CN115266658A - Method and device for measuring liquid content of wet gas oil-gas-water three-phase fluid - Google Patents
Method and device for measuring liquid content of wet gas oil-gas-water three-phase fluid Download PDFInfo
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Abstract
The application discloses a method and a device for measuring the liquid content of a wet gas oil-gas-water three-phase fluid, wherein the method comprises the following steps: the wet gas oil-gas-water three-phase fluid flows out of the gas well through a pipeline; continuously measuring moisture oil gas water three-phase fluid based on a photon technology to obtain the mass phase fraction of each phase medium; judging whether the mass liquid content in the mass phase fraction of each phase medium meets the validity condition; when the mass liquid content (oil content and water content) in the first group of medium mass phase fractions meets the validity condition, inputting the first group of medium mass phase fractions into a valid data set; when the mass liquid content in the second group of medium mass phase fraction does not meet the validity condition, calling an effective data set based on an AI algorithm to calculate to obtain a predicted liquid content meeting the validity condition; and replacing the predicted liquid content with the mass liquid content in the second group of medium mass phase fractions. The accuracy and the effectiveness of mass liquid content under the wet gas condition are improved.
Description
Technical Field
The application relates to the technical field of industrial mixed-phase fluid measurement, in particular to a method and a device for measuring the liquid content of a wet gas oil-gas-water three-phase fluid.
Background
The moisture is a special mixed-phase flow form mainly based on gas, and is widely used in many industries such as oil and gas exploitation, oil refining chemical industry, energy power and the like. The oil and gas industry generally defines moisture as gas well effluents having a gas phase volume fraction of greater than 90% and other liquid phases (including both oil and water phases) and other components (solid phases) volume fractions of less than 10% at operating conditions. Wherein the liquid phase component is mainly composed of entrained alkane components and saturated water generated by the condensation of the ground production system temperature and pressure reduction, and injection agents and the like manually added for preventing the formation of hydrate. The natural gas/shale gas related to an oil-gas field gas wellhead metering room, a transfer station and a combined station belong to the category of moisture.
Moisture metering methods can be divided into two categories: the first is to use the traditional single-phase gas flowmeter to measure the moisture, because the gas contains a small amount of liquid and solid impurities or sand, the indication value of most gas flowmeters will generate the phenomenon of measurement increase, the measurement error usually exceeds more than 30%, the more the liquid content is, the larger the error is; the second is to use a wet gas flowmeter capable of measuring the fraction under the condition of wet gas mixed phase flow, including microwave, ultrasonic, cross-correlation, tracing, process tomography, photoelectric, nuclear magnetic resonance/NMR and ray/photon, and most of them are in the field test or laboratory research and development improvement stage.
The first and second moisture metering methods still adopt the steps of separating each phase of fluid medium (including partial separation) in the mixed phase, and then metering the content of each phase of fluid medium by using a differential pressure flowmeter (such as a throttling device like an orifice plate).
Disclosure of Invention
In order to solve the problem that the mass liquid content cannot be accurately and effectively calculated under the wet gas condition, the application provides a method and a device for measuring the liquid content of a wet gas oil-water three-phase fluid.
In a first aspect, the application provides a method for measuring the liquid content of a wet gas oil-water three-phase fluid, which adopts the following technical scheme:
a method for measuring the liquid content of a wet gas oil-gas-water three-phase fluid comprises the following steps:
the wet gas oil-gas-water three-phase fluid flows out of the gas well through a pipeline;
continuously measuring moisture oil-gas-water three-phase fluid based on a photon technology to obtain multiple groups of medium mass phase fractions, wherein each group of medium mass phase fractions comprises a mass gas content and a mass liquid content, and the mass liquid content comprises a mass oil content and a mass water content;
judging whether the mass liquid content in each group of medium mass phase fraction meets the validity condition;
when the mass liquid content in the first group of medium mass phase fractions meets the validity condition, inputting the first group of medium mass phase fractions into a valid data set;
when the mass liquid content in the mass phase fraction of the second group of media does not meet the validity condition, calling the valid data set based on an AI algorithm to calculate to obtain the predicted liquid content meeting the validity condition;
replacing the predicted liquid content with a mass liquid content in the second set of medium mass phase fractions, and inputting the second set of medium mass phase fractions into the validation data set.
By adopting the technical scheme, in the process of exploiting the gas well, the moisture oil-gas-water three-phase fluid flows out of the gas well through a pipeline, the moisture oil-gas-water three-phase fluid is continuously measured based on the photon quantum technology, a plurality of groups of medium mass phase fractions are obtained, each group of medium mass phase fractions comprises a mass gas content and a mass liquid content, the mass liquid content comprises a mass oil content and a mass water content, whether the mass liquid content in each group of medium mass phase fractions meets an effectiveness condition or not is judged, when the mass liquid content in the first group of medium mass phase fractions meets the effectiveness condition, the first group of medium mass phase fractions are input into an effective data set, when the mass liquid content in the second group of medium mass phase fractions does not meet the effectiveness condition, the effective data set is called based on an AI algorithm to calculate to obtain a predicted liquid content meeting the effectiveness condition, the predicted liquid content is replaced by the mass liquid content in the second group of medium mass phase fractions, and the second group of medium mass phase is input into the effective data set. Because the AI algorithm is continuously carried out in the measurement process of the wet gas oil-gas-water three-phase fluid, the liquid content prediction is more and more accurate when the mass liquid content rate does not meet the validity condition along with the increase of the valid data sets, and the accuracy and the validity of the mass liquid content rate under the wet gas condition are improved.
Optionally, the method for continuously measuring the moisture oil-gas-water three-phase fluid based on the photon technology to obtain the mass phase fraction of the multiple groups of media comprises the following steps:
emitting a first energy level group of light quanta, a second energy level group of light quanta and a third energy level group of light quanta through a phase splitter installed on the pipeline, wherein the energy of the first energy level group of light quanta is 31keV, the energy of the second energy level group of light quanta is 81keV, and the energy of the third energy level group of light quanta is 356keV;
continuously detecting and receiving the actually measured transmission quantity of the light quanta of the three energy level groups corresponding to each fluid medium according to a preset time interval;
acquiring the dielectric-free transmission quantity of the optical quanta of each energy level group;
according to the characteristics of a light quantum source, linear mass absorption coefficients of a first energy level group light quantum and a second energy level group light quantum corresponding to each fluid medium and a Compton scattering constant of a third energy level group light quantum are obtained;
calculating the gas linear quality, the oil linear quality and the water linear quality of each measurement of the moisture oil-gas-water three-phase fluid according to the measured transmission quantity, the medium-free transmission quantity, the linear mass absorption coefficient and the Compton scattering constant;
calculating to obtain the mass gas content, the mass oil content and the mass water content of each measurement according to the gas linear mass, the oil linear mass and the waterline quality;
obtaining the mass liquid content according to the mass oil content and the mass water content measured each time;
and obtaining a group of medium mass phase fractions according to the mass liquid content and the mass gas content of each measurement, and finally obtaining a plurality of groups of medium mass phase fractions measured for multiple times.
Optionally, determining whether the mass liquid content in each group of medium mass phase fractions meets the validity condition includes:
judging whether the mass liquid content in each group of medium mass phase fraction is lower than a moisture condition threshold value or not;
if the moisture condition is not lower than the moisture condition threshold, determining that the moisture oil-gas-water three-phase fluid does not meet the moisture standard;
if the mass oil content is lower than the moisture condition threshold, judging whether the mass oil content and the mass water content in the mass liquid content are negative values;
if the mass oil content and the mass water content are not negative values, determining that the mass liquid content meets the validity condition;
and if negative values exist in the mass oil content and the mass water content, determining that the mass liquid content does not meet the validity condition.
Optionally, inputting the first set of media mass phase fractions into the validation data set, including:
when the mass liquid content in the first group of medium mass phase fraction meets the validity condition, acquiring a first time point when the first group of medium mass phase fraction is measured;
a first time point is associated with a first set of media quality fractions and input to a valid data set.
Optionally, the obtaining of the predicted liquid content meeting the validity condition by calling the valid data set based on the AI algorithm includes:
when the mass liquid content in the second group of medium mass phase fraction does not meet the validity condition, acquiring a second time point when the second group of medium mass phase fraction is measured;
calling historical medium quality facies fractions in the effective data set before a second time point based on an AI algorithm, wherein the historical medium quality facies fractions comprise at least one group of medium quality facies fractions;
and obtaining a predicted liquid content rate meeting the validity condition according to the mass liquid content rate in the historical medium mass phase fraction.
Optionally, the historical media mass phase fraction is a set of media mass phase fractions,
obtaining a predicted liquid content rate meeting an effectiveness condition according to the mass liquid content rate in the historical medium mass phase fraction, wherein the predicted liquid content rate comprises the following steps:
and taking the mass liquid content in the historical medium mass phase fraction as a predicted liquid content, wherein the predicted liquid content meets the validity condition.
Optionally, the historical media mass phase fractions include at least two sets of media mass phase fractions,
obtaining a predicted liquid content rate meeting an effectiveness condition according to the mass liquid content rate in the historical medium mass phase fraction, wherein the predicted liquid content rate comprises the following steps:
acquiring the time point of each group of medium mass phase fractions in the historical medium mass phase fractions, and sequencing all mass liquid containing rates according to time sequence;
obtaining at least two mass liquid contents nearest to the second time point;
performing linear change analysis according to at least two mass liquid contents to obtain a mass liquid content change trend;
and calculating to obtain the predicted liquid content meeting the validity condition according to the change trend of the mass liquid content.
Optionally, replacing the predicted liquid content with a mass liquid content in the second group of medium mass phase fractions, and inputting the second group of medium mass phase fractions into the valid data set, including:
replacing the predicted liquid content with the mass liquid content in the mass phase fraction of the second group of media;
acquiring a second time point when a second group of medium phase fraction is measured;
a second set of media quality phase fractions and a second point in time are input to the valid data set, and the second set of media quality phase fractions is labeled as a predicted data type.
In a second aspect, the application provides a device for measuring the liquid content of a wet gas oil-water three-phase fluid, which adopts the following technical scheme:
the phase separator is arranged on a pipeline, and the pipeline is used for enabling the wet gas oil-gas-water three-phase fluid to flow out of the gas well;
the phase analyzer is used for continuously measuring moisture oil-gas-water three-phase fluid based on a photon technology to obtain multiple groups of medium mass phase fractions, wherein each group of medium mass phase fractions comprises a mass gas content and a mass liquid content, and the mass liquid content comprises a mass oil content and a mass water content;
the AI algorithm module is used for judging whether the mass liquid content in each group of medium mass phase fraction meets the validity condition; when the mass liquid content in the first group of medium mass phase fractions meets the validity condition, inputting the first group of medium mass phase fractions into a valid data set; when the mass liquid content in the second group of medium mass phase fraction does not meet the validity condition, calling an effective data set based on an AI algorithm to calculate to obtain a predicted liquid content meeting the validity condition; and replacing the predicted liquid content rate with the mass liquid content rate in the second group of medium mass phase fractions, and inputting the second group of medium mass phase fractions into the effective data set.
In summary, the present application includes at least one of the following advantageous technical effects:
because the AI algorithm is continuously carried out in the measurement process of the wet gas oil-gas-water three-phase fluid, the liquid content prediction is more and more accurate when the mass liquid content rate does not meet the validity condition along with the increase of the valid data sets, and the accuracy and the validity of the mass liquid content rate under the wet gas condition are improved.
Drawings
FIG. 1 is a schematic flow chart of a method for measuring the liquid content of a wet gas oil-gas-water three-phase fluid.
FIG. 2 is a schematic structural diagram of a liquid content measuring device for a wet gas oil-water three-phase fluid.
Fig. 3 is a schematic flow chart of the present application for determining whether or not the mass liquid content satisfies the validity condition.
Detailed Description
In order to make the objects, technical solutions and advantages of the present application more apparent, the present application is further described in detail below with reference to the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are merely illustrative of the present application and are not intended to limit the present application.
The embodiment of the application discloses a method for measuring the liquid content of a moisture oil-gas-water three-phase fluid.
Referring to fig. 1, the method is performed by steps including:
101, flowing out of a gas well through a pipeline, wherein the gas, oil and water three-phase fluid is wet gas.
The liquid content measuring device of the wet gas oil-gas-water three-phase fluid is shown in fig. 2, wherein a phase splitter 202 is installed on a pipeline 201, an AI algorithm module 203 is connected with the phase splitter 202, the pipeline 201 is arranged to control the flow of the wet gas oil-gas-water three-phase fluid from a gas well in the process of production, and fluid media comprise gas, oil and water.
102, continuously measuring the moisture oil-gas-water three-phase fluid based on a photon technology to obtain a plurality of groups of medium mass phase fractions.
Wherein, based on the continuous measurement moisture oil gas water three-phase fluid of photon technique, specific process is:
(1) Emitting a first energy level group light quantum, a second energy level group light quantum and a third energy level group light quantum through a phase splitter arranged on the pipeline;
specifically, a photon is called photon (photon) for short, and is a basic particle for transferring electromagnetic interaction, and is a standard boson. Photons are carriers of electromagnetic radiation, whereas in quantum-field theory photons are considered as mediators of electromagnetic interactions. Compared to most elementary particles, the stationary mass of a photon is zero, which means that its propagation speed in vacuum is the speed of light. Like other quanta, photons have a wave-particle duality: photons can show the properties of refraction, interference, diffraction and the like of classical waves; and the particularities of the photons can be demonstrated by the photoelectric effect. Photons can only transmit quantized energy, are lattice particles, and are mass-energy phase states of ring quantum particles. The amount of energy of a photon is proportional to the frequency of the light, and the higher the frequency, the higher the energy. When a photon is absorbed by an atom, there is an electron that gains sufficient energy to transition from the inner orbital to the outer orbital, and the atom with the electron transition changes from the ground state to the excited state.
Using a Ba-133 photon source in a phase splitter, emitting photons of a first energy level set having an energy of 31keV, a second energy level set having an energy of 81keV, and a third energy level set having an energy of 356keV, a known Ba-133 photon source having a radioactivity of 25 microliving, emitting nearly one million individual photons of the energy sets 31keV, 81keV and 356keV per second, the phase measurements being performed by measuring the energy of each photon, depending on the photoelectric cross-sections of the substance and the subset of energies 31keV, 81keV, and the compton cross-sections of the substance and the subset of energies of 356keV;
(2) Continuously detecting and receiving the actually measured transmission quantity of the fluid medium corresponding to the light quanta of the three energy level groups according to a preset time interval;
the preset time interval is a time interval for collecting data, and the time interval generally reaches millisecond level;
(3) Acquiring the dielectric-free transmission quantity of the optical quanta of each group of energy levels;
the number of the medium-free transmission is a calibration value and can be obtained through calibration calculation in advance, and the calculation principle is as follows: when a hollow tube without medium is arranged in the pipeline, the phase splitter emits a first energy level group light quantum, a second energy level group light quantum and a third energy level group light quantum, and the medium-free transmission quantity of the received first energy level group light quantum can be detected by the light quantum probe
Dielectric-free transmission quantity of optical quanta of the second energy level group
And the amount of dielectric-free transmission of third energy group photons
；
(4) Acquiring linear mass absorption coefficients of the first energy level group light quanta and the second energy level group light quanta corresponding to each fluid medium, and the Compton scattering constant of the third energy level group light quanta;
wherein, in the exploitation process of the present oil and gas well, the most important fluid media for monitoring each component in the mixed phase fluid flowing out of the oil and gas well are oil, gas and water, and the calculation principle of the calibration value of the linear mass absorption coefficient of each fluid medium is as follows:
setting fluid medium in the pipeline to be full of oil, transmitting a first energy level group light quantum, a second energy level group light quantum and a third energy level group light quantum by the phase analyzer, and detecting the transmission quantity of the oil receiving the first energy level group light quantum by the light quantum probe
Oil transmission number of optical quanta of the second energy level group
And the oil transmission number of the third energy level group optical quantum
；
Setting fluid medium in the pipeline to be full of gas, transmitting a first energy level group light quantum, a second energy level group light quantum and a third energy level group light quantum by the phase analyzer, and detecting the gas transmission quantity of the first energy level group light quantum
Gas transmission number of optical quanta of the second energy level group
And the number of gas transmissions of the third set of energy levels
；
The fluid medium in the pipeline is set to be full of water, and the phase analyzer emits the first energy level group light quantumDetecting the amount of water transmitted by the first set of optical quanta
Water transmission amount of second energy level group optical quantum
And the water transmission number of the third energy level group optical quantum
；
Then according to the full oil photoelectric absorption equation, the full gas photoelectric absorption equation, the full water photoelectric absorption equation and the non-medium transmission quantity of the first energy level group optical quantum
Oil transmission amount
Gas transmission amount
And water transmission amount
Respectively calculating the oil line property absorption coefficient of the first energy level group light quantum
Gas line mass absorption coefficient
And water line quality absorption coefficient
；
The general equation for the photoelectric absorption of each fluid medium of a mixed-phase fluid due to the first set of energy levels for optical quanta (energy 31 keV) is:
wherein the content of the first and second substances,
subscript is
、
Or
，
It is meant that the fluid medium is an oil,
it is meant that the fluid medium is a gas,
by which is meant that the fluid medium is water,
as a property quantity of the oil line,
is the quality quantity of the gas line,
for the water line quality quantity, when the fluid medium in the pipeline is full of oil, the photoelectric absorption general equation of each fluid medium of the first energy level group light quantum is converted into a full-oil photoelectric absorption equation, and the expression of the full-oil photoelectric absorption equation is as follows:
then transmitting no medium
And oil transmission amount
The oil-filled photoelectric absorption equation is substituted to obtain the oil line mass absorption coefficient of the first energy level group light quantum
；
The gas-line mass absorption coefficient of the first energy level group optical quantum is obtained by calculation in the same way as the calculation of the oil-line mass absorption coefficient
And water line mass absorption coefficient
；
According to the full oil photoelectric absorption equation, the full gas photoelectric absorption equation, the full water photoelectric absorption equation and the non-medium transmission quantity of the second energy level group optical quantum
Oil transmission amount
Gas transmission amount
And water transmission amount
And calculating to obtain the oil line mass absorption coefficient of the second energy level group optical quantum
Gas line mass absorption coefficient
And water line quality absorption coefficient
；
The general equation for the photoelectric absorption of each fluid medium of a mixed-phase fluid due to the second energy level set of optical photons (energy 81 keV) is:
when the fluid medium in the pipeline is full of oil, converting the photoelectric absorption general equation of each fluid medium of the second energy level group light quanta into a full-oil photoelectric absorption equation, specifically:
then transmitting no medium
And oil transmission amount
The oil-filled photoelectric absorption equation is substituted to obtain the oil line mass absorption coefficient of the first energy level group light quantum
；
The gas-line mass absorption coefficient of the second energy level group optical quantum is calculated and obtained in the same way as the calculation of the oil-line mass absorption coefficient
And water line quality absorption coefficient
；
Obtaining a Compton scattering constant according to the Compton scattering characteristics of the third energy level group light quanta
Since the secondary radiation after compton scattering depends on the scattering angle and on the properties of the scatterer, which are independent of the material, the energy already reaches the energy of the compton effect for a third energy group of photons with an energy of 356keV, the compton scattering property of which is the compton scattering constant
And the compton absorption equation for each fluid medium of the third energy level set optical quantum (energy 356 keV) mixed-phase fluid is:
(5) Calculating the gas linear quality, the oil linear quality and the water linear quality of each measurement of the moisture oil-gas-water three-phase fluid according to the actually measured transmission quantity, the non-medium transmission quantity, the linear mass absorption coefficient and the Compton scattering constant;
wherein, according to the above-mentioned general photoelectric absorption equation of each fluid medium of the first energy level set of optical quanta, the general photoelectric absorption equation of each fluid medium of the second energy level set of optical quanta, and the Compton absorption equation of each fluid medium of the third energy level set of optical quanta,
order to
，
，
，
，
，
，
，
，T=
；
The set of equations is obtained as:
T=
；
constructing a determinant according to the above equation set
、
、
And
；
wherein the content of the first and second substances,
、
according to the above determinant
、
、
And
to obtain
、
、
And
is expressed as
According to the above
、
、
And
solving to obtain the oil line property quantity of the mixed phase fluid
Gas line quality
And water line quality
。
(6) Calculating the mass gas content, the mass oil content and the mass water content of each measurement according to the gas linear mass, the oil linear mass and the waterline quality;
according to the quality of oil line
Gas line quality
And water line quality
Calculating to obtain the mass oil content
Mass air content
And mass water content
The expression is as follows:
mass oil content
；
Mass air content
；
Mass water content
；
(7) Obtaining the mass liquid content according to the mass oil content and the mass water content measured each time;
mass liquid content
Water content by mass
And mass oil content
Summing;
(8) And obtaining a group of medium mass phase fractions according to the mass liquid content and the mass gas content of each measurement, and finally obtaining a plurality of groups of medium mass phase fractions measured for multiple times.
And 103, judging whether the mass liquid content in each group of medium mass phase fraction meets the validity condition or not.
Wherein the mass-phase fraction algorithm in step 102 covers the full flow condition, i.e., mass air fraction
From zero to one hundred percent, mass water content
And mass oil content
From zero to one hundred percent;
for natural gas/shale gas/tight gas wells, the production is dominated by moisture and the gas fraction is extremely high, i.e., its volumetric gas fraction
Over 90 percent, volume liquid content
(volumetric Water content
And volume oil content
Sum) is less than 10%, in the process of measuring moisture by using photon technology, the absorption of oil and water to photons with different energy is very little, the change of the counting of the photons with different energy is very small, and in addition, the random fluctuation of the counting of the photons makes the measurement of the volume moisture content very difficultThe difficulty often causes the volumetric water content calculated by the algorithm in the step 102 to be invalid (negative or more than 100%);
thus, using a mass ratio to describe moisture having a higher air void fraction, the air void fraction is mass
Over 80 percent, mass liquid holdup
(water content by mass)
And mass oil content
And the sum) is 20% or less. At this time, the water content is determined by mass
And mass oil content
As a measure of mass liquid holdup
And judging the validity. Mass water content
And mass oil content
The validity criterion is: mass water content
And mass oil content
Neither should be negative.
The specific process of determining whether the mass liquid content meets the validity condition is shown in fig. 3, and the steps include:
301, judging whether the mass liquid content in each group of medium mass phase fraction is lower than a moisture condition threshold value or not;
the mass liquid holdup is variable due to the fact that the proportion of the fluid medium coming out of the gas well is variable
Below a moisture condition threshold of 20% is required to be met, if not below 20%, step 302 is performed; if the value is less than 20%, executing step 303;
302, determining that the wet gas oil-water three-phase fluid does not meet the wet gas standard;
303, judging whether the mass oil content and the mass water content in the mass liquid content are negative values; if both are non-negative values, go to step 304; if negative values exist in the mass oil content and the mass water content, executing a step 305;
304, determining that the mass liquid content rate meets the validity condition;
and 305, determining that the mass liquid content rate does not meet the effectiveness condition.
And 104, when the mass liquid content in the first group of medium mass phase fractions meets the validity condition, inputting the first group of medium mass phase fractions into a valid data set.
When the mass liquid content rate meets the validity condition, a first time point when a first group of medium mass phase fraction rate is measured is obtained, and the first time point and the first group of medium mass phase fraction rate are correlated and input into a valid data set.
And 105, when the mass liquid content in the mass phase fraction of the second group of media does not meet the validity condition, calling the valid data set based on the AI algorithm to calculate to obtain the predicted liquid content meeting the validity condition.
And when the mass liquid content rate does not meet the validity condition, acquiring a second time point when a second group of medium mass phase fraction is measured, calling historical medium mass phase fraction before the second time point in the valid data set based on an AI algorithm, wherein the historical medium mass phase fraction comprises at least one group of medium mass phase fraction, and obtaining the predicted liquid content rate meeting the validity condition according to the mass liquid content rate in the historical medium mass phase fraction.
And 106, replacing the predicted liquid content rate with the mass liquid content rate in the second group of medium mass phase fractions, and inputting the second group of medium mass phase fractions into the effective data set.
And replacing the predicted liquid content rate with the mass liquid content rate in the second group of medium mass phase fractions, acquiring a second time point when the second group of medium phase fractions are measured, inputting the second group of medium mass phase fractions and the second time point into the effective data set, and marking the second group of medium mass phase fractions as a predicted data type.
The implementation principle of the embodiment is as follows: the phase analyzer is arranged on a pipeline and measures through three groups of light quanta with different energy levels, sampling and separation assay of solid-phase sand in a mixed-phase fluid are not needed by workers, the moisture oil-gas-water three-phase fluid is continuously measured on the basis of the light quantum technology, multiple groups of medium mass phase fractions are obtained, each group of medium mass phase fractions comprises a mass gas fraction and a mass liquid fraction, the mass liquid fraction comprises a mass oil content and a mass water content, whether the mass liquid content in each group of medium mass phase fractions meets an effectiveness condition or not is judged, when the mass liquid content in the first group of medium mass phase fractions meets the effectiveness condition, the first group of medium mass phase fractions are input into an effective data set, when the mass liquid content in the second group of medium mass phase fractions does not meet the effectiveness condition, the effective data set is called based on an AI algorithm to calculate a predicted liquid content meeting the effectiveness condition, the predicted liquid content is replaced by the mass liquid content in the second group of medium mass phase fractions, and the second group of medium mass phase fractions are input into the effective data set. Because the AI algorithm is continuously carried out in the measurement process of the wet gas oil-gas-water three-phase fluid, the liquid content prediction is more and more accurate when the mass liquid content rate does not meet the validity condition along with the increase of the valid data sets, and the accuracy and the validity of the mass liquid content rate under the wet gas condition are improved.
In the above embodiment of fig. 1, the calculation process of the predicted liquid-containing rate includes the following two ways:
if the current time point is the second measurement, only one previous measurement is carried out, and in an effective data set, the historical medium mass phase fraction is a group of medium mass phase fractions, the mass liquid content in the historical medium mass phase fraction is directly used as the predicted liquid content, and the predicted liquid content meets the effectiveness condition;
(II) if the current second time point is the ith measurement, the effective data set has (i-1) groups of medium mass phase fractions in total, the P/c groups of medium mass phase fractions can be selected by backtracking according to a preset time length P from the second time point to the backtracking and a preset time interval c, wherein P/c is an integer and is more than or equal to 2, the P/c mass liquid contents are subjected to linear change analysis according to time change to obtain a mass liquid content change trend, and the predicted liquid content meeting the effectiveness condition is calculated according to the mass liquid content change trend;
assuming that P is 0.05 second, the preset time interval c is 0.01 second, and the mass liquid content rate measured 100 th time at the second time point does not meet the validity condition, then the mass liquid content rates measured 99 th time, 98 th time, 97 th time and 96 th time, namely 95 th time, need to be selected by backtracking, the variation trends of the mass liquid content rates measured 95 th time, 96 th time, 97 th time, 98 th time and 99 th time are analyzed according to the time sequence, linear fitting is carried out, the predicted liquid content rate is obtained, the predicted liquid content rate needs to meet the validity condition, namely the predicted liquid content rate is lower than 20%, and the predicted mass oil content rate and the predicted mass water content rate in the predicted liquid content rate are not negative;
it should be noted that, in order to prevent the mass liquid content in the historical medium mass phase fractions selected from the valid data set within the preset time period from being the predicted liquid content, which results in inaccurate subsequent prediction, optimization needs to be performed, first, if P is 0.05 second, the preset time interval c is 0.01 second, and the mass liquid content measured 100 th time at the second time point does not satisfy the validity condition, 99 th, 98 th, 97 th, and 96 th times, that is, 95 th times, need to be selected retrospectively, if the medium mass phase fraction at the 96 th time point is marked as the predicted data type, it indicates that the mass liquid content at the 96 th time is predicted, the mass liquid content at the 96 th time point is deleted, and the mass liquid content at the 94 th time point is continuously selected retrospectively, and the change trends of the mass liquid contents at the 94 th, 95 th, 97 th, 98 th, and 99 th times are analyzed in time sequence to perform linearity to obtain the predicted liquid content.
As shown in fig. 2, the embodiment of the present application further discloses a liquid content rate measuring device for a wet gas oil-water three-phase fluid, comprising:
a phase separator 202 mounted on a pipe 201 for flowing a wet gas oil gas water three-phase fluid from a gas well;
the phase analyzer 202 is used for continuously measuring the moisture oil-gas-water three-phase fluid based on a photon technology to obtain a plurality of groups of medium mass phase fractions, wherein each group of medium mass phase fractions comprises a mass gas content and a mass liquid content, and the mass liquid content comprises a mass oil content and a mass water content;
the AI algorithm module 203 is used for judging whether the mass liquid content in each group of medium mass phase fraction meets the validity condition; when the mass liquid content in the first group of medium mass phase fractions meets the validity condition, inputting the first group of medium mass phase fractions into a valid data set; when the mass liquid content in the mass phase fraction of the second group of media does not meet the validity condition, calling the valid data set based on an AI algorithm to calculate to obtain the predicted liquid content meeting the validity condition; and replacing the predicted liquid content rate with the mass liquid content rate in the second group of medium mass phase fractions, and inputting the second group of medium mass phase fractions into the effective data set.
The implementation principle of the embodiment is as follows: in the process of gas well exploitation, a wet gas oil gas water three-phase fluid flows out of a gas well through a pipeline 201, a phase component instrument 202 continuously measures the wet gas oil gas water three-phase fluid on the basis of a photon technology to obtain multiple groups of medium mass phase fractions, each group of medium mass phase fractions comprises a mass gas content and a mass liquid content, the mass liquid content comprises a mass oil content and a mass water content, an AI algorithm module 203 judges whether the mass liquid content in each group of medium mass phase fractions meets an effectiveness condition or not, when the mass liquid content in a first group of medium mass phase fractions meets the effectiveness condition, the first group of medium mass phase fractions are input into an effective data set, when the mass liquid content in a second group of medium mass phase fractions does not meet the effectiveness condition, the effective data set is called to calculate on the basis of an AI algorithm to obtain a predicted liquid content meeting the effectiveness condition, the predicted liquid content is replaced by the mass liquid content in the second group of medium mass phase fractions, and the second group of medium mass phase fractions are input into the effective data set. Because the AI algorithm is continuously carried out in the measurement process of the wet gas oil-gas-water three-phase fluid, the liquid content prediction is more and more accurate when the mass liquid content rate does not meet the validity condition along with the increase of the valid data sets, and the accuracy and the validity of the mass liquid content rate under the wet gas condition are improved.
The foregoing is a preferred embodiment of the present application and is not intended to limit the scope of the application in any way, and any features disclosed in this specification (including the abstract and drawings) may be replaced by alternative features serving equivalent or similar purposes, unless expressly stated otherwise. That is, unless expressly stated otherwise, each feature is only an example of a generic series of equivalent or similar features.
Claims (9)
1. A method for measuring the liquid content of a wet gas oil-gas-water three-phase fluid is characterized by comprising the following steps:
the wet gas oil-gas-water three-phase fluid flows out of the gas well through a pipeline;
continuously measuring the moisture oil-gas-water three-phase fluid based on a photon technology to obtain mass phase fraction of a multi-phase medium, wherein each group of medium mass phase fraction comprises a mass gas content and a mass liquid content, and the mass liquid content comprises a mass oil content and a mass water content;
judging whether the mass liquid content in each group of medium mass phase fraction meets the validity condition;
when the mass liquid content in the first group of medium mass phase fractions meets the validity condition, inputting the first group of medium mass phase fractions into a valid data set;
when the mass liquid content in the second group of medium mass phase fraction does not meet the validity condition, calling the valid data set based on an AI algorithm to calculate to obtain a predicted liquid content meeting the validity condition;
replacing the predicted liquid content with a mass liquid content in the second set of media mass phase fractions and inputting the second set of media mass phase fractions to the active data set.
2. The method for measuring the liquid content of the wet gas oil-gas-water three-phase fluid according to claim 1, wherein the method for continuously measuring the wet gas oil-gas-water three-phase fluid based on the photon technology to obtain a plurality of groups of medium mass phase fractions comprises the following steps:
emitting a first energy level set of optical photons, a second energy level set of optical photons, and a third energy level set of optical photons by a phase splitter mounted on the pipe, the first energy level set of optical photons having an energy of 31keV, the second energy level set of optical photons having an energy of 81keV, and the third energy level set of optical photons having an energy of 356keV;
continuously detecting and receiving the actually measured transmission quantity of the light quanta of the three energy level groups corresponding to each fluid medium according to a preset time interval;
acquiring the dielectric-free transmission quantity of the optical quanta of each energy level group;
according to the characteristics of a light quantum source, acquiring the linear mass absorption coefficients of the first energy level group light quantum and the second energy level group light quantum corresponding to each fluid medium and the Compton scattering constant of the third energy level group light quantum;
calculating the gas linear quality, the oil linear quality and the water linear quality of each measurement of the moisture oil-gas-water three-phase fluid according to the measured transmission quantity, the no-medium transmission quantity, the linear mass absorption coefficient and the Compton scattering constant;
calculating the mass gas content, the mass oil content and the mass water content of each measurement according to the gas linear mass, the oil linear mass and the water linear mass;
obtaining the mass liquid content according to the mass oil content and the mass water content measured each time;
and obtaining a group of medium mass phase fractions according to the mass liquid content and the mass gas content of each measurement, and finally obtaining a plurality of groups of medium mass phase fractions measured for multiple times.
3. The method for measuring the liquid content of the wet gas oil-gas-water three-phase fluid according to claim 1, wherein the step of determining whether the mass liquid content in each group of medium mass phase fractions meets the validity condition comprises the following steps:
judging whether the mass liquid content in each group of medium mass phase fraction is lower than a moisture condition threshold value or not;
if the moisture condition threshold value is not lower than the moisture condition threshold value, determining that the moisture oil-gas-water three-phase fluid does not meet the moisture standard;
if the mass oil content is lower than the moisture condition threshold, judging whether the mass oil content and the mass water content in the mass liquid content are negative values;
if the mass oil content and the mass water content are both non-negative values, determining that the mass liquid content meets the validity condition;
and if negative values exist in the mass oil content and the mass water content, determining that the mass liquid content does not meet the validity condition.
4. The method of claim 3, wherein the inputting the first set of media mass-phase fractions into an effective data set comprises:
when the mass liquid content in the first group of medium mass phase fraction meets the validity condition, acquiring a first time point when the first group of medium mass phase fraction is measured;
associating the first point in time with the first set of media quality fractions for input to a validation data set.
5. The method for measuring the liquid content of the wet gas oil-water three-phase fluid according to claim 4, wherein the step of calling the valid data set based on AI algorithm to calculate the predicted liquid content meeting the validity condition comprises the following steps:
when the mass liquid content in the second group of medium mass phase fraction does not meet the validity condition, acquiring a second time point when the second group of medium mass phase fraction is measured;
invoking historical media quality facies fractions in the valid data set prior to the second point in time based on an AI algorithm, the historical media quality facies fractions comprising at least one set of media quality facies fractions;
and obtaining a predicted liquid content rate meeting the validity condition according to the mass liquid content rate in the historical medium mass phase fraction.
6. The method of claim 5, wherein the historical media mass phase fractions are a set of media mass phase fractions,
the obtaining of the predicted liquid content meeting the validity condition according to the mass liquid content in the historical medium mass phase fraction comprises the following steps:
and taking the mass liquid content in the historical medium mass phase fraction as a predicted liquid content, wherein the predicted liquid content meets the validity condition.
7. The moisture vapor oil gas water three-phase fluid liquid fraction measuring method according to claim 5, wherein the historical medium mass phase fractions comprise at least two sets of medium mass phase fractions,
the obtaining of the predicted liquid content meeting the validity condition according to the mass liquid content in the historical medium mass phase fraction comprises the following steps:
acquiring the time point of each group of medium mass phase fraction in the historical medium mass phase fraction, and sequencing all mass liquid containing rates according to time sequence;
obtaining at least two mass liquid-containing rates closest to the second time point;
performing linear change analysis according to the at least two mass liquid contents to obtain a mass liquid content change trend;
and calculating to obtain the predicted liquid content meeting the effectiveness condition according to the change trend of the mass liquid content.
8. The method of claim 7, wherein said replacing said predicted fluid cut with a mass fluid cut of said second set of media mass phase fractions and inputting said second set of media mass phase fractions into said validation data set comprises:
replacing the predicted liquid content with a mass liquid content in the second set of medium mass phase fractions;
obtaining a second point in time when the second set of medium phase fraction measurements are made;
inputting the second set of media mass phase fractions and the second time point into the valid data set, and labeling the second set of media mass phase fractions as predicted data types.
9. A wet gas oil-gas-water three-phase fluid liquid content measuring device is characterized by comprising:
a phase separator mounted on a conduit for flow of a wet gas oil gas water three phase fluid from a gas well;
the phase analyzer is used for continuously measuring the moisture oil-gas-water three-phase fluid based on a photon technology to obtain multiple groups of medium mass phase fractions, wherein each group of medium mass phase fractions comprises a mass gas content and a mass liquid content, and the mass liquid content comprises a mass oil content and a mass water content;
the AI algorithm module is used for judging whether the mass liquid content in each group of medium mass phase fraction meets the validity condition; when the mass liquid content in the first group of medium mass phase fractions meets the validity condition, inputting the first group of medium mass phase fractions into a valid data set; when the mass liquid content in the second group of medium mass phase fraction does not meet the validity condition, calling the valid data set based on an AI algorithm to calculate to obtain a predicted liquid content meeting the validity condition; replacing the predicted liquid content with a mass liquid content in the second set of media mass phase fractions and inputting the second set of media mass phase fractions to the active data set.
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| CN117890395A (en) * | 2024-03-14 | 2024-04-16 | 成都洋湃科技有限公司 | Heavy caliber finished product crude oil measuring device, method, electronic equipment and measuring system |
| CN118149919A (en) * | 2024-05-08 | 2024-06-07 | 成都洋湃科技有限公司 | Mixed-phase fluid mass flow measuring method and throttling type light quantum mixed-phase flowmeter |
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| Publication number | Priority date | Publication date | Assignee | Title |
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| CN117890395A (en) * | 2024-03-14 | 2024-04-16 | 成都洋湃科技有限公司 | Heavy caliber finished product crude oil measuring device, method, electronic equipment and measuring system |
| CN117890395B (en) * | 2024-03-14 | 2024-05-17 | 成都洋湃科技有限公司 | Heavy caliber finished product crude oil measuring device, method, electronic equipment and measuring system |
| CN118149919A (en) * | 2024-05-08 | 2024-06-07 | 成都洋湃科技有限公司 | Mixed-phase fluid mass flow measuring method and throttling type light quantum mixed-phase flowmeter |
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