level and, as a result of this, overlapping the discharge of the gas phase, accumulation of the gas phase up to a predetermined pressure difference between it and the medium in the common line and, as a result of this, discharge of the liquid phase by a portion of a given value into the common line while measuring its flow rate and opening the gas discharge phase, as well as maintaining the pressure of the gas phase within the specified limits by dumping it into a common line and dumping a portion of the gas phase, additionally received from the well with a gas "bubble", regardless of the level of accumulation of the liquid phase, it is agreed but the invention by measuring the instantaneous volumetric and mass flow rates of the gas phase and calculating its density, the liquid phase is pre-separated during its accumulation, as a result of which individual drops of oil are associated into separate integrated clusters, then throttled and fed to gravity separation, where they are finally separated its oil and water, integrated into the layers, which are alternately selected, separately and sequentially measure their instantaneous density, identify the liquid by its density, discharge into separate line of oil and water in constant portions of a known volume value, previously determined experimentally, determining the beginning and end of discharge of a portion of identified fluid by changing the measured density, and calculate the flow rate of the well by the number of portions of oil and water in the accounting period of time, and the remaining gas phase that are released during throttling are discharged after measuring their flow rate into a common line.

In addition, the pressure of the gas phase is maintained within predetermined limits, in case of emergency receipt of its additional portion by displacing the accumulated liquid phase into the emergency capacity with subsequent return, and the additional portion of the gas phase is dumped into the compensating capacity and into the common line.

The technical task according to the III variant of the method for measuring the flow rate of oil wells, including the continuous process of separating the oil-gas mixture into components (separation products), containing first the separation of the gas phase from the liquid dispersion of the mixture flow and the inertial effect on the gas stream, then the separation of the liquid phase into oil and water by the method sludge in the gravitational field, and a repeating measurement cycle, including sequentially dumping the gas phase into a common line with simultaneous measurement of its flow rate, accumulation of the liquid phase to of this level and, as a result of this, overlapping the discharge of the gas phase, accumulation of the gas phase up to a predetermined pressure difference between it and the medium in the common line and, as a result, discharge of the liquid phase by a portion of a given value into the common line with simultaneous measurement of its flow rate and opening of the gas discharge phase, as well as maintaining the pressure of the gas phase within the specified limits by dumping it into a common line and dumping a portion of the gas phase, additionally received from the well with a gas "bubble", regardless of the level of accumulation of the liquid phase, it is agreed but the invention by measuring the instantaneous volumetric and mass flow rates of the gas phase and calculating its density, the liquid phase is preliminarily separated during its accumulation, as a result of which individual drops of oil are associated into separate integrated clusters, then throttled and fed to gravity separation, where they are finally separated its oil and water, integrated into the layers, which are alternately selected, separately and sequentially measure their instantaneous density, identify the density of the liquid, determine the beginning At the beginning and the end of the process of selecting the identified fluid by changing the measured density, measure the length of time during which the selection process is carried out, alternately identified fluids are dumped into a common line, then the current flow rate of the well is calculated separately for oil and water by dividing the value of the volume of the calibrated capacity V _o - part of the gravitational separation cavity inherent in a particular device for the length of time the selection process is carried out: oil - to calculate the flow rate of water, water - to calculate oil flow rate; and the remaining gas phase released during throttling is discharged after measuring their flow rate into a common line.

In addition, the pressure of the gas phase is maintained within predetermined limits, in the event of an emergency receipt of its additional portion, by displacing the accumulated liquid phase into the emergency reservoir with subsequent return, and the additional portion of the gas phase is discharged into the compensating reservoir and into the common line.

The technical task of the device for measuring the flow rate of oil wells, containing a gas separator with a product separator and a float associated with a valve on the gas line, communicating the gas separator with a common line, liquid and gas flow meters, valves mounted on a liquid, also communicating gas separator with a common line, and a gas lines, with the possibility of fixing them in two extreme positions: “Open” or “Closed”, is solved according to the invention in that the device includes a unit for calculating, accounting for production, registration and analysis showing of flow meters mounted in pairs that contain volumetric and mass flowmeters, in the indicated order of listing, installed sequentially along the flow, on gas and liquid lines in front of valves made in the same way and with the possibility of additional opening of the passage above the extreme fixed position “Open”, gravity separator made in the form of an inclined cylindrical vessel with a throttle inlet, in communication with a siphon product sampler, consisting of upper and opposite siphons, having a common short elbow, the long elbow of the upper siphon communicating with the bottom of the vessel, and the long elbow of the opposite siphon connected to the top of the vessel, of two diaphragms mounted at the inlets of the long elbows of the siphons and turned with sharp edges to the siphons, a plunger and a gas meter installed sequentially on the discharge a line that communicates the upper connection point of the long elbow of the opposite siphon with the top of the inclined cylindrical vessel with a common line, in addition, the bottom of the vessel is connected through a food sampler to a gas separator, NJ upper siphon point communicates with one common liquid line, wherein the diameters of passage section siphons of opposed upper and associated with the liquid line diameter portion before the metering dependence:

where D _on is the diameter of the siphons, the upper and the opposite,

d _JL - the diameter of the liquid line.

In addition, the device includes an emergency tank in communication with a gas separator with a product sampler containing a pit and a sampling pipe, and a valve installed on the gas line downstream of the valve is equipped with a bypass containing a compensating tank and valve in series.

In this case, the upper and opposite siphons are formed by two vertical supply pipes, which are long siphon elbows, the inlets of which are connected to the bottom and top of the inclined cylindrical vessel, respectively, and a connecting link made in the form of a vertical trunk having upper and lower double knees at the ends, through which the exits vertical inlet pipes connected with a vertical barrel, which is a common short elbow of siphons, rotated relative to the axis of the barrel to each other up to rikosnoveniya long siphon knees.

The device also includes two differential pressure gauges mounted on a common short siphon elbow, spaced in height by a predetermined distance H ₀ , associated with a unit for calculating, recording production, recording and analyzing flowmeter readings.

The technical task of a variant of a device for measuring the flow rate of oil wells, comprising a gas separator with a product sampler and a float associated with a gas line damper communicating with the gas separator with a common line, liquid and gas flow meters, valves mounted on a liquid, also communicating gas separator with a common line, and gas lines, with the possibility of fixing them in two extreme positions: “Open” or “Closed”, is solved according to the invention in that the device includes a unit for calculating, accounting for production, registration and anal from the readings of flowmeters mounted in a pair that contains volumetric and mass flowmeters, in the indicated order of listing installed sequentially along the flow on the gas line in front of the valve, made in the same way and with the possibility of additional opening of the passage above the extreme fixed position “Open”, gravity separator made in the form of an inclined cylindrical vessel with a throttle inlet in communication with a siphon product sampler, consisting of upper and opposite siphons, having a common a thin knee, the long elbow of the upper siphon communicating with the bottom of the vessel, and the long elbow of the opposite siphon connected to the top of the vessel, of two diaphragms mounted on the inlets of the long elbows of the siphons and turned with sharp edges to the siphons, a plunger and a gas meter installed sequentially on the discharge line , communicating the upper point of the long elbow of the opposite siphon with the top of the inclined cylindrical vessel with a common line, in addition, the bottom of the vessel is connected through the food sampler to the gas separator, the upper point upper siphon communicates with one common liquid line, wherein the diameters of passage section siphons of opposed upper and associated with the liquid line diameter portion upstream of the valve mounted on it arranged to pass the additional opening beyond the extreme fixed position "open", the relationship:

where D _on is the diameter of the siphons, the upper and the opposite,

d _JL - the diameter of the liquid line;

moreover, on the common short knee of siphons, two differential pressure gauges are installed, spaced in height by a predetermined distance H ₀ , associated with a unit for calculating, accounting for recording production and analyzing flow meter readings. In addition, the device includes an emergency tank in communication with a gas separator with a product sampler containing a pit and a sampling pipe, and a shutter installed on the gas line downstream of the valve is equipped with a bypass containing a compensating tank and valve in series.

In this case, the upper and opposite siphons are formed by two vertical supply pipes, which are long siphon elbows, the inlets of which are connected to the bottom and top of the inclined cylindrical vessel, respectively, and a connecting link made in the form of a vertical trunk having upper and lower double knees at the ends, through which the outlets vertical inlet pipes connected with a vertical barrel, which is a common short elbow of siphons, rotated relative to the axis of the barrel to each other up to ikosnoveniya long siphon knees.

The invention is illustrated by drawings:

figure 1 - diagram of the device;

figure 2 is a section aa of the inertial chipper;

figure 3 is a diagram of a gravity separator with a siphon product sampler at the time of changing the selection of water for oil;

4 is a diagram of a separator with a siphon product sampler at the time of changing the selection of oil to take water;

figure 5 - diagram of the valve with the possibility of additional opening of the passage above the extreme fixed position "Open", callout B from figure 1;

6 is a diagram of the valve, callout In figure 1;

Fig.7 is a diagram of the installation of the diaphragm, leader G of Fig.1;

Fig is a fragment of a diagram of a variant of the device (distinguishing feature);

Fig.9 is a diagram of a gravity separator with a siphon sampler at the time of water withdrawal;

figure 10 is a view of D on the siphon sampler bottom.

A device for measuring the flow rate of oil wells contains a gas separator 1 with a product sampler 2, consisting of a sampling pipe 3, a pit 4, and a float 5 connected to a shutter 6 on the gas line 7, communicating the gas separator 1 with a common line 8. At the outlet of the gas separator 1 to the gas line 7 has an inertial chipper 9 made of corrugated sheets 10 with pockets 11 for trapping liquid and a bottom 12 for draining the liquid trapped from the gas stream, located at the inlet 13 to the gas line 7. The gas separator 1 is equipped with a protective partition 14 of the grid separating the inertial impingement plate 9 from the rest of the gas separator 1 for a primary slurry catching drops and foam. The gas separator 1 is equipped with gratings 15 for dispersion of oil and gas flow. A design similar to a gas separator 1 and an inertial chipper 9 is known in the art. There is a sealed emergency tank 16 in communication with the gas separator 1. The liquid line 17 through the product separator 2 communicates the gas separator 1 with a common line 8. On the gas 7 and liquid 17 lines are mounted a pair of gas and liquid flow meters composed of volumetric flow meters 18, 19 of turbine type and mass flowmeters 20, 21 of the type of constricting devices, such as diaphragms. Flowmeters are installed sequentially downstream, in the indicated order of listing, in front of valve 22 on liquid 17 and valve 23 on gas 7 lines. The latter is installed in front of the shutter 6. The shutter 6 is equipped with a bypass 24, which includes a sealed compensating capacity 25 and a valve 26. Valves 22, 23, 26 with a stem 27, a seat 28, a shut-off element 29, a throttle 30 and a spring 31 are configured to install them in two extreme fixed positions “Open” or “Closed” by means of fixing elements in the form of permanent ring magnets 32, strung on the rod 27, mounted in the magnetic circuits 33, mounted in the housing 34 of the valves 22, 23, 26. The magnets 32 interact in extreme positions when moving the rod 27 with a washer 35 made of magnetic material placed between the magnets 32 and mounted on the rod 27 to which the locking element 29 is attached with a throttle 30 located in the passage channel of the seat 20. The magnets 32 fix the washer 35 in the extreme positions Open ”or“ Closed ”.

Valves 22 and 23 are endowed with the possibility of additional opening of the passage above the extreme fixed position “Open”. This possibility is achieved by the fact that the washer 35 is mounted on the sleeve 36, pressed against the stop at the end of the rod 27 by an additional spring 37 and resting on the locking element 29, seated with the possibility of movement on the rod 27. In the liquid line 17 between the gas separator 1 and the flow meters 19 and 21 a gravity separator 38 is installed, made in the form of an inclined cylindrical vessel 39 with a throttle 40 at the inlet and with a siphon product sampler 41, consisting of siphons of the upper 42 and opposite 43, having a common short elbow 44 and formed by vertical leading pipes 45, 46, which are long elbows 47, 48 of siphons 42, 43, the inputs of which are in communication with the bottom and top of the vessel 39, respectively, and a connecting link 49, made in the form of a vertical barrel 50, having at the ends of the upper 51 and lower 52 double knees, by means of which the outputs of the vertical supply pipes 45, 46 are connected with the vertical shaft 50, which is the common short elbow 44 of the siphons 42, 43. The double elbows 51, 52 are rotated relative to the axis of the barrel 50 until the long elbows 47, 48 come in contact. This is done with target reducing the space taken up siphons 42, 43. In hydraulics, in the classic sense called siphon conduit, wherein the fluid flow caused by hydrostatic pressure directed from the pipeline to the input of inflection long knee. The hydrostatic pressure in our case is caused by the difference in the densities of oil and water. In case of lowering the oil-water interface in the vessel 39 before the entry of the long elbow 47 of the upper siphon 42, in which the water is located, the hydrostatic pressure on this water is directed downward. If the interface rises above the inlet of the long knee 48 of the opposed siphon 43, in which the oil is located, the hydrostatic pressure on this oil is directed upward from the bend of the opposed siphon 43 to the inlet of the long knee 48. Corresponding to the direction of the hydrostatic pressure, the opposed siphon 43 siphon.

On the common short knee 44 siphons 42, 43 are installed spaced apart by a predetermined distance H ₀ , sensors 53 of the differential pressure gauge 54. In front of the entrances of the long knees 47, 48 are installed diaphragms 55, 56, which point with sharp edges to the siphons 42, 43. The box siphon 43 is communicated with a common line 8, a discharge line 57, which includes a plunger 58 in series with the flow (a float needle valve) and a gas meter 59. The long elbow 48 of the opposed siphon 43 is connected to the top of the vessel 39 by a connection 60, to the upper point of which a discharge line 57 is connected. The bottom of the vessel 39 is communicated through a throttle 40 and a food sampler 2 with a gas separator 1, the upper point of the upper siphon 42 is connected to the volumetric flow meter 19 by a section 61 of the liquid line 17, the diameter of which is related to the diameters of the passage section of the siphons 42 and 43 by:

where D _on - siphon diameter 42, 43,

d _JL - the diameter of the plot 61 lines.

The device includes a unit 62 for calculating, recording production, recording and analyzing the readings of flowmeters 18, 19, 20, 21 of liquid and gas, a gas meter 59 and a differential pressure gauge 54 with which it is connected. The layers of oil and water in the vessel 39 are separated by the interface 63, in the siphon top 42 or opposed 43 separated by the interface 64. On the liquid line 17 in front of the entrance to the gravity separator 38 there is a shut-off valve 65. Behind the valve 65, downstream, into the liquid line 17 a nozzle 66 with a shut-off valve 67 has been inserted. Cranes 65, 67 with a nozzle 66 are designed to perform work on measuring the volume of portions of liquid taken by the food sampler 41. Oil in the vessels of the gravity separator 38 is indicated by shading, and water by shading.

The device variant, unlike the main version, contains only one pair of flow meters 18, 20 on the gas line 7. There are no flow meters on the liquid line 17 and only the valve 22 is installed, communicated by section 61 with the upper point of the upper siphon 42. The function of the flow meter on the liquid line from the gas separator 39 to the common line 8, a differential pressure gauge 54 is implemented, the sensors 53 of which are mounted on a common short elbow 44 of the siphons 42, 43, and are spaced apart in height by the size H ₀ .

The method for measuring the flow rate of oil wells is as follows: the oil-gas mixture from the oil well is fed to the gas separator 1, where it is divided into two phases in a continuous process - liquid, two-component, and gas by dispersing (crushing) the mixture flow on the gratings 15. The gas phase flow is passed before entering 13 into the gas line 7 through the inertial chipper 9 and the grid 14, where it is freed from the remnants of the liquid phase in the form of a droplet suspension and foam, which increases the reliability of measuring gas flow. At the inlet to the vessel 39, a throttle 40 is installed, which “supports” the gas phase in the gas separator 1. This restrictor 40 limits the decrease in pressure of the gas phase in the section from the wells to the gas separator 1. This reduces the likelihood of a foam formation process. In a constantly repeating measurement cycle, the following operations are performed: the gas phase through a pair of 18, 20 gas flow meters, through the open valve 23 and the open shutter 6 through the gas line 7 are discharged into the common line 8 and thereby maintain the pressure of the gas phase in the gas separator 1 within specified limits, and the liquid phase is accumulated in the lower part of the gas separator 1 and in the emergency container 16 connected with it, since the valve 22 is closed and locked in this extreme position “Closed”, the spring force 31 and the magnetic force holding the closed magnetic circuit and formed by the lower permanent annular magnet 32, the magnetic circuit 33 and the washer 35, which in total exceed the force created by the pressure drop across the valve 22 acting on the shut-off element 29, which tightly closes the seat 28. The liquid phase filling the lower part of the emergency tank 16 compresses the gas pillow at its top. The liquid phase is previously separated into components (separation products) - oil and water; in the lower part of the gas separator 1 and in the emergency tank 16 by the method of sedimentation in a gravitational field in the process of accumulation of the liquid phase. Sludge is constantly disturbed by the process of mixing new portions of the liquid phase coming from above into the settling part of it. Therefore, the result of preliminary separation will not be the integration of oil into a single layer above water, but the association of individual drops of oil into separate integrated clusters. The liquid phase is discharged in common portions of a predetermined amount through a food sampler 2 through a liquid line 17 and through a choke 40 for final separation into oil and water into a gravity separator 38, which are associated into integrated layers, and from there through a siphon product sampler 41 to a common line 8 through a pair 19, 21 flowmeters and valve 22 when it is opened. First, water is discharged into the liquid line 17 from the gas separator 1, and then the interface between the water and oil accumulations is lowered, coincides with the end of the sampling pipe 3, and as a result, oil is taken from its separate integrated accumulations. In this case, it is possible to mix water from its residues below the interface. To reduce the amount of water being mixed, the sampling pipe 3 is placed in a pit 4 of limited size, which also serves as a dirt collector. After that, the water separated from the oil comes from above and pushes the oil from the end of the extraction pipe 3. Next, the water is discharged until the oil reaches the end. The discharge of oil begins until water from above breaks down through a layer of oil. The length of time necessary for the passage of water through the oil layer ensures the supply of oil to the gravity separator 38 by separate integrated clusters, which accelerates and significantly increases the efficiency of the separation of oil from water in it into a single integrated layer. As the accumulation of the liquid phase in the gas separator 1, the float 5 rises and closes the shutter 6. The differential pressure of the gas phase on the valve 23 falls below a predetermined minimum level, and the valve 23 closes. This occurs as follows: the force from the differential pressure acting on the throttle 30, the locking element 23, together with the holding magnetic force of the closed magnetic circuit formed by the upper permanent ring magnet 32, the magnetic circuit 33, the washer 35 in total exceed the spring force of the spring 31. This fixes valve 23 in the extreme position "Open". The shut-off element 29 opens the seat 28 by an amount that ensures the maximum throughput of the valve 23. When the pressure drop falls below a predetermined level, the force imbalance is violated and the spring force 31, exceeding the magnetic holding force and the force of the reduced pressure drop on the shut-off element 29, tears off the washer 35 from the magnetic circuit, the holding magnetic force immediately decreases in magnitude practically to zero, and the locking element 29 without intermediate stops sits on the saddle 28 and is fixed in the extreme position ryto "valve 22 similarly as described above in a similar case. Valve 23 is closed. The discharge of the gas phase into the common line 8 is blocked. The pressure of the gas phase in the gas separator 1 increases, and the pressure drop across the valve 22 also increases and when it reaches a predetermined maximum level, the force from the pressure drop will exceed the sum of the spring force 31 and the magnetic holding force and the valve 22 will open and lock in the “Open” position , as shown above in a similar position on valve 23. The locking of valves 22, 23 and 26 in the extreme positions “Open” or “Closed” is ensured by the imbalance of forces acting on the locking elements 29 of the valves 22, 23, 26. In the extreme position “Open” valves 22, 23, 26 are fixed by an imbalance of forces acting on the locking elements 29: the sum of the force of the differential pressure on the throttle 30 and the locking element 29 and the holding magnetic force is greater than the spring force 31. In the extreme position “Closed” valves 22, 23, 26 are fixed by an imbalance of forces acting on the locking elements 29: the sum of the elastic force of the spring 31 and the retaining magnetic force is greater than the force of the pressure drop acting on the locking element 29 sitting on the saddle 28. The imbalance of forces occurs when the differential and pressure: opening from the extreme position “Closed” occurs when the pressure drop exceeds the specified maximum level; closing from the extreme position “Open” occurs when the pressure drop decreases below a predetermined minimum level. The retaining magnetic force acts only at a minimum distance between the permanent ring magnet 32 and the washer 35. With the slightest separation of the washer 35 from the magnets 32, the holding magnetic force sharply decreases in magnitude to almost zero. The transition of the locking organs 29 from one extreme position to another occurs quickly without intermediate positions.

After the valve 22 is opened by a pressure drop, the liquid phase from the gas separator 1 is fed through a product line 2 to the gravity separator 38, to the bottom of the inclined vessel 39 through a liquid line 17. Oil is flooded in separate integrated clusters in water to the inclined side wall and further along it to the interface 63 components. The inclined position of the vessel 39 contributes to the collection of oil accumulations in one place, near the wall, and then at the interface 63, where they are associated with an integrated layer of already settled oil. In vessel 39, water and oil settle in a gravitational field. The residual gas, which did not have time to stand out in the gas separator 1, is released after the liquid phase pressure drops in the throttle 40 and rises with separate bubbles to the inclined side wall of the vessel 39, and then along it to the collection point at the upper point of connection 60 of the long elbow 48 of the opposed siphon 43 with the top vessel 39, from where it is discharged by a plunger 58 through a gas meter 59 through a gas meter 59 to a common line 8. A gas meter 59 measures the residual gas flow.

Then, the separated and settled water and oil collected in the vessel 39 in two layers separated by the interface 63 are alternately taken by a siphon product collector 41 and sequentially in a common portion through a pair of counters 19 and 21 and the valve 22 on the liquid line 17 is dumped into a common line 8. The volume of the gravitational separator 38, as a rule, is much smaller than the volume of the gas separator 1, since the gas separator 1 can be installed and work in the open air and this is unlimited in size, in contrast to the gravitational separator 38, which output with concomitant flowmeter 18, 19, 20, 21 and valves 22, 23, 26 must be protected from exposure to negative air temperature, however is set to teplozaschischennyh heated block boxes, which severely limits its size. As a result of this, the volume of the total portion of the liquid phase discharged into the common line 8, 24 exceeds the volume of the gravity separator 38 and the portion is called “common” because it will always contain oil and water, which are separately and alternately supplied for flow measurement and discharge to the common line 8 Even in the opposite case, for example in areas with a favorable climate, it is impossible to avoid moments when the total portion contains oil and water, because it is almost impossible to synchronize the change of oil selection to water selection and vice versa with the beginning and Tzom reset total dose in the general line 8.

Water and oil are selected as follows: water is taken from the bottom of the vessel 39 through the long elbow 47 of the upper siphon 42, oil is collected at the top of the vessel 39 and in the long elbow 48 of the opposed siphon 43, which came together with water from the gas separator 1. The interface of 63 layers of oil and water drops down both in the vessel 39 and the interface 64 in the long knee 48, since they are interconnected vessels (see figures 1, 2, 3, 4, 9). Moreover, when lowering, the interface 64 lags behind the interface 63 by the height of the column of liquids with different densities, oil and water creating a hydrostatic pressure comparable to the hydrostatic resistance created by the diaphragms 55, 56, the fluid flow in siphons 42, 43. The interface 64 in the long elbow 48 will reach the junction with the common short elbow 44 of the siphons 42, 43, its further lowering slows down until the interface 63 in the vessel 39 (see Fig. 3) drops by the value of H ₁ , that is, reached t of the entrance of the long elbow 47 of the upper siphon 42. The siphon 40 begins to act and draws the water contained in it, and pushes it to the bottom of the vessel 39, drawing oil in its place from the top of the vessel 39 under the influence of hydrostatic pressure:

where H ₁ - the height of the nonequilibrium hydrostatic columns of liquids, m,

g = 9.81 m / s ² - acceleration of gravity,

ρ _in and ρ _n - the density of water and oil,

ΔP ₁ is the hydraulic resistance of the diaphragms 55, 56, the upper 42 and the opposite siphon 43 to the flow of water from the upper siphon 42 to the bottom of the vessel 39 and the oil flow from the top of the vessel 39 to the opposite siphon 43.

The selection of water stops and begins the selection of oil (see figure 1). Oil is taken from the top of the vessel 39 through the long elbow 48 of the opposite siphon 43. Its place in the vessel 39 is occupied by the water that came with the oil from the gas separator 1. The surface of the section 63 rises upward in the vessel 39, and the interface 64 in the long elbow 47 of the upper siphon 42 until the interface 63 in vessel 39 rises to a height of H ₂ (see FIG. 4). The box siphon 43 draws oil from the common short knee 44 and pushes oil from the long knee 48 to the top of the vessel 39, in its place draws water from the bottom of the vessel 39 (see Fig. 3) under the influence of hydrostatic pressure:

where H ₂ - the height of the nonequilibrium hydrostatic columns of liquids, m,

ΔP ₂ is the hydraulic resistance of the diaphragms 55, 56 of the upper 42, 43 to the flow of oil from the opposite siphon 43 to the top of the vessel 39 and to the flow of water from the bottom of the vessel 39 to the upper siphon 42.

The selection of oil stops and begins the selection of water (see figure 3). The change in the mass of oil to water and vice versa occurs quickly, without intermediate stops, from one extreme fixed position to another and vice versa, only when the interface 63 reaches the upper and lower extreme positions. The height of the gravity separator 38 with siphon product sampling device 41 in surface installations: points for measuring the flow rate of wells; especially mobile, located in heated block boxes; limited, which contradicts the technical task of the invention: improving the accuracy of measuring the flow rate of wells by increasing the efficiency and quality of separation and sludge of product components. To resolve this contradiction, it is necessary, within the limits of size, to increase the maximum mass of the oil layer in vessel 39, if possible, that is, to maximize the oil sludge time, which increases the efficiency of the process and the quality of gas and water separation from oil and, ultimately, increases the measurement accuracy the magnitude of its density, in this case as close to true as possible. To do this, it is necessary to make the vessel 39 the maximum in diameter and height, and the siphon food sampler 41 - in height the maximum possible within the limit and the condition:

where H ₃ - the height of the long knee of the upper siphon 42;

H ₄ - the maximum thickness of the oil layer;

H ₅ - the height of the long knee of the opposite siphon 43;

H ₆ - the height between the inflection points or the height of the common short knee of siphons 42, 43;

L - height limit.

It is also necessary to significantly reduce the hydraulic resistance coefficient of siphons 42, 43 in comparison with the local hydraulic resistance coefficients of the diaphragms 55, 56 to ensure the placement of the siphon product sampler 41 within the limit L, since in this case it becomes possible to select the necessary value of hydraulic resistance to the fluid flow under the influence of hydrostatic pressure . The solution to the problem is reduced by the influence of the dynamic pressure of the fluid flow in the siphons 42, 43, initiated by the discharge of the liquid phase into the common line 8, and at the outlet of the liquid line 17 from the upper siphon 42 on the hydrostatic equilibrium of the liquid in the siphons 42, 43. For this, the diameters of the passage sections the siphons 42, 43 are 1.5 to 2.5 times larger than the diameter of the portion 61 of the liquid line 17 connected to the upper siphon 42. From the course of the theory of hydraulics it is known by the example of considering the case of fluid outflow from the reservoir through an opening, central disposed, the impact on the size of the tank for fluid flow through the opening (see. "Mechanical Engineer Handbook", Volume 2, str.637-638, Table. №23, I.S.Acherkan, Mashgiz, Moscow, 1960 YG). But the response of the fluid flow through the hole to its hydrostatic state in the reservoir is also well known. When the ratio of the area of the tank F to the area of the hole f:

the influence of the size of the tank on the nature of the fluid flow through the hole, for example, the effect on the fluid flow (this is reflected in the value of the flow coefficient - µ), decreases compared to the ratio of areas:

X times. By analogy with this phenomenon taking the diameter D _of passage sections, the top 42 and 43 of opposed siphons in n times the diameter d _YF liquid line portion 61:

.Where

.

Based on this, when

according to the data of table 23 of the "Handbook", we conclude that the response of the fluid flow at the inlet to the portion 61 of the fluid line 17 on the hydrostatic state of the fluid in the siphons 42, 43 will decrease

The dynamic head of the fluid flow initiated by the discharge in siphons 42, 43 will decrease in

compared with the case if

the hydraulic resistance of the siphons 42, 43 will decrease by approximately the same amount. From the point of view of minimizing the influence of the liquid flow at the inlet to the section 61 of the liquid line 17 on the hydrostatic equilibrium of the liquid in the siphons 42, 43, it is desirable to increase the value of n over 2.5, but, on the other hand, an increase in the value of n implies a significant increase in the diameters of the siphons 42, 43 and the dimensions of the food _sampler 41. The diameter d of the section 61 of the liquid line 17 is already 1.5–2 times larger than the caliber of the liquid meters in order to increase them measurement accuracy. Taking into account actually used in practice measurements of flow rates of meter calibers from 15 to 80 mm and taking into account the need to place a gravity separator 38 with a food sampler 41 in a limited space of the block box for protection against climatic influences, we will take, for design reasons, a value of n within 1.5 ÷ 2 ,5. Small values of n should be used for calibers of 80 mm or less; large values of n should be used for calibers of 15 mm or more.

In view of the foregoing, the nature of the fluid flow in siphons 42, 43 will be determined almost exclusively by hydrostatic imbalance, determined by the difference in the densities of oil and water and the value of H ₁ or H ₂ , but not by the fluid flow at the inlet to section 61 of the fluid line 17 and the fluid flow in siphons 42 , 43 caused by selection. The change in oil selection for water withdrawal and vice versa is carried out depending on the position of the interface 63 in the vessel 39 relative to the siphons 42, 43. The thickness of the oil layer is determined by the height of the siphons 42, 43 and the values of H ₁ and H ₂ , which can be adjusted by changing ΔP ₁ and ΔP ₂ , choosing the corresponding diaphragms 55, 56. The diaphragms 55 and 56 are set with sharp edges to the siphons 42, 43, in this case, the hydraulic resistance coefficient of the diaphragm 55 to the water flow from the upper siphon 42 to the bottom of the vessel 39 or the diaphragm 56 to the oil flow from the opposed siphon 43 top sos yes 39 while changing selection largest 1.5 ÷ 2.5 times the aperture 55 the flow resistance coefficient of water in the top 42 of the siphon the bottom of the vessel 39 or aperture 56 in the flow of oil Opposed siphon 43 from the top of the vessel 39, with the selection of the liquid. This circumstance contributes to the efficient operation of the siphon product sampler 41.

The quantities taken by the product sampler 41 and discharged into a common line of 8 portions of oil and water are stable and unchanged, since the change in oil selection to take water and back only occurs when the surface 63 of the separation of oil and water layers in the vessel 39 is lower than the opposite siphon 43 by the value of the liquid column H ₁ and up above the upper siphon 42 by the value of the liquid column H ₂ . The values of H ₁ and H _{2 are} constant and unchanged, since only when the interface 63 is shifted by these values relative to the upper siphon 42 or opposed siphon 43, respectively, they are included in the work under the action of only the hydrostatic pressure created by the liquid columns H ₁ and H ₂ due to the difference in density of oil and water. The height between the inflection points H _{5 of the} siphons 42 and 43 is also a constant value. Thus, the volume V ₀ accumulated in the vessel 39 of oil or water, before changing the selection from water to oil or vice versa and the beginning of the discharge of liquid into a common line 8, with a layer height:

constant. During the selection of oil or water, the volume of the liquid phase enters the gravity separator 38 during the selection and discharge time:

where V _in , V _n = m · V _in are the volumes of water and oil received in the liquid phase,

- коэффициент относительного содержания нефти в жидкой фазе - величина постоянная при стабильном функционировании скважины, в том числе стабильном составе жидкой фазы.

- coefficient of relative oil content in the liquid phase - a constant value with stable well operation, including a stable composition of the liquid phase.

The selection of oil is carried out from the top of the vessel 39, the volume of the selected and dumped in a common line 8 of oil:

the place of the oil selected and discharged into the common line 8 is occupied by water, the interface 63 rises up to the height H ₄ , the selection and discharge of oil ceases, therefore, the volume V _in is equal to V _o . At the same time, oil in volume was supplied with water

which is combined with the oil taken and discharged into the common line 8. As a result, taking into account the foregoing, the volume of the portion of oil taken by the food sampler 41 will be equal to

и вытесняет воду из объема V_o; поверхность раздела 63 опускается на высоту Н₄, отбор и сброс воды прекращается, происходит смена отбора воды на отбор нефти. Объем отобранной и сброшенной в общую линию 8 воды будет:constant and unchanged with stable well operation. During the selection and discharge of water, water flows directly into the upper siphon 42, bypassing the vessel 39, the oil supplied with the water is collected in the vessel 39 in volume

and displaces water from the volume V _o ; section 63 surface drops to a height of H ₄ , water withdrawal and discharge cease, water withdrawal changes to oil withdrawal. The volume of water withdrawn and discharged into a common line 8 will be:

и воды в объеме

при стабильном функционировании, особенно в части состава жидкой фазы, нефтяной скважины, постоянны и неизменны. Объемы порций определяются опытным путем, замером их, например, мерной тарой, при настройке и запуске в эксплуатацию устройства. Объем V_o накопленной нефти во время отбора воды или объем V_o воды, занявшей место отобранной и сброшенной в общую линию накопленной нефти, определяется опытным путем следующим образом: сразу же по окончании отбора воды, определяемого по резкому изменению статического давления столба Н₀ жидкости в общем коротком колене 44 сифонов 42, 43 с помощью дифманометра 54, перекрывают запорный вентиль 65 и открывают вентиль 67. По патрубку 66, подсоединенному по временной схеме сетью, включающей объемный счетчик воды, к источнику воды с регулируемым напором, соответствующим интервалу значений перепада давлений, на который настроен клапан 22, подают в сосуд 39, вытесняя накопившуюся нефть, воду до тех пор, пока не произойдет смена отбора нефти, накопленной во время отбора воды при подаче жидкой фазы в сосуд 39, на отбор воды. Определяем этот момент по резкому изменению статического давления столба Н₀ жидкости.constant and unchanging. Thus, selected in the sampler 41 and discharged into a common line 8 portions of oil in volume

and water in volume

with stable operation, especially in terms of the composition of the liquid phase, the oil well, are constant and unchanged. Serving volumes are determined empirically, by measuring them, for example, with a measuring container, when setting up and commissioning the device. The volume V _{o of} accumulated oil during water withdrawal or the volume V _{o of} water that took the place of the accumulated oil sampled and discharged into the common line is determined empirically as follows: immediately after the completion of water extraction, determined by a sharp change in the static pressure of the liquid column N ₀ in a common short knee 44 siphons 42, 43 using a differential pressure gauge 54, close the shut-off valve 65 and open the valve 67. Through the pipe 66, connected by a temporary circuit with a network including a volumetric water meter, to a regulated pressure source of water, corresponding to the range of pressure differential values for which the valve 22 is configured, is supplied to the vessel 39, displacing the accumulated oil, water until the selection of oil accumulated during the selection of water during the supply of the liquid phase to the vessel 39 is replaced by a selection of water. We determine this moment by a sharp change in the static pressure of the column H _{0 of} liquid.

процесса отбора нефти с начала и до конца и расход воды Q_в Вычисляем объем воды, занявшей место нефти

Подключаем патрубок 66 к источнику нефти, открываем вентиль 67 и подаем нефть в сосуд 39, вытесняя воду, до тех пор, пока отбор воды не сменится отбором нефти.We shut off valve 67. We measure the time of implementation

the process of oil selection from beginning to end and water consumption Q _in Calculate the volume of water that took the place of oil

We connect the pipe 66 to the oil source, open the valve 67 and feed the oil into the vessel 39, displacing the water until the water withdrawal is replaced by the oil withdrawal.

- процесса отбора воды и расход Q_н - нефти и определяем объем нефти, вытеснившей воду из сосуда 39 и занявшей ее место

При тщательном исполнении процесса определения объема V_o должно быть:

Открываем вентиль 55 и перекрываем вентиль 67. Объем V_o определяется в отличие от объема порций нефти и воды, отбираемых и сбрасываемых в общую линию 8, вне зависимости от m - относительного содержания нефти в жидкой фазе. Объем V_о является объемом тарированной емкости 68, определяемым объемом части сосуда 39, ограниченного высотой:Completely repeat the process of measuring the time of implementation

- the process of water withdrawal and flow rate Q _n - oil and determine the amount of oil that displaced water from the vessel 39 and took its place

With careful execution of the process of determining the volume V _o should be:

We open the valve 55 and close the valve 67. The volume V _o is determined in contrast to the volume of portions of oil and water taken and discharged into a common line 8, regardless of m - the relative oil content in the liquid phase. The volume V _about is the volume of the calibrated capacity 68, determined by the volume of the part of the vessel 39, limited by the height:

where H ₆ is the design size of the product sampler 41,

H ₁ , N ₂ - the heights of the nonequilibrium columns of the liquid, creating a hydrostatic pressure, due to the difference in the densities of oil and water, limited by the hydraulic resistance of the diaphragms 55, 56.

With the shutter 6 closed and the valve 23 closed, the gas phase accumulates in the gas separator 1, until the pressure drop across the valve 22 reaches a predetermined maximum level at which the valve 22 opens (start of the measurement cycle):

where ΔP _22max - the maximum pressure drop of the opening of the valve 10,

k is the coefficient of influence of the throttle 40 on the pressure of the medium,

P _22max - the maximum pressure of the medium in the gas separator 1 when opening the valve 22,

P ₀ is the pressure of the medium in the common line 8.

When the gas phase pressure corresponding to the specified minimum differential on valve 22 is reached, valve 22 will close:

where ΔP _22min - the minimum pressure drop of closing the valve 10,

P _22min - the minimum pressure of the medium in the gas separator 1 when closing the valve 22.

Accordingly, the differential pressure of the opening and closing valves 23 and 26:

where R _23max , P _23min - the maximum and minimum pressure of the medium in the gas separator 1 when opening or closing the valve 23, respectively,

P _6max , P _6min - the maximum and minimum pressure of the medium in front of the shutter 6,

ΔP _23max , ΔP _23min , ΔP _26max , ΔP _26min - pressure drops for opening and closing valves 23 and 26, respectively.

After opening valve 22, the liquid phase is discharged into the common line 8. The level of the liquid phase in the gas separator 1 decreases, the float 5 opens the damper 6. The gas phase accumulated in the compensating tank 25, when the valve 26 is closed, is discharged through the valve 6 into the common line 8. Pressure before damper 6 drops from P _6min to P ₀ , at the same time the pressure in the gas separator 1 continues to rise to P _23max . The pressure drop ΔP _23max opens the valve 23 after the pressure drop in front of the shutter 6 to P ₀ and the gas phase from the separator 1 is discharged into a common line 8, while the gas partially enters the compensation tank 25, where the pressure rises to P _{6 min} . The pressure in the gas separator 1 drops to P _22min and, with a differential ΔP _{22min, the} valve 22 closes, the liquid phase begins to accumulate, the float 5 begins to cover the shutter 6. The pressure in the gas separator 1 increases from P _22min to ΔP _23min . The pressure increases in front of the shutter 6 to P _6min and the valve 23 closes. The damper 6 closes, the valve 26 is still closed. The gas phase begins to accumulate in the gas separator 1. The compensating container 25 is designed to create a time gap between the opening of the valve 6 and the opening of the valve 23, closing of the valve 22 and closing of the valve 23, to ensure that all the liquid phase accumulated to a predetermined volume is displaced from the gas separator 1 and the gas accumulates phase in compensating tank 25. End of measurement cycle. Pressure ratio:

P _23max > P _22max > P _23min > P _22min > P ₀ , P _6max > P _6min > P ₀

provide a measuring cycle of the device.

The device has returned to the starting position of the measurement cycle described above. Each pair of gas and liquid flow meters includes a volumetric flow meter 18 or 20 of a turbine type and a mass flow meter 19 or 21 of a type of constricting device - a diaphragm. When the gas and liquid phases flow through them, the first volumetric flow meter 18 or 20 measures the instantaneous volumetric flow rate - Q _{o of the} measured flow, the second mass flow meter 19 or 21 - instantaneous mass flow rate Q _{m of} the same stream. Costs are related by the equation:

where ρ is the density of the medium being measured.

Block 62 for calculating, accounting for production, registration and analysis of the readings of flowmeters 18, 19, 20, 21, gas meter 59, differential pressure gauge 54 based on the work pragma laid down in it, not only record and analyze the volume and mass flow rates of the gas, liquid phases and its components , taking into account production, but also calculating the density of gas and sequentially the components of the liquid phase, as well as taking into account previously calculated values of the densities of water and oil, identification, registration and calculation of instantaneous volume and mass flow rates of a possible emulsion its components. With a separate supply of water and oil by a siphon product sampler 41 through a pair of flow meters 19 and 21, block 62 calculates the densities: water - ρ _in , emulsions: - mixtures of water and oil - ρ _e and oil - ρ _n Calculation is performed based on instantaneous values of mass and volumetric flow rates liquids measured simultaneously. Known values of the densities of the components of the liquid phase are used to identify, measure and account for the production of components of the liquid phase. That is, taking into account the measurement of the flow rate of the gas phase, including through the gas meter 59, a differentiated, phase-wise and component-wise measurement of the flow rate of the well is carried out. Based on the data obtained and the testimony of a pair of flow meters 19 and 21, the following are used to calculate the flow rates of the components of a possible emulsion — oil and water: the mass flow equation of the emulsion is known:

and the equation for the volumetric flow rate of the emulsion:

- массовые расходы эмульсии, нефти и воды, составляющих эмульсию,Where

- the mass flow rate of the emulsion, oil and water constituting the emulsion,

- объемные расходы эмульсии, нефти и воды, составляющих эмульсию.

- volumetric flow rates of the emulsion, oil and water constituting the emulsion.

We transform equation (2) taking into account equation (1):

after substitution from equation (3) we have:

whence after simple transformations we get:

The data obtained are taken into account in the general accounting for the extraction of components.

The residual gas dissolved in water and oil, after separation of the gas phase in the gas separator 1 and gravity separator 39, is present in such insignificant amounts by mass that this against the background of permissible measurement errors of the pair 19, 21 cannot affect the accuracy of measuring the well flow rate.

To reduce possible measurement errors, the volumetric flow meters 18 or 19 are installed upstream of the mass flow meters 20 or 21. This is explained as follows: when a narrowing type flows through the mass flow meter 20 or 21, the flow of the measured medium expands to different degrees depending on the flow rate, therefore the flow volume changes: in a gaseous medium due to gas expansion, in a liquid medium due to the release of an unpredictable volume of residues of gas previously dissolved in a liquid medium, and therefore in the case of installation asses the counter 20 or 21 to flow ahead of flow meter 18 and 19 may be additional measurement error volumetric flow rate. To create optimal operating conditions for flow meters 18, 19, 20 and 21, the valves 22, 23 are adjusted according to the instructions for regulating the flow meters to specified, optimal, in order to ensure maximum accuracy, the intervals of the values of the pressure drops on the valves 22, 23: the maximum level of pressure drop is to open valves 22, 23, minimum - to close. According to the readings of the sensors 53 of the differential pressure gauge 54, the beginning and end of the supply of the total portion of the liquid are recorded by recording a sharp change in pressure to · P _22max and κ · P _22min , then the hydrostatic pressure of the liquid column H _{0 of} constant height is measured in the common short bend 44 siphons 42, 43, block 62 calculate the instantaneous average density of the fluid flowing in the column H ₀ according to the formula:

where ρ _W is the instantaneous average density of the fluid N ₀ flowing in the column,

ΔP _article - the measured hydrostatic pressure of a liquid column with a height of H ₀ ,

H ₀ - the specified distance in height between the sensors 53 of the differential pressure gauge 54 - a column of liquid H ₀ ,

g = 9.81 m / s ² - acceleration of gravity;

then the fluid flowing there is identified by density and the relative content of oil and water in the total portion is calculated, the volume and mass flow rates of oil and water are determined taking into account their relative content by the number of total portions of a given volume value, taken separately from the components and alternately from the gravity separator 38 in the accounting period of time, and calculate the average values of the volumetric and mass flow rates of oil and water. The volumetric relative content of oil and water in the total portion is determined as follows: based on equation (9) we compose a system of equations, the validity of which is obvious:

,

,

- объемная доля нефти в столбе жидкости Н₀;Where

- volume fraction of oil in the liquid column H ₀ ;

- объемная доля воды в столбе жидкости Н₀.

- volume fraction of water in the liquid column H ₀ .

We transform equation (10) taking into account equation (11):

where do we have:

in the end we get:

- текущая относительная объемная доля воды в столбе жидкости Н₀;

- the current relative volume fraction of water in the liquid column H ₀ ;

- текущая относительная объемная доля нефти в столбе жидкости Н₀.

- the current relative volume fraction of oil in the liquid column H ₀ .

и

в течение времени t - сброса общей порции меняются от нуля до единицы и наоборот. Относительное объемное содержание нефти и воды в общей порции вычисляют блоком 62 по следующим формулам:Quantities

and

during the time t - reset, the total portion changes from zero to one and vice versa. The relative volumetric content of oil and water in the total portion is calculated by block 62 according to the following formulas:

- объемная доля нефти в общей порции,

- volume fraction of oil in the total portion,

- объемная доля воды в общей порции,

- volume fraction of water in the total portion,

where ρ _n and ρ _in - peak values of the density of oil and water in the total portion,

ρ _W - the current value of the density of the liquid in the column H ₀ .

Given the insignificance of the volume of the liquid column H ₀ in comparison with the volume of the total portion, it can be argued that the error in measuring the density and volume fraction of oil and water will be mainly determined by the accuracy of pressure measurement by sensors 53 of the differential pressure gauge 54. Measurement of density and volume fractions of oil and water in the total servings in this way is also possible in the event that a possible oil-water emulsion flows in the liquid column H ₀ . The size of the total portion of the selected fluid and the time of its discharge are determined by setting the joint operation of the float 5 and the shutter 6 by adjusting the connection between them, ensures the stability of the flow rate of wells and is determined empirically when setting up the device. The measurement and calculation data according to the sensors 53 of the differential pressure gauge 54 duplicate the measurements according to the flow meters 19, 21. Both measurement methods are compared and analyzed by block 62. The analysis results are the basis for assessing the quality and reliability of the device. When a gas "bubble" breaks out of the wells into the gas separator 1, the pressure of the gas phase in it increases sharply and the emergency liquid phase is forced out of the gas separator 1 into the emergency tank 16 communicated with it, additionally compressing the gas cushion in it. The liquid phase level in the gas separator 1 drops sharply, the float 5 lowers and opens the shutter 6, if it is not open. The valve 23 opens, if it is closed, under the influence of an increased pressure drop across it, due to a sharp increase in the pressure of the gas phase in the gas separator 1 and a drop in the pressure of the medium behind the valve 23. When the rod 27 moves up, the sleeve 36 is pressed by the spring 37 against the stop at the end of the rod 27, together with the washer 35, is also carried upward until the washer 35 contacts the upper magnet 32 and stops. With a normal pressure drop, the force created by it on the shut-off element 29 and the throttle 30 minus the spring force of the spring 31 does not exceed the spring force of the pre-compressed additional spring 37, so the stem 27 cannot move further and stops in the extreme fixed position “Open”. The locking element 29 moves away from the seat 28 by an amount that ensures the maximum throughput of the valve 23. But the pressure drop during the breakthrough of the gas "bubble" is much higher than the maximum level and the rod 27 additionally compresses the spring 37 and spring 31 and, sliding in the sleeve 36, additionally raises the locking element 29 above the seat 28, leading the throttle 30 out of contact with the passage channel of the seat 28, in excess of the extreme fixed position “Open”, which ensures the maximum flow capacity of the valve 23. The excess gas phase ext but is discharged from the gas separator 1. The compensating pressure vessel 25 increases to P _6maks. Through the opened valve 26 and the shutter 6, the excess gas phase is discharged into the common line 8. The pressure of the gas phase in the gas separator 1 rapidly drops to the previous value, the liquid phase flowing into the emergency tank 16 under the pressure of the gas cushion in it returns to the gas separator 1, the liquid level The phases in it are restored, the float 5 and with it the shutter 6 return to their previous position. Valve 23, if it was previously closed, will close, if it is open, it will return to the extreme fixed position “Open”. Valve 22, if it was previously closed, will open in the same way as valve 23, in case of an emergency increase in the pressure of the gas phase, if the pressure of the gas phase in the gas separator 1 does not have time to return to its previous value. Part of the gas phase will penetrate the gravity separator 38 and will be dumped along the discharge line 57 to the common line 8. Valve 22, if it was open, will return to its previous “Open” state after the gas phase is reset. A pair of 18, 20 flow meters on the gas line 7 and during the discharge continues to measure the flow rate of the gas phase. The range of permissible pressure drops for a pair of 18, 20 gas flowmeters is wider than liquid, and the level of measurement error of the flow meters 18, 20 on the gas line 7 during discharge of the excess gas phase therefore will not practically change. The accuracy of the measurement of the liquid phase by flow meters 19, 21 during an emergency discharge may be impaired, but given the short duration of the emergency discharge, this violation will practically not affect the accuracy of production accounting, and since emergency discharge does not significantly affect the measurement accuracy in a duplicate way, this method is used as standard for correcting measurement errors in the main way. The valve 26 after the pressure drop of the gas phase in the compensating tank 25 to P _6min closes.

идентификацию нефти или воды, определение объемного относительного содержания нефти или воды блоком 62 по формулам (9)÷(17) в отбираемой и сбрасываемой общей порции заданной величины по результатам замера, подсчет количества сброшенных общих порций нефти или воды в учетный отрезок времени, вычисление средних объемных и массовых расходов нефти и воды блоком 62 и сброс порций в общую линию 8. Сброс жидкой фазы во время аварийного роста давления газовой фазы при прорыве из скважин газового «пузыря» не оказывает заметного влияния на точность измерения дебита устройством.Variant I of the method for measuring the flow rate of wells, unlike the main version, excludes the measurement of instantaneous volumetric and mass flow rates of the components of the liquid phase by flow meters 19, 21 and instead includes the measurement using sensors 53 of the differential pressure gauge 54 of the hydrostatic pressure of the liquid column in the common short bend 44 siphons 42, 43 of a given height H ₀ , the calculation of the instantaneous fluid density in the elbow 44 according to the formula

identification of oil or water, determination of the volumetric relative content of oil or water by block 62 according to formulas (9) ÷ (17) in the selected and discarded total portion of a given value according to the measurement results, counting the number of dumped total portions of oil or water in the accounting time interval, calculation of average the volume and mass flow rates of oil and water by block 62 and the discharge of portions into a common line 8. The discharge of the liquid phase during an emergency increase in the pressure of the gas phase when a gas bubble breaks out of the wells does not significantly affect the accuracy of measurements rhenium flow rate device.

идентификацию по плотности нефти или воды в отбираемом продуктоотборником 41 очередной отдельной порции, известной постоянной величины объема, определяемой опытным путем при настройке устройства в отличие от I варианта способа, подсчет количества отобраных порций нефти и воды в учетный отрезок времени, вычисление блоком 62 средних объемных и массовых расходов нефти и воды и сброс отобранных порций в общую линию 8. Начало и конец сброса порции идентифицированной жидкости определяют датчиком 53 дифманометра 54 по изменению величины измеряемой плотности.Variant II of the method for measuring the flow rate of wells, unlike the main version, excludes the measurement of instantaneous volumetric and mass flow rates of the components of the liquid phase by flow meters 19, 21 and instead includes the measurement using sensors 53 of the differential pressure gauge 54 of the hydrostatic pressure of the liquid column in the common short bend 44 siphons 42, 43 of a given height H ₀ , the calculation of the instantaneous fluid density in the elbow 44 according to the formula

identification by the density of oil or water in the selected food sampler 41 of the next separate portion, the known constant volume value, determined empirically when setting up the device in contrast to the first variant of the method, counting the number of selected portions of oil and water in the accounting time interval, calculating by block 62 the average volume and the mass flow rates of oil and water and the discharge of selected portions into a common line 8. The beginning and end of the discharge of a portion of identified liquid is determined by the sensor 53 of the differential pressure gauge 54 th density.

When selecting a portion of oil, oil flows through a common short elbow 44 of siphons 42, 43 and block 62 identifies the flowing oil until the selection changes. When a portion of water is taken, water flows along the long elbow 47 of the upper siphon 42, in the general short elbow 44, the water stands up to the change of selection and block 62 identifies the water until the change of selection.

The volumes of the selected portions of oil and water are constant and are determined by the height H _{6 of the} food sampler 41 and the height of the liquid columns H ₁ and H ₂ , which depend only on the difference in the densities of oil and water and the values of the hydraulic resistance coefficient of the diaphragms 55, 56. Since the listed values are constant, then the volume of the liquid portion taken by the food sampler 41 is constant.

As shown in the description of the implementation of the main implementation of the method for measuring the flow rate of an oil well, the volume taken by the product sampler 41 and the portion of oil discharged into the common line 8

constant and unchanging; water

constant and unchanging

- объем порции нефти,Where

- the volume of a portion of oil,

V _in - the volume of a portion of water,

V _o - the amount of oil accumulated in the vessel 39 before changing the selection of water to the selection of oil or vice versa,

- коэффициент относительного содержания нефти в жидкой фазе, величина постоянная при стабильном функционировании скважины.

- coefficient of relative oil content in the liquid phase, a constant value with stable well operation.

идентификацию по плотности жидкости: нефти или воды в отбираемом продуктоотборником 41 очередной отдельной порции, определение начало и конца процесса отбора по резкому изменению величины замеряемой плотности и, в отличие от I и II вариантов способа измерение величины отрезка времени, в течение которого осуществляют процесс отбора, сброс поочередно идентифицированной жидкости в общую линию 8 и затем вычисление блоком 62 текущего дебита скважин, по компонентам, путем деления величины объема тарированной емкости V₀ на величину отрезка времени осуществления процесса отбора: нефти - для вычисления дебита воды, воды - для вычисления дебита нефти.Variant III of the method for measuring the flow rate of wells, unlike the main version, excludes the measurement of instantaneous volumetric and mass flow rates of the components of the liquid phase by flow meters 19, 21 and instead includes the measurement using sensors 53 of the differential pressure gauge 54 of the hydrostatic pressure of the liquid column in the common short bend 44 siphons 42, 43 of a given height H ₀ , calculation by block 62 of the instantaneous fluid density in the elbow 44 according to the formula

identification by the density of the liquid: oil or water in the selected separate sampler 41 of the next portion, determining the beginning and end of the selection process by a sharp change in the value of the measured density and, unlike the I and II variants of the method, measuring the length of time during which the selection process is carried out, alternately discharge liquid in the identified common line 8 and subsequently calculating unit 62 of the current production rate of wells in the components, by dividing the volume V ₀ tared container on the interval time values and implementing the selection process: oil - to calculate the water flow rate, water - to calculate the oil flow rate.

When water is withdrawn, the liquid phase water from the gas separator through the lower part of the vessel 39 follows the long elbow 47 of the upper siphon 42 and then along the section 61 of the liquid line 17 through the valve 22 to the common line 8. The oil that comes with the water floats into the vessel 39 and accumulates in its upper part, the interface 63 falls down to a height of H ₄ from the upper end position when the selection began, to the lower extreme position when the selection is completed. Thus, during the process of water withdrawal, oil in a volume of V _{0 was} supplied to the calibrated tank 68 of the vessel part 39, limited by H ₄ height, which makes it possible to determine the oil flow rate.

In the selection of oil, oil through the opposite siphon 43 from the upper part of the vessel 39 along the portion 61 of the liquid line 17 and through the valve 22 enters the common line 8. The surface of the section 63 rises up to a height of H ₄ from the lower extreme position, when the selection began, to the upper extreme the position when the selection is over. Oil released volume V _{0 of} calibrated capacity 68 of part of vessel 39, limited by height N ₄ , and instead of it, calibrated capacity 68 received water in volume of V ₀ during the process of oil selection. This makes it possible to determine the flow rate of water. Unlike method variant II, variant III allows determining the flow rate of wells, regardless of the relative oil content m in the liquid phase. The increase in the pressure of the gas phase during the breakthrough of the gas "bubble" does not have a significant effect on the accuracy of measuring the flow rate of the device according to II and III variants of the method.

Using the proposed invention will protect the device from a sharp increase in pressure in the gas separator during the breakthrough of a gas "bubble" from the wells and timely and emergency discharge of excess gas phase into a common line, will also help maintain optimal modes of operation of liquid and gas flow meters with a pressure drop of them, providing accuracy and quality of flow measurement and calculating the density of oil, water and gas, and also due to the efficient and high-quality two-stage separation efti, water and gas, oil and water supply to measure alternately in portions, after the maximum possible settling time, duplicate measurements. The well production rate is measured and taken into account with high accuracy both in general and in oil, water, gas separately. The quality and reliability of the device is monitored and supported by comparing and analyzing the results of two duplicated measuring systems.

Claims (16)

1. A method of measuring the flow rate of oil wells, including a continuous process of separating the oil-gas mixture into components (separation products), comprising: first separating the gas phase from the liquid dispersion of the mixture stream and inertial effect on the gas stream, then separating the liquid phase into oil and water by the sludge method gravitational field, and a repeating measurement cycle, including sequentially: discharge of the gas phase into a common line with simultaneous measurement of its flow rate, accumulation of the liquid phase to a predetermined level and, as a result, w, overlapping the discharge of the gas phase, the accumulation of the gas phase up to a predetermined differential pressure of it and the medium in the common line and, as a result, the discharge of the liquid phase in a portion of a given value into the common line with the simultaneous measurement of its flow rate and the opening of the discharge of the gas phase; as well as maintaining the pressure of the gas phase within the specified limits by dumping it into a common line and dumping a portion of the gas phase, additionally received from the wells with a gas "bubble", regardless of the level of accumulation of the liquid phase, characterized in that the instantaneous volumetric and mass flow rates of the gas phase are measured and its density is calculated, the liquid phase is preliminarily separated during its accumulation, as a result of which individual drops of oil are associated into separate integrated clusters, then throttled and fed to gravity sep a walkie-talkie, where it is finally separated into oil and water, integrated into the layers, which are alternately taken, measure, separately, sequentially their instantaneous volume and mass flow rates, and dump them into a common line with a given portion of a given value, and calculate their densities to identify the liquid by density when taking into account production, and the remaining gas phase released during throttling is discharged after measuring their flow rate into a common line. 2. The method according to claim 1, characterized in that the pressure of the gas phase is maintained within predetermined limits, in case of an emergency receipt of its additional portion, by displacing with the subsequent return of the accumulated liquid phase to the emergency reservoir and dumping the additional portion into the compensating reservoir and into the common line. 3. The method according to claim 1, characterized in that duplicate measurements of the costs of the products of separation of the liquid phase in the process of their alternate selection by sequentially measuring their instantaneous density, identifying by the density of the liquid and determining the relative content, based on the measurement of oil and water in a common portion, counting the number of dumped total portions of a given amount of oil and water in the accounting period of time, calculating the average values of them, oil and water, volume and mass flow rates, and compare the results of measuring the flow rates to both ways, and then analyze the results of the comparison, and make a conclusion about the stability of the value of the allowable flow rate measurement error for corrective action. 4. A method of measuring the flow rate of oil wells, including a continuous process of separating the oil-gas mixture into components (separation products), comprising: first separating the gas phase from the liquid dispersion of the mixture stream and inertial action on the gas stream, then separating the liquid phase into oil and water by the sludge method gravitational field, and a repeating measurement cycle, including sequentially: discharge of the gas phase into a common line, with simultaneous measurement of its flow rate, accumulation of the liquid phase to a predetermined level and, as a result, th overlap reset gaseous phase, accumulation of the gas phase to a predetermined differential pressure, and its environment in the common line and, consequently, the discharge of the liquid phase portion of a predetermined value in a common line with simultaneous measurement of its flow rate and the discharge opening of the gas phase; as well as maintaining the pressure of the gas phase within specified limits by dumping it into a common line and dumping a portion of the gas phase, additionally received from wells with a gas "bubble", regardless of the level of accumulation of the liquid phase, characterized in that the instantaneous volume and mass flow rates of the gas phase are measured and its density is calculated, the liquid phase is preliminarily separated during its accumulation, as a result of which individual droplets of oil are associated into separate integrated clusters, then throttled and fed to the gravitational sep aration, where it is finally separated into oil and water, integrated into the layers, which are alternately taken, separately and sequentially measure their instantaneous density, dumped into a common line and a common portion of a given value, identify the liquid by density and determine the relative content, based on the measurement, of oil and water in a common portion, count the number of dumped total portions of a given amount of oil and water in the accounting period of time and calculate the average values of them, oil and water, volume and mass flow rates, and The gas phase attacks released during throttling are discarded after measuring their flow rate into a common line. 5. The method according to claim 4, characterized in that the pressure of the gas phase is maintained within predetermined limits, in case of emergency receipt of an additional portion thereof, by displacing and then returning the accumulated liquid phase to the emergency capacity and dumping the additional portion of gas into the compensating capacity and into the total line. 6. A method of measuring the flow rate of oil wells, including a continuous process of separating the oil-gas mixture into components (separation products), comprising: first separating the gas phase from the liquid dispersion of the mixture stream and inertial action on the gas stream, then separating the liquid phase into oil and water by the sludge method gravitational field, and a repeating measurement cycle, including sequentially: discharge of the gas phase into a common line with simultaneous measurement of its flow rate, accumulation of the liquid phase to a predetermined level and, as a result, w, overlapping the discharge of the gas phase, the accumulation of the gas phase up to a predetermined differential pressure of it and the medium in the common line and, as a result, the discharge of the liquid phase in a portion of a given value into the common line with the simultaneous measurement of its flow rate and the opening of the discharge of the gas phase; as well as maintaining the pressure of the gas phase within specified limits by dumping it into a common line and dumping a portion of the gas phase, additionally received from wells with a gas "bubble", regardless of the level of accumulation of the liquid phase, characterized in that the instantaneous volume and mass flow rates of the gas phase are measured and its density is calculated, the liquid phase is preliminarily separated during its accumulation, as a result of which individual droplets of oil are associated into separate integrated clusters, then throttled and fed to the gravitational sep aration, where it is finally separated into oil and water, integrated into the layers, which are alternately taken, separately and sequentially measure their instantaneous density, identify the liquid by density, discharge oil and water separately into constant lines in constant portions of a known volume value, previously determined experimentally, determining the beginning and end of the discharge of a portion of the identified fluid by changing the measured density, and calculate the flow rate of the well by the number of portions of oil and water in the reference time interval, residues of the gas phase, separated out by throttling, reset after the measurement of flow rate in the common line. 7. The method according to claim 6, characterized in that the pressure of the gas phase is maintained within predetermined limits, in case of emergency receipt of an additional portion thereof, by displacing and then returning the accumulated liquid phase to the emergency capacity and dumping the additional portion of gas into the compensating capacity and into the total line. 8. A method of measuring the flow rate of oil wells, including a continuous process of separating the oil-gas mixture into components (separation products), comprising: first separating the gas phase from the liquid dispersion of the mixture stream and inertial action on the gas stream, then separating the liquid phase into oil and water by the sludge method gravitational field, and a repeating measurement cycle, including sequentially: discharge of the gas phase into a common line with simultaneous measurement of its flow rate, accumulation of the liquid phase to a given level and, as a result, w, overlapping the discharge of the gas phase, the accumulation of the gas phase up to a predetermined differential pressure of it and the medium in the common line and, as a result, the discharge of the liquid phase in a portion of a given value into the common line with the simultaneous measurement of its flow rate and the opening of the discharge of the gas phase; as well as maintaining the pressure of the gas phase within specified limits by dumping it into a common line and dumping a portion of the gas phase, additionally received from wells with a gas "bubble", regardless of the level of accumulation of the liquid phase, characterized in that the instantaneous volume and mass flow rates of the gas phase are measured and its density is calculated, the liquid phase is preliminarily separated during its accumulation, as a result of which individual drops of oil are associated into separate integrated clusters, then they are throttled and fed to the gravitational sep aration, where it is finally separated into oil and water, integrated into the layers, which are alternately taken, separately and sequentially measure their instantaneous density, identify the liquid by density, determine the beginning and end of the process of selecting the identified liquid by a sharp change in the measured density, measure the length of time, during which the selection process is carried out, alternately identified fluid is discharged into a common line, then the current flow rate of the well is calculated separately for oil and water by doing the value of the volume of the calibrated capacity V ₀ - the part of the gravitational separation cavity inherent in a particular device, by the length of time for the selection process: oil - to calculate the flow rate of water, water - to calculate the flow rate of oil, and the remaining gas phase released during throttling is discharged after measuring their flow in a common line. 9. The method according to claim 8, characterized in that the pressure of the gas phase is maintained within predetermined limits, in case of emergency receipt of its additional portion, by displacing and then returning the accumulated liquid phase to the emergency reservoir and dumping the additional portion of gas into the compensating reservoir and into the total line. 10. A device for measuring the flow rate of oil wells, comprising a gas separator with a product sampler and a float associated with a gas line damper communicating the gas separator with a common line; liquid and gas flow meters, valves installed on a liquid, also communicating gas separator with a common line, and gas lines, with the possibility of fixing them in two extreme positions: “Open” or “Closed”, characterized in that the device includes a calculation unit, production metering , registration and analysis of the readings of flowmeters mounted in pairs that contain volumetric and mass flowmeters, in the indicated order of listing, installed sequentially along the flow on the gas and liquid lines, in front of the valves, also with the possibility of additional opening of the passage above the extreme fixed position “Open”, a gravity separator made in the form of an inclined cylindrical vessel with a throttle inlet in communication with a siphon product collector consisting of an upper and an opposite siphon having a common short elbow, with a long elbow the upper siphon is communicated with the bottom of the vessel, and the long knee of the opposite siphon is connected to the top of the vessel, and two diaphragms are installed at the inlets of the long elbows of the siphons and facing sharp the edges to the siphons, plunger and gas meter installed sequentially on the discharge line, communicating the upper point of the long elbow of the opposed siphon with the top of the vessel, with a common line, while the bottom of the vessel is connected through a food sampler with a gas separator, the upper point of the upper siphon is connected with a common liquid line a line, and the diameters of the passage section of siphons, the upper and the opposite are connected with the diameter of the section of the liquid line in front of the flow meters dependence:
D _ON = (1,5 ÷ 2,5) · d _VL ,
where D _ON - the diameter of the siphons, upper and opposite,
d _LC - diameter of the liquid line section. 11. The device according to claim 10, characterized in that it includes an emergency tank in communication with a gas separator with a food sampler containing a pit and a sampling pipe, and a valve installed on the gas line downstream of the valve is equipped with a bypass containing compensating tank and valve in series . 12. The device according to claim 10, characterized in that it includes two differential pressure gauges mounted on a common short elbow of siphons, spaced in height by a predetermined distance H ₀ associated with the unit for calculating, accounting for production, recording and analysis of meter readings. 13. The device according to claim 10, characterized in that the upper and opposite siphons are formed by two vertical supply pipes, which are long elbows of siphons, the inputs of which are in communication with the bottom and top of the vessel, respectively, and a connecting link made in the form of a vertical trunk having ends upper and lower double knees, through which the outputs of the vertical supply pipes are in communication with the vertical trunk, which is the common short elbow of siphons, and turned closely relative to the axis of the barrel l to the contact of the long knees of the siphons. 14. A device for measuring the flow rate of oil wells, containing a gas separator with a product sampler and a float associated with a gas line damper communicating with the gas separator with a common line, liquid and gas flow meters, valves installed on a liquid, also communicating gas separator with a common line, and gas lines , with the possibility of fixing them in two extreme positions: “Open” or “Closed”, characterized in that the device includes a unit for calculating, accounting for production, registration and analysis of meter readings, mounted pairs th, which contains volumetric and mass flowmeters, in the indicated order of listing, installed sequentially along the flow on the gas line in front of the valve, made also with the possibility of additional opening of the passage above the extreme fixed position “Open”, a gravity separator made in the form of an inclined cylindrical vessel with a throttle inlet in communication with a siphon product sampler consisting of an upper and an opposite siphon having a common short knee, the long elbow of the upper the background is communicated with the bottom of the vessel, and the long elbow of the opposed siphon is connected to the top of the vessel, of two diaphragms installed at the inlets of the long elbow of the siphon with edges to the siphons, a plunger and a gas meter installed in series on the discharge line, communicating the upper connection point of the long elbow of the opposite siphon with a vessel with a common line, in addition, the bottom of the vessel is connected through a food sampler to a gas separator, the upper point of the upper siphon is connected to the common line by a liquid line, and the diameters of the siphon in, upper and opposite, are connected with the diameter of the liquid line section in front of the valve installed on it, made also with the possibility of additional opening of the passage above the extreme fixed position “Open”, by the dependence:
D _ON = (1,5 ÷ 2,5) · d _VL ,
where D _ON - the diameter of the siphons, upper and opposite,
d _LC - the diameter of the liquid line;
at the same time, on the common short knee of siphons, two differential pressure gauges are installed, spaced in height by a predetermined distance H ₀ , associated with a unit for calculating, recording production, recording and analyzing flowmeter readings. 15. The device according to p. 14, characterized in that it includes an emergency tank in communication with the gas separator with a product sampler containing a pit and a sampling pipe, and the valve installed on the gas line downstream of the valve is equipped with a bypass containing compensating capacity and valve in series . 16. The device according to 14, characterized in that the upper and opposite siphons are formed by two vertical supply pipes, which are long elbows of siphons, the inputs of which are in communication with the bottom and top of the vessel, respectively, and a connecting link made in the form of a vertical trunk having ends upper and lower double knees, through which the outputs of the vertical supply pipes are in communication with the vertical trunk, which is the common short elbow of siphons, and turned closely relative to the axis of the barrel l to the contact of the long knees of the siphons.

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