CN110805427A - Method for realizing three-phase flow metering produced by wellhead - Google Patents
Method for realizing three-phase flow metering produced by wellhead Download PDFInfo
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Abstract
The invention discloses a method for metering three-phase flow produced at a wellhead, which comprises the steps of measuring mixed liquid including liquid oil, gas and water in real time for a single well of an oil field through a preset testing device, outputting a curve reflecting the change of a voltage value of the characteristics of the mixed liquid along with time, obtaining a corresponding average voltage value F1 and correspondingly obtaining the water content F1 of oil-water mixed liquid influenced by gas according to a numerical curve of a time length △ t1 influenced by gas for the curve, obtaining the average voltage value F corresponding to the oil-water mixed liquid and correspondingly obtaining the water content F according to a numerical curve of a corresponding electric value in a time length △ t2 influenced by the liquid oil and the water and not influenced by the gas, measuring the mixed liquid through a flow meter, and obtaining the total volume of a pore plate Q through measurementZ(ii) a And calculating to obtain different volume flows of liquid oil, gas and water in the mixed liquid respectively through a preset calculation formula. The invention can realize the production of oil, gas and water produced at the well headSeparate measurement of the quantities.
Description
Technical Field
The invention relates to the technical field of oil and gas field development and exploitation engineering, in particular to a method for realizing three-phase flow metering produced by a wellhead.
Background
At present, in the field of oilfield development, the measurement of oil, gas and water output of a single wellhead of an oilfield mainly depends on a mobile gas-liquid separation measurement pry.
Disclosure of Invention
The invention aims to provide a method for realizing metering of three-phase flow produced at a wellhead aiming at the technical problems in the prior art.
Therefore, the invention provides a method for realizing metering of three-phase flow produced at a wellhead, which comprises the following steps:
firstly, measuring mixed liquid including liquid oil, gas and water flowing through a connecting pipeline in real time for an oil field single well through a preset testing device, and outputting a curve reflecting the change of a voltage value of the characteristics of the mixed liquid along with time;
secondly, for a curve reflecting the change of the voltage value of the characteristics of the mixed liquor along with time, obtaining a curve area S1 by integrating a numerical curve in any period of time △ t1 influenced by the gas, then carrying out averaging calculation on the curve area S1 and the period of time △ t1 to obtain an average voltage value, taking the average voltage value as an average voltage value F1 under the influence state of the gas, and correspondingly measuring to obtain the water content F1 of the mixed liquor at the moment;
thirdly, for a curve reflecting the change of the voltage value of the characteristics of the mixed liquid along with time, obtaining a numerical curve of a corresponding electric value within an arbitrary period of time △ t2 (in a gas influence state, the corresponding electric value of the oil-water mixed liquid is the minimum value of a gas influence wave line; when the mixed liquid does not contain gas, the corresponding electric value of the oil-water mixed liquid changes along with time to approximate a straight line) which is influenced by liquid oil and water and is not influenced by gas phase, obtaining an area S2 of the curve of the corresponding electric value of the oil-water mixed liquid by integrating, then carrying out averaging calculation on the curve area S2 for a period of time △ t2 to obtain an average voltage value, taking the average voltage value as an average voltage value F (namely the average voltage value F corresponding to the oil-water mixed liquid) under the influence state of the liquid oil and water, and correspondingly measuring the water content;
fourthly, connecting a liquid outlet pipe of the preset testing device with a conveying pipeline, measuring the mixed liquid through a pore plate flowmeter arranged on a liquid inlet pipe 61 of the preset testing device 6, and measuring to obtain the total volume flow Q of the mixed liquid containing liquid oil, gas and waterZ；
The fifth step, according to the total volume flow Q of the mixed liquidZAnd the water content f1 and the water content f are calculated to obtain different volume flow rates respectively corresponding to liquid oil, gas and water in the mixed liquid through a preset calculation formula.
The single well of the oil field comprises a casing, wherein an oil pipe is arranged inside the casing;
the part of the sleeve exposed out of the bottom surface is provided with a Christmas tree;
the bottom end of the oil pipe is provided with an oil pump;
the casing pipe vertically extends downwards into the oil layer;
the oil pipe is connected with the inlet end of the preset testing device through a connecting pipeline;
and the liquid outlet pipe of the preset testing device is connected with the conveying pipeline.
Wherein the preset testing device is a water content analyzer.
Wherein, predetermine testing arrangement specifically includes: a moisture analyzer housing;
the lower parts of the left side and the right side of the shell of the moisture analyzer are respectively communicated with a liquid inlet pipe and a liquid outlet pipe;
the water content analyzer is characterized in that a test core body is arranged in the shell of the water content analyzer;
the water content analyzer comprises a shell, a water content analyzer and a control system, wherein the shell comprises a first vertical pipeline, a rising inclined pipeline and a second vertical pipeline which are sequentially communicated with one another;
the left end of the first vertical pipeline is connected with the right end of the liquid inlet pipe;
the right end of the second vertical pipeline is connected with the left end of the liquid outlet pipe;
the test core is inserted into the first vertical pipeline from top to bottom.
Wherein the total volume flow of the oil-gas-water three-phase mixed liquid measured by the orifice plate flowmeter is QZWherein:
QZ＝Qg+Qw+Qoformula (1);
in the above formula, QZIs the total volume of the mixed solution, Qg is the gas content in the mixed solution, QwIs the volume of water in the mixture, QoIs the crude oil content in the mixed solution.
QW/(Qw+Qo) F, formula (2);
(Qg+Qw+Qo)/(QW+QO)＝f1/f, formula (3);
q can be obtained from the formula (2)O＝(1-f)×QW/f(4)；
Q is eliminated by the formula (2) and the formula (3)W+QOThe following can be obtained:
Qg＝(f1/f2-f)×Qwequation (5);
substituting the above formula (4) and formula (5) into formula (1), eliminating QgAnd QoThe following can be obtained:
volume Q of water in the mixed liquorw＝Qz×(f1-f2)/(f1+f-f3) Equation (6);
substituting equation (6) into equations (4) and (5) yields QoAnd QgAnd QzThe relationship of (a) to (b) is as follows:
crude oil content Q in the mixed solutiono＝Qz×(1-f)(f1-f3)/[f(f1+f-f3)]Equation (7);
gas content Q in the mixed solutiong＝Qz×(f1-f3)/(f1+f-f3) Equation (8).
Compared with the prior art, the technical scheme provided by the invention has the advantages that the method for metering the three-phase flow produced by the wellhead is provided, the preset testing device and the orifice plate differential pressure flowmeter can be installed in the wellhead flow of the single well of the oil field, the yield (namely volume flow) of oil, gas and water produced by the wellhead of the well can be respectively measured, and the method has great production practice significance.
In addition, the method for realizing the metering of the three-phase flow produced by the wellhead can be combined with a data remote transmission communication technology to realize the digital remote metering of the oil, gas and water production quantities produced by the oil well, thereby realizing the miniaturization, low cost and automation.
Drawings
FIG. 1 is a flow chart of a method of metering a three phase flow produced at a wellhead according to the present invention;
FIG. 2 is a schematic diagram of a well site installation state of a preset testing device involved in a method for metering wellhead produced three-phase flow according to the invention;
FIG. 3 is a schematic diagram of an internal structure of a predetermined testing device involved in a method for metering three-phase flow produced at a wellhead according to the present invention;
FIG. 4 is a top view of a pre-set testing apparatus involved in a method of metering three-phase flow produced at a wellhead according to the present invention;
fig. 5 is a schematic diagram of a curve of voltage values output by a testing device and reflecting characteristics of mixed liquor under different conditions, the voltage values being varied with time, in the method for metering three-phase flow produced at a wellhead according to the present invention.
FIG. 6 is a schematic diagram of the testing principle of the high-frequency signal electrical values corresponding to the oil-water mixed media with different water contents;
FIG. 7 is a diagram illustrating the correspondence between different water addition amounts and the electrical values of the mixed liquid;
fig. 8 is a schematic diagram showing a correspondence relationship between the electrical value mV and the water content f when the oil and water are mixed in a liquid state.
Detailed Description
In order that those skilled in the art will better understand the technical solution of the present invention, the following detailed description of the present invention is provided in conjunction with the accompanying drawings and embodiments.
Referring to fig. 1-8, the present invention provides a method for metering three-phase flow produced at a wellhead, comprising the steps of:
firstly, for an oil field single well, a liquid inlet pipe 61 of a preset testing device 6 is communicated with an oil pipe 2 in a casing 1 through a connecting pipeline 7, a mixed liquid including liquid oil, gas and water flowing through the connecting pipeline 7 is measured in real time through the preset testing device 6, and a curve reflecting the change of a voltage value of the mixed liquid along with time is output;
in the first step, it should be noted that, referring to fig. 5, when the mixed liquor produced by the oil well flows through the preset test device, the preset test device can output a mV voltage value reflecting the characteristics of the mixed liquor, and a time distribution curve diagram of the test voltage value is shown in fig. 5;
secondly, for a curve of voltage values reflecting characteristics of the mixed liquor along with time change, integrating a numerical curve in any period of time △ t1 influenced by gas (namely gas phase) to obtain a curve area S1, then averaging the curve area S1 for the time △ t1 to obtain an average voltage value, taking the average voltage value as an average voltage value F1 under the influence state of the gas, and correspondingly measuring to obtain the water content F1 of the mixed liquor at the time (for example, the mixed liquor is measured by an existing water content tester);
thirdly, for a curve of voltage values reflecting characteristics of the mixed liquid along with time change, obtaining a numerical curve of corresponding electric values (namely voltage values) within an arbitrary period of time △ t2 (it needs to be noted that the corresponding electric values of the oil-water mixed liquid are the minimum values of wave lines influenced by gas in a gas-influenced state, when the oil-water mixed liquid does not contain gas, the corresponding electric values of the oil-water mixed liquid change approximately linearly along with time), obtaining an area S2 of the corresponding electric values of the oil-water mixed liquid by integrating, then averaging the area S2 of the curve over a time length △ t2 to obtain an average voltage value, taking the average voltage value as an average voltage value F (namely the corresponding average voltage value F of the oil-water mixed liquid) under the influenced states of the liquid oil and water, and correspondingly measuring the water content F of the mixed liquid at the moment (for example, measuring the mixed liquid by using an existing water content tester);
fourthly, connecting the liquid outlet pipe 62 of the preset testing device 6 with the conveying pipeline 8, and measuring and obtaining the total volume flow Q of the mixed liquid containing liquid oil, gas and water through the orifice plate flowmeter 9 arranged on the liquid inlet pipe 61 of the preset testing device 6Z；
It should be noted that, the orifice flowmeter, as an existing flow measuring device, can measure the flow of gas, steam, liquid and water, and is widely applied to process control and measurement in the fields of petroleum, chemical industry, metallurgy, electric power, heat supply, water supply and the like.
The fifth step, according to the total volume flow Q of the mixed liquidZAnd the water content f1 influenced by the gas phase and the water content f of the mixed liquid obtained by mixing the oil and the water are calculated through a preset calculation formula to obtain different volume flow rates respectively corresponding to the oil, the gas and the water in the mixed liquid.
In the present invention, the orifice plate flowmeter 9 is a differential pressure orifice plate flowmeter, and specifically, may be an YD-W series micro-differential pressure oil well online metering device (of course, may be a product of other manufacturers) produced by beijing yadan petroleum technology development ltd. The orifice flowmeter 9 is used for measuring the total volume of the oil-gas-water three-phase mixed output and meets the environmental conditions of use pressure, temperature and the like required by the invention, so that a manufacturer can perform algorithm adjustment and instrument calibration according to the requirement.
Referring to fig. 2 and 3, for an oil field single well, the single well comprises a casing 1, wherein the casing 1 is internally provided with an oil pipe 2, and an annular space between the oil pipe 2 and the casing 1 is an oil casing annulus;
the part of the sleeve 1 exposed out of the bottom surface is provided with a Christmas tree 5;
the bottom end of the oil pipe 2 is provided with an oil pump 4;
the casing 1 extends vertically downwards into the reservoir 3.
In the field of oil field development, a christmas tree is a wellhead device for producing oil, such as a flowing well or a mechanical production well.
The oil pipe 2 is connected with an inlet end 61 of a preset testing device 6 through a connecting pipeline 7;
the outlet pipe 62 of the test device 6 is connected to the delivery line 8.
In the present invention, the preset testing device 6 may be an existing moisture analyzer (i.e., a moisture content analyzer), as long as it can measure and output a curve of voltage values reflecting characteristics of the mixed liquid with time.
In a specific implementation, referring to fig. 3, the preset testing device 6 may specifically include: moisture analyzer housing 60;
the lower parts of the left side and the right side of the water content analyzer shell 60 are respectively communicated with a liquid inlet pipe 61 and a liquid outlet pipe 62;
inside the moisture analyzer case 60, a test core 63 is installed;
the interior of the water content analyzer casing 60, including a first vertical duct 6301, a rising inclined duct 6303, and a second vertical duct 6302 which are sequentially communicated with each other;
the left end of the first vertical pipeline 6301 is connected with the right end of the liquid inlet pipe 61;
the right end of the second vertical pipe 6302 is connected with the left end of the liquid outlet pipe 62;
the test core 63 is inserted into the first vertical duct 6301 from above.
In particular, the liquid inlet pipe 61 and the liquid outlet pipe 62 (i.e. liquid inlet and outlet pipes) can be round pipes with an inner diameter of 50mm and an outer diameter of 60mm, and are made of 304 stainless steel; stainless steel flanges 64 are arranged on the liquid inlet pipe 61 and the liquid outlet pipe 62; the predetermined testing device 6 as a water content analyzer is connected to a flange-type orifice flowmeter 9 and a flow pipeline of an oil well through a flange 64.
In the concrete implementation, the water content instrument shell 60 is a stainless steel cylinder and is composed of an upper cover 601, an outer cylinder 602 and a lower cover 603, the upper cover 604 and the lower cover 603 are connected with the middle outer cylinder 602 through threads, and thread sealing is realized through an O-shaped sealing ring. The upper part of the outer cylinder 602 is provided with a threaded inlet 6020 which can be used for connecting explosion-proof flexible pipes on site.
In particular, the housing 60 of the moisture meter, the liquid inlet pipe 61 and the liquid outlet pipe 62 (i.e., liquid inlet and outlet pipes) are sealed and fixed by welding.
In the concrete implementation, a stainless steel round stick with the diameter of 2.5mm can be selected as the test core body 63, the outer surface of the core body is a thermal spraying epoxy resin insulating layer (or a thermal spraying tetrafluoroethylene insulating layer), and the thickness of the insulating layer is 0.2-0.3 mm;
in the concrete implementation, the sealing between the core body 63 and the vertical pipe section is tested: the test core 63 is inserted into the first vertical pipe 6301 (i.e., the middle vertical pipe section) from top to bottom;
an upper core protection tube 631 and a lower core protection tube 632 are respectively mounted at the upper and lower ends of the test core 63, and the upper and lower ends of the test core 6 are connected and sealed with the pipe part by the arrangement of a screw base and a seal gasket (e.g., an upper end seal gasket 681 and a lower end seal gasket 682).
In the concrete implementation, the core protection tube: the upper end and the lower end of the testing core body 63 are respectively provided with an upper core body protection tube 631 and a lower core body protection tube 632, the protection tubes are divided into an inner layer and an outer layer, the outer layer is a stainless steel capillary tube with the wall thickness of 1.5-2mm, and the inner layer is a transparent elastic silicone tube with the wall thickness of 1.5-2mm and is in close contact with the testing core body 63; the outer stainless steel capillary tube plays a role in signal shielding on one hand and prevents fluid from scouring the test core body at the bent pipe part on the other hand; the silicone tube of inlayer plays to support and keeps apart and insulating protective action, fish tail insulating layer when avoiding installing stainless steel capillary. The inner silicone tube is firstly installed on the testing core body 63, then the outer stainless steel tube is installed on the testing core body, the effective length of the testing core body 63 between the upper protection tube and the lower protection tube can be ensured to be 150mm,200mm and 300mm (or customized according to the situation, but the effective length is shorter as much as possible to reduce the total volume of the testing equipment), and then resin is poured into the gap between the uppermost part of the upper protection tube 631 of the core body and the lowermost part of the lower protection tube 632 of the core body and is sealed with the testing core body, so that the sealing between the core body protection tube and the testing core body.
In a specific implementation, the test core 63 is connected to a signal circuit board 65 (an integrated circuit board) (via a coaxial shielding line 69, the coaxial shielding line 69 having a coaxial metallic shielding layer 690 thereon).
It should be noted that, for the signal circuit board 65, the high-frequency signal generation circuit main control chip included thereon may adopt the STM32F103 produced by semiconductor production by the intended method as the main control chip; the signal generator included on the circuit can adopt AD9850 to generate high-frequency signals, and AD8130 is used as a signal amplifying circuit; the AD8302 chip can be used for detection; in addition, an LCD local display and a 485 communication serial port are needed to facilitate local and instant display and remote analysis of data. The method can be used for carrying out customized design and production in detail by referring to the fourth chapter of a Master thesis 'radio frequency method crude oil moisture content measurement technology research' in 2018 of Jiang Hai tide of Xian oil university, and a design and production object can be a professor of a microelectronic circuit in university of colleges and universities or a manufacturer specially producing a high-frequency signal generator.
In particular, the middle part of the ascending inclined pipeline 6303 is connected with the lower end of a vertically distributed test liquid inlet pipe 66;
the upper end of the test liquid inlet pipe 66 is covered and provided with a plug 67.
In the present invention, regarding the second step to the fifth step, for the mixed liquid including the liquid oil, the GAS and the water, since the mixing ratio of the GAS and the water components in each mixed liquid is different and the corresponding electrical values are different, the integral area S1 of the numerical curve affected by the GAS in the time period of △ t1 is averaged over the time period of △ t1 to obtain an average electrical value, which is the average electrical value F1 in the GAS affected state, corresponding to the measured water content F1 in the mixed liquid affected by the GAS phase.
In addition, the mixed liquid mainly comprises mixed liquid with different oil-water ratios, a numerical curve influenced by crude oil and water is obtained by averaging the integral area S2 of the numerical curve within a period of △ t2 with the time △ t2 to obtain an average electric value, the measured electric value F of the mixture is obtained, the corresponding measured water content of the mixed liquid of oil and water is F,
in particular, the flowmeter is realized by an orifice plateThe total volume flow of the measured oil-gas-water three-phase mixed liquid (namely the mixed liquid comprising liquid oil, gas and water) is QZWherein:
QZ＝Qg+Qw+Qoformula (1);
in the above formula, QZIs the total volume of the mixed solution, Qg is the gas content in the mixed solution, QwIs the volume of water in the mixture, QoIs the crude oil content in the mixed solution.
QW/(Qw+Qo) F, formula (2);
(Qg+Qw+Qo)/(QW+QO)＝f1/f, formula (3);
q can be obtained from the formula (2)O＝(1-f)×QW/f(4)；
Q is eliminated by the formula (2) and the formula (3)W+QOThe following can be obtained:
Qg＝(f1/f2-f)×Qwequation (5);
substituting the above formula (4) and formula (5) into formula (1), eliminating QgAnd QoThe following can be obtained:
volume Q of water in the mixed liquorw＝Qz×(f1-f2)/(f1+f-f3) Equation (6);
substituting equation (6) into equations (4) and (5) yields QoAnd QgAnd QzThe relationship of (a) to (b) is as follows:
crude oil content Q in the mixed solutiono＝Qz×(1-f)(f1-f3)/[f(f1+f-f3)]Equation (7);
gas content Q in the mixed solutiong＝Qz×(f1-f3)/(f1+f-f3) Equation (8);
it should be noted that, for the present invention, the above gas volume flow rate QgThe volume of the pipeline under the condition of pressure strip is multiplied by a volume expansion coefficient K if the gas volume flow under the normal pressure condition is required to be obtained, wherein the K is P/P0P is the pressure in the pipeline measured by the differential pressure orifice plate flowmeter, P0Is at standard atmospheric pressure.
It should be noted that, for the present invention, the theoretical model of the measurement method of the water content f is from the study on the technology for measuring crude oil water content by radio frequency method in the master paper 2018 of the ginger sea tide of the western-ann petroleum university, the difference is that: in order to facilitate field installation and indoor test debugging, the structure of the water-containing test device is redesigned as shown in figure 3.
The principle of testing the high-frequency signal electrical values corresponding to the oil-water mixed media with different water contents is shown in fig. 6, and when the high-frequency signal electrical values are measured in a laboratory, the testing flow of the testing equipment (namely, the water content testing device, and the preset testing device 6) in fig. 3 is as follows:
1. opening the upper cover (with the integrated circuit board) of the test equipment, and statically suspending the test equipment at one side of the test equipment;
2. sealing a liquid inlet on the left side of the test equipment by using a flange blind plate;
3. unscrewing a sealing plug of the liquid inlet pipe to be tested;
4. electrifying the integrated circuit board, and displaying an electric value mV which can be acquired in an air state on site;
5. placing a horn-shaped funnel on a test liquid inlet pipe, slowly adding pure oil (white wax oil or transformer oil) by using a measuring cylinder or a beaker, stopping adding the oil when liquid flows out from a liquid outlet at the right side, recording the volume V0ml of the added pure oil, and recording the electric value mV of output phase change;
6. adding water into the test liquid inlet pipe by using a measuring cylinder with the volume of 20ml, wherein the water sinks and the oil floats upwards due to the existence of density difference, and the oil is gradually replaced out of the test pipe cavity along with the addition of the water; the water is tap water (or saline solution is used for preparing simulated formation water needing mineralization), 10ml of water is added every time, and each stable electric value mv and accumulated water addition amount ml are recorded;
7. when the cumulative water adding amount reaches V0ml, the pure oil initially added into the pipeline of the experimental facility is considered to be completely replaced by water, and the water adding experiment is stopped.
8. The data are collated, the ordinate is the electrical value mV, the abscissa is the accumulated water content mV, and the chart is drawn as shown in FIG. 7, when the accumulated water addition amount reaches V1, the recorded electrical value is reduced from F0, and when the accumulated water addition amount reaches more than V2, the recorded electrical value is stabilized at FW and does not change any more; the volume of V1 corresponds to the lowermost end of the sensor test core, and the volume of V2 corresponds to the uppermost end of the sensor test core, (V2-V1) in which the oil is replaced by water.
9. The data is rearranged as shown in fig. 8, and the corresponding relation between the electrical value mV and the water content f when the oil and the water are mixed in the liquid state is obtained: in the volume segment of (V2-V1), the water content is increased by [10/(V2-V1) ] 100% when 10ml of water is added, and the data is rearranged, so that the water content F corresponding to different electrical values in the process that the electrical value (namely the voltage value) of the sensor test core is reduced from F0 to FW can be obtained. The electric value F of any point corresponding to the change of the water content from 0 percent to 100 percent can be obtained by curve fitting.
In summary, compared with the prior art, the method for metering three-phase flow produced by a wellhead provided by the invention can be used for installing the preset testing device and the orifice plate differential pressure flowmeter in the wellhead flow of a single well of an oil field, can realize respective measurement of the yield (namely volume flow) of oil, gas and water produced by the wellhead of the well, and has great production practice significance.
In addition, the method for realizing the metering of the three-phase flow produced by the wellhead can be combined with a data remote transmission communication technology to realize the digital remote metering of the oil, gas and water production quantities produced by the oil well, thereby realizing the miniaturization, low cost and automation.
The foregoing is only a preferred embodiment of the present invention, and it should be noted that, for those skilled in the art, various modifications and decorations can be made without departing from the principle of the present invention, and these modifications and decorations should also be regarded as the protection scope of the present invention.
Claims (5)
1. A method for realizing three-phase flow metering produced by a wellhead is characterized by comprising the following steps:
firstly, for an oil field single well, measuring mixed liquid including liquid oil, gas and water flowing through a connecting pipeline (7) of the oil field single well in real time through a preset testing device (6), and outputting a curve reflecting the change of a voltage value of the characteristics of the mixed liquid along with time;
secondly, for a curve reflecting the change of the voltage value of the characteristics of the mixed liquid along with the time, obtaining a curve area S1 by integrating a numerical curve in any period of time △ t1 influenced by gas, then carrying out averaging calculation on the curve area S1 and the period of time △ t1 to obtain an average voltage value, taking the average voltage value as an average voltage value F1 under the influence of the gas, and correspondingly measuring to obtain the water content F1 of the oil-water mixed liquid influenced by the gas phase at the moment;
thirdly, for a curve reflecting the change of the voltage value of the characteristics of the mixed liquid along with time, obtaining the area S2 of the curve of the corresponding electrical value within any period of time △ t2 influenced by liquid oil and water and not influenced by gas phase through integration, then carrying out averaging calculation on the time length △ t2 by the area S2 of the curve to obtain an average voltage value, taking the average voltage value as an average voltage value F under the influence state of the liquid oil and the water, and correspondingly measuring to obtain the water content F of the mixed liquid at the moment;
fourthly, connecting a liquid outlet pipe (62) of the preset testing device (6) with the conveying pipeline (8), measuring the mixed liquid through a pore plate flowmeter (9) arranged on a liquid inlet pipe (61) of the preset testing device (6), and measuring to obtain the total volume flow Q of the mixed liquid containing liquid oil, gas and waterZ；
The fifth step, according to the total volume flow Q of the mixed liquidZAnd the water content f1 influenced by the gas phase and the water content f of the mixed liquid obtained by mixing the oil and the water are calculated through a preset calculation formula to obtain different volume flow rates respectively corresponding to the oil, the gas and the water in the mixed liquid.
2. The method for realizing three-phase flow metering at the wellhead production according to claim 1, characterized in that the oilfield single well comprises a casing (1), the casing (1) is internally provided with a tubing (2);
the part of the sleeve (1) exposed out of the bottom surface is provided with a Christmas tree (5);
the bottom end of the oil pipe (2) is provided with an oil pump (4);
the casing (1) vertically extends downwards into the oil layer (3);
the oil pipe (2) is connected with an inlet end (61) of a preset testing device (6) through a connecting pipeline (7);
and a liquid outlet pipe (62) of the preset testing device (6) is connected with the conveying pipeline (8).
3. The method for realizing three-phase flow metering at wellhead production according to claim 1, characterized in that the preset testing device (6) is a water content analyzer.
4. The method for metering three-phase flow produced at a wellhead as claimed in claim 1, characterized in that the presetting test device (6) comprises in particular: a moisture analyzer housing (60);
the lower parts of the left side and the right side of the moisture analyzer shell (60) are respectively communicated with a liquid inlet pipe (61) and a liquid outlet pipe (62);
a test core body (63) is arranged inside the water content analyzer shell (60);
the water content analyzer comprises a water content analyzer shell (60), a first vertical pipeline (6301), a rising inclined pipeline (6303) and a second vertical pipeline (6302) which are sequentially communicated with one another;
the left end of the first vertical pipeline (6301) is connected with the right end of the liquid inlet pipe (61);
the right end of the second vertical pipeline (6302) is connected with the left end of the liquid outlet pipe (62);
the test core (63) is inserted into the first vertical pipe (6301) from the top down.
5. The method for realizing three-phase flow measurement produced by a wellhead as claimed in any one of claims 1 to 4, wherein the total volume flow of the oil-gas-water three-phase mixed liquid measured by the orifice plate flowmeter is QZWherein:
QZ＝Qg+Qw+Qoformula (1);
in the above formula, QZIs the total volume of the mixed solution, Qg is the gas content in the mixed solution, QwIs the volume of water in the mixture, QoIs the crude oil content in the mixed solution.
QW/(Qw+Qo) F, formula (2);
(Qg+Qw+Qo)/(QW+QO)＝f1/f, formula (3);
q can be obtained from the formula (2)O＝(1-f)×QW/f(4)；
Q is eliminated by the formula (2) and the formula (3)W+QOThe following can be obtained:
Qg＝(f1/f2-f)×Qwequation (5);
substituting the above formula (4) and formula (5) into formula (1), eliminating QgAnd QoThe following can be obtained:
volume Q of water in the mixed liquorw＝Qz×(f1-f2)/(f1+f-f3) Equation (6);
substituting equation (6) into equations (4) and (5) yields QoAnd QgAnd QzThe relationship of (a) to (b) is as follows:
crude oil content Q in the mixed solutiono＝Qz×(1-f)(f1-f3)/[f(f1+f-f3)]Equation (7);
gas content Q in the mixed solutiong＝Qz×(f1-f3)/(f1+f-f3) Equation (8).
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