CN115825373A - Prediction method and device of natural gas hydrate, storage medium and computer equipment - Google Patents
Prediction method and device of natural gas hydrate, storage medium and computer equipment Download PDFInfo
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Abstract
The application discloses a natural gas hydrate prediction method, a natural gas hydrate prediction device, a storage medium and computer equipment. The method comprises the following steps: acquiring a target water content of the natural gas and a corresponding relation between the water content and a preset coefficient of a hydrate; determining a preset coefficient corresponding to the target water content according to the corresponding relation; calculating the pressure critical value of the hydrate corresponding to each preset temperature interval according to the preset coefficient and the temperature threshold values of the plurality of preset temperature intervals; and if the environmental temperature of the environment where the natural gas is located is within any preset temperature interval, determining hydrate generation information of the environment where the natural gas is located according to the magnitude relation between the pressure critical value corresponding to any preset temperature interval and the environmental pressure of the environment where the natural gas is located. According to the method, the judgment standard of the hydrate generation condition is constructed by calculating the target water content of the natural gas with low complexity, and the hydrate prediction cost is reduced on the basis of ensuring the hydrate prediction accuracy.
Description
Technical Field
The application relates to the technical field of natural gas storage and transportation, in particular to a method, a device, a storage medium and computer equipment for predicting natural gas hydrate.
Background
In the process of natural gas exploitation and transportation, the natural gas generally faces the severe environment of low temperature and high pressure, water in the natural gas can be separated out at a low enough temperature and a high enough pressure, and natural gas hydrate is formed under a certain condition. Along with the adhesion and aggregation of the natural gas hydrate, hydrate blockage easily occurs in a natural gas conveying pipeline, so that the heat value of natural gas can be reduced, the conveying capacity of the conveying pipeline is influenced, and huge economic loss is caused.
In the related art, natural gas hydrates are predicted using thermodynamic models or hydrate models based on hydrate formation kinetics. However, the use of the mathematical model requires complex calculation procedures and iterative calculation of a large number of parameters, the use threshold is high, the operation difficulty is high, in addition, for different water-rich phase systems, different model mathematics need to be adopted for description, a single mathematical model is difficult to adapt to changeable use scenes, and the hydrate generation prediction cost is further improved.
Disclosure of Invention
In view of this, the present application provides a method, an apparatus, a storage medium, and a computer device for predicting a gas hydrate, which construct a criterion for determining a hydrate formation condition by calculating a target water content of a gas with a low complexity, and reduce a hydrate prediction cost on the basis of ensuring the hydrate prediction accuracy.
According to an aspect of the present application, there is provided a method for predicting natural gas hydrates, including:
acquiring a target water content of the natural gas and a corresponding relation between the water content and a preset coefficient of a hydrate;
determining a preset coefficient corresponding to the target water content according to the corresponding relation;
calculating the pressure critical value of the hydrate corresponding to each preset temperature interval according to the preset coefficient and the temperature threshold values of the plurality of preset temperature intervals;
and if the environmental temperature of the environment where the natural gas is located is within any preset temperature interval, determining hydrate generation information of the environment where the natural gas is located according to the magnitude relation between the pressure critical value corresponding to any preset temperature interval and the environmental pressure of the environment where the natural gas is located.
Optionally, obtaining the target water content of the natural gas specifically includes:
acquiring the random water content of the natural gas;
determining a gas phase fugacity coefficient and a liquid phase fugacity coefficient of the natural gas according to the gas phase component parameters of the natural gas;
and (3) performing iterative operation on the random water content according to the gas phase fugacity coefficient and the liquid phase fugacity coefficient based on the fugacity equation of the natural gas hydrate phase equilibrium principle to determine the target water content.
Optionally, the pressure critical value of the hydrate corresponding to each preset temperature interval is calculated according to the preset coefficient and the temperature threshold values of the plurality of preset temperature intervals, and the following formula is adopted:
wherein P represents a critical value of pressure, A 1 、A 2 、LOG t 01、LOG t 02、h 1 、h 2 Q represents a preset coefficient, and T represents a temperature threshold.
Optionally, obtaining a corresponding relationship between the water content and a preset coefficient of the hydrate specifically includes:
acquiring a prediction precision grade, and matching a corresponding relation according to the prediction precision grade;
wherein, under the condition that the prediction precision level is the first precision level, the corresponding relation comprises:
if there is a defect of eyesThe standard water content is more than 200mg/m 3 ，A 1 The value range of (A) is 0.04902 +/-0.001 2 The value range of (a) is 145.80977 +/-10, LOG t 01 is-2.02471 +/-0.1 and LOG t 02 is 21.02167 +/-1 and h 1 The value range of (a) is 0.04694 +/-0.001 and h 2 The value range of (a) is 0.08039 +/-0.001, and the value range of q is 0.04688 +/-0.001;
if the target water content is less than or equal to 200mg/m 3 And is greater than 150mg/m 3 ，A 1 The value range of (A) is 0.06218 +/-0.001 2 The value range of (A) is 146.30136 +/-10 and LOG t 01 is-2.40621 +/-0.1 and LOG t 02 has a value range of 21.0495 +/-1 and h 1 The value range of (a) is 0.04766 +/-0.001 and h 2 The value range of (a) is 0.08018 +/-0.001, and the value range of q is 0.04533 +/-0.001;
if the target water content is less than or equal to 150mg/m 3 And is more than 85mg/m 3 ，A 1 The value range of (A) is 0.00731 +/-0.0001, A 2 The value range of (A) is 2.20335 +/-0.1, LOG t 01 is-21.89319 +/-1, LOG t 02 is-17.98678 +/-1 and h 1 The value range of (a) is 0.05054 +/-0.001, h 2 The value range of (a) is 0.13383 +/-0.01, and the value range of q is 0.57908 +/-0.01;
if the target water content is less than or equal to 85mg/m 3 ，A 1 The value range of (A) is 0.15407 +/-0.01 2 The value range of (A) is 263.70669 +/-10 and LOG t 01 is 28.7588 +/-1, LOG t 02 is 6.54229 +/-0.1 and h 1 The value range of (a) is 0.04695 +/-0.001, h 2 The value range of (a) is 0.33323 +/-0.01, and the value range of q is 0.80448 +/-0.01;
when the prediction accuracy level is the second accuracy level, the correspondence relationship includes:
if the target water content is more than 200mg/m 3 ，A 1 The value range of (A) is-6.60181 +/-0.1 2 The value range of (A) is 800.83927 +/-10 and LOG t 01 is-66.89705 +/-1, LOG t 02 is 46.12825±1、h 1 The value range of (A) is 0.0349 +/-0.001 and h 2 The value range of (a) is 0.05937 +/-0.001, and the value range of q is 0.00991 +/-0.0001;
if the target water content is less than or equal to 200mg/m 3 And is more than 150mg/m 3 ，A 1 The value range of (A) is 0.96307 +/-0.01 2 The value range of (A) is 219.73946 +/-10 and LOG t 01 is 39.35777 +/-1, LOG t 02 is 22.28462 +/-1 and h 1 The value range of (a) is 0.04884 +/-0.001 and h 2 The value range of (a) is 0.23263 +/-0.01, and the value range of q is 0.82284 +/-0.01;
if the target water content is less than or equal to 150mg/m 3 And is more than 85mg/m 3 ，A 1 The value range of (A) is 0.77791 +/-0.01 2 The value range of (A) is 182.12123 +/-10 and LOG t 01 is 28.84231 +/-1, LOG t 02 is 14.03702 +/-1 and h 1 The value range of (a) is 0.05156 +/-0.001, h 2 The value range of (a) is 0.27971 +/-0.01, and the value range of q is 0.75716 +/-0.01;
if the target water content is less than or equal to 85mg/m 3 ，A 1 The value range of (A) is 0.69813 +/-0.01 2 The value range of (A) is 190.79597 +/-10 and LOG t 01 is 24.37341 +/-1 and LOG t 02 is 8.75168 +/-0.1 and h 1 The value range of (a) is 0.05353 +/-0.001 and h 2 The value range of (a) is 0.33074 +/-0.01, and the value range of q is 0.76957 +/-0.01.
Optionally, determining hydrate generation information of the environment where the natural gas is located according to a magnitude relation between a pressure critical value corresponding to any preset temperature interval and the environmental pressure of the environment where the natural gas is located, specifically including:
if the pressure critical value corresponding to any preset temperature interval is smaller than or equal to the environmental pressure, determining the hydrate generation information as that the environment of the natural gas meets the hydrate generation condition;
and if the pressure critical value corresponding to any preset temperature interval is greater than the environmental pressure, determining the hydrate generation information as that the natural gas environment does not accord with the hydrate generation condition.
Optionally, the method for predicting natural gas hydrates further comprises:
if the hydrate generation information indicates that the environment of the natural gas meets the hydrate generation condition, calculating the addition amount of the hydrate inhibitor according to the environment temperature, the environment pressure and the liquid production amount of the natural gas;
and outputting the addition amount of the hydrate inhibitor.
Optionally, the method for predicting natural gas hydrates further comprises:
establishing a coordinate system of temperature and pressure, wherein the coordinate system comprises a plurality of preset temperature intervals and pressure critical values;
sequentially connecting coordinate points of pressure critical values corresponding to a plurality of preset temperature intervals in a coordinate system to form a hydrate evolution curve;
and generating and displaying the natural gas hydrate evolution image according to the evolution curve and the coordinate system.
According to another aspect of the present application, there is provided a natural gas hydrate prediction apparatus including:
the acquisition module is used for acquiring the target water content of the natural gas and the corresponding relation between the water content and the preset coefficient of the hydrate;
the determining module is used for determining a preset coefficient corresponding to the target water content according to the corresponding relation; and
calculating the pressure critical value of the hydrate corresponding to each preset temperature interval according to the preset coefficient and the temperature threshold values of the plurality of preset temperature intervals;
and the prediction module is used for determining hydrate generation information of the natural gas environment according to the magnitude relation between the pressure critical value corresponding to any preset temperature interval and the environment pressure of the natural gas environment if the environment temperature of the natural gas environment is in any preset temperature interval.
Optionally, the obtaining module specifically includes:
the first parameter acquisition module is used for acquiring the random water content of the natural gas;
the coefficient calculation module is used for determining a gas-phase fugacity coefficient and a liquid-phase fugacity coefficient of the natural gas according to the gas-phase component parameters of the natural gas;
and the water content calculation module is used for performing iterative operation on the random water content according to the gas phase fugacity coefficient and the liquid phase fugacity coefficient based on the fugacity equation of the natural gas hydrate phase equilibrium principle to determine the target water content.
Optionally, the obtaining module specifically includes:
the second parameter acquisition module is used for acquiring the prediction precision grade;
and the matching module is used for matching the corresponding relation according to the prediction precision grade.
Optionally, the prediction module is specifically configured to determine that the environment where the natural gas is located meets the hydrate generation condition if the pressure critical value corresponding to any one of the preset temperature intervals is less than or equal to the environmental pressure; and if the pressure critical value corresponding to any preset temperature interval is greater than the environmental pressure, determining the hydrate generation information as that the natural gas environment does not accord with the hydrate generation condition.
Optionally, the natural gas hydrate prediction device further includes:
the inhibition module is used for calculating the addition amount of the hydrate inhibitor according to the environment temperature, the environment pressure and the liquid production amount of the natural gas if the hydrate generation information indicates that the environment of the natural gas meets the hydrate generation condition;
and the output module is used for outputting the addition amount of the hydrate inhibitor.
Optionally, the natural gas hydrate prediction device further comprises:
the generating module is used for establishing a coordinate system of temperature and pressure, and the coordinate system comprises a plurality of preset temperature intervals and pressure critical values; sequentially connecting pressure critical value coordinate points corresponding to a plurality of preset temperature intervals in a coordinate system to form a hydrate evolution curve; generating a natural gas hydrate evolution image according to the evolution curve and the coordinate system;
and the display module is used for displaying the natural gas hydrate evolution image.
According to yet another aspect of the present application, there is provided a readable storage medium having stored thereon a program or instructions which, when executed by a processor, implement the steps of the above-described natural gas hydrate prediction method.
According to yet another aspect of the present application, there is provided a computer apparatus comprising a storage medium, a processor and a computer program stored on the storage medium and executable on the processor, the processor implementing the steps of the method for predicting natural gas hydrates described above when executing the program.
By means of the technical scheme, the target water content of the natural gas meeting the natural gas precision requirement is determined based on the natural gas hydrate phase equilibrium principle, and the preset coefficient suitable for natural gas hydrate prediction is matched by utilizing the corresponding relation between the target water content and the preset coefficient of the hydrate and the preset water content. And respectively calculating pressure critical values of the hydrate which is possibly generated under the condition of a plurality of preset temperature intervals according to the preset coefficients so as to obtain the judgment standard of the hydrate generation condition. When the environmental temperature of the environment where the natural gas is located is in any preset temperature interval, the hydrate generation information of whether the actual environment where the natural gas is located can generate a large amount of hydrates or not can be determined by comparing the pressure critical value corresponding to any preset temperature interval with the environmental pressure of the environment where the natural gas is located. On the one hand, the generation condition of the natural gas hydrate in the conveying environment is accurately and quickly predicted according to the water content of the natural gas and the environmental parameters, so that a user can visually know whether the current natural gas conveying environment is dangerous to block by the hydrate or not, corresponding measures are taken in time, the hydrate is effectively prevented from blocking a conveying channel, and an important guarantee is provided for the flowing safety of the natural gas. On the other hand, the judgment standard of the hydrate generation condition is established by calculating the target water content of the natural gas with lower complexity, complex hydrate model establishment and solving processes are not needed, the calculation difficulty is low, the prediction process is simplified, the operation threshold is low, the application range is wide, and the hydrate prediction cost is favorably reduced.
The foregoing description is only an overview of the technical solutions of the present application, and the present application can be implemented according to the content of the description in order to make the technical means of the present application more clearly understood, and the following detailed description of the present application is given in order to make the above and other objects, features, and advantages of the present application more clearly understandable.
Drawings
The accompanying drawings, which are included to provide a further understanding of the application and are incorporated in and constitute a part of this application, illustrate embodiment(s) of the application and together with the description serve to explain the application and not to limit the application. In the drawings:
fig. 1 shows one of the flow diagrams of the prediction method of natural gas hydrate provided by the embodiment of the present application;
fig. 2 shows a second schematic flow chart of a natural gas hydrate prediction method provided in the embodiment of the present application;
FIG. 3 shows one of the gas hydrate evolution images provided by the embodiments of the present application;
fig. 4 shows a second natural gas hydrate evolution image provided in the embodiment of the present application;
fig. 5 shows a block diagram of a natural gas hydrate prediction apparatus provided in an embodiment of the present application.
Detailed Description
The present application will be described in detail below with reference to the accompanying drawings in conjunction with embodiments. It should be noted that the embodiments and features of the embodiments in the present application may be combined with each other without conflict.
Reference will now be made in detail to embodiments of the present application, examples of which are illustrated in the accompanying drawings, wherein like or similar reference numerals refer to the same or similar elements or elements having the same or similar function throughout. The embodiments described below with reference to the accompanying drawings are exemplary only for explaining the present application and are not construed as limiting the present application.
As used herein, the singular forms "a", "an", "the" and "the" are intended to include the plural forms as well, unless the context clearly indicates otherwise. It will be further understood that the terms "comprises" and/or "comprising," when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof. It will be understood that when an element is referred to as being "connected" or "coupled" to another element, it can be directly connected or coupled to the other element or intervening elements may also be present. Further, "connected" or "connected" as used herein may include wirelessly connected or wirelessly attached. As used herein, the term "and/or" includes all or any element and all combinations of one or more of the associated listed items.
Exemplary embodiments according to the present application will now be described in more detail with reference to the accompanying drawings. These exemplary embodiments may, however, be embodied in many different forms and should not be construed as limited to only the embodiments set forth herein. It should be understood that these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the concept of these exemplary embodiments to those of ordinary skill in the art.
In this embodiment, a method for predicting natural gas hydrate is provided, as shown in fig. 1, the method includes:
wherein the target water content is the water content of the natural gas which meets the national standard precision requirement. The corresponding relation between the water content and the preset coefficient of the hydrate can be obtained in advance through experimental data statistics. The preset coefficient is used for representing the relation between the temperature and the pressure in the process of generating or dissociating the hydrate.
In one possible embodiment, step 100, the step of obtaining the target water content of the natural gas specifically includes:
step 111, acquiring the random water content of the natural gas;
it will be appreciated that the random moisture content is an assumed initial value, and may be a manually set value, or a value randomly selected from a preset set of possible moisture content values of the natural gas by a random algorithm for the composition of the natural gas.
Step 112, determining a gas phase fugacity coefficient and a liquid phase fugacity coefficient of the natural gas according to the gas phase component parameters of the natural gas;
specifically, the gas phase component parameters include the content of each gas phase component contained in the natural gas, which may include carbon dioxide, methane, ethane, propane, etc., gas molar volume, gas temperature, gas pressure, etc.
And 113, performing iterative operation on the random water content according to the gas phase fugacity coefficient and the liquid phase fugacity coefficient based on the fugacity equation of the natural gas hydrate phase equilibrium principle to determine the target water content.
In this embodiment, since liquid water and liquid hydrocarbon should not exist in the natural gas under the pressure and temperature of the natural gas junction, the water dew point of the natural gas can indirectly reflect the saturated water vapor content, and then the water dew point and the total pressure of the natural gas can be calculated under the condition that the dry gas composition, the water dew point and the total pressure of the natural gas are known. Specifically, the partial molar fugacity coefficient of the water component in the gas phase (gas phase fugacity coefficient) and the partial molar fugacity coefficient of the water component in the liquid phase (liquid phase fugacity coefficient) are calculated based on the P-R (Peng-Robinson) state equation by the gas phase component parameters of the natural gas. The partial molar fugacity coefficient of the components in the gas phase is equal to the partial molar fugacity coefficient of the components in the liquid phase based on the phase equilibrium principle. Therefore, if the difference value between the fugacity coefficient of the water component in the gas phase and the fugacity coefficient of the water component in the liquid phase does not meet the preset difference value range under the same environment, and the error between the random water content and the actual water content is large, new random water content is obtained again, and the calculation is repeated to perform iterative operation repeatedly until the difference value between the partial molar fugacity coefficient of the water component in the gas phase and the partial molar fugacity coefficient of the water component in the liquid phase can meet the preset difference value range, so that the accuracy of the randomly configured random water content can be verified through the fugacity equation, and when the difference value between the partial molar fugacity coefficient of the water component in the gas phase and the partial molar fugacity coefficient of the water component in the liquid phase can meet the preset difference value range, the randomly set water content is judged to reach the precision requirement, and the random water content is output as the target water content.
Wherein, the standard water content can refer to ISO (GB/T22634-2008) and the calculation program for compiling the natural gas water content/water dew point disclosed in the prior art.
Specifically, since the liquid phase is only water at the time of gas-liquid equilibrium, the pure component fugacity calculation formula is used for calculating the fugacity coefficient of the liquid phase as follows:
when the gas phase is a mixed component of the natural gas, the molar fugacity coefficient of the water vapor is calculated as the gas phase fugacity coefficient only by combining the component mixing rule of the natural gas, and the formula is as follows:
the fugacity equation is as follows:
in the formula (I), the compound is shown in the specification,
expressing the liquid phase fugacity coefficient;
represents the gas phase fugacity coefficient; A. b is an intermediate variable, Z represents a compression factor of the P-R equation of state, a m 、b m Denotes the mixing parameter, x, of a multi-component gas mixture i Denotes the molar fraction of component i in the liquid phase, i.e. the randomly disposed random water content, y i It is considered that y represents the mole fraction of the component i in the gas phase and only water is precipitated due to the water content of the liquid phase i ＝1。
Wherein A = (a (T). Times.p)/(R) 2 ×T 2 ) B = (B (T) × p)/(R × T), R is the gas constant R =8.314 kJ/(kmol · K), p is the gas pressure, T is the gas temperature; a compression factor Z satisfiesZ 3 -(1-B)×Z 2 +(A-2×B-3×B)×Z-(A×B-B 2 -B 3 ) =0; mixing parameters
k ij Is a binary interaction parameter obtained by regression of relevant experimental data of i-j binary pairs, and has a mixing rule
The correlation is carried out based on a P-R (Peng-Robinson) state equation and a gas phase component parameter, wherein the equation is as follows:
v is the gas molar volume, a (T) and b are coefficients, determined by the following formula: a (T) = α (T) r )×a(T c )、b＝0.07780R×(T c /p c )，a(T c )＝0.45725R 2 ×(T c 2 /p c )，α(T r )＝[1+k×(1-T r ) 0.5 )] 2 ，k＝0.37464+1.54226ω-0.26992ω 2 ，T r ＝T/T c ，T c Is the critical temperature, T r Is the relative temperature, p c At the critical pressure, ω is the eccentricity factor of the material.
In a possible embodiment, in step 100, the step of obtaining a correspondence between a water content and a preset coefficient of a hydrate specifically includes:
step 121, obtaining a prediction precision grade;
and the prediction precision grade is used for indicating the required precision of predicting whether the hydrate generation amount is dangerous or not by a user. For example, the higher the prediction accuracy level, the lower the pressure critical value calculated by the preset coefficient under the same temperature condition, the higher the possibility for the absence of hydrate-induced hazard problems when the actual pressure is less than the pressure critical value.
And step 122, matching the corresponding relation between the water content and the preset coefficient of the hydrate according to the prediction precision grade.
And the preset coefficients corresponding to the same preset temperature interval in the corresponding relations matched according to different prediction precision grades are different, so that the subsequently calculated pressure critical values are different.
In the embodiment, the corresponding relations between different prediction precision grades and the preset coefficients of the water content and the hydrate are correlated in advance, and the corresponding relation matched with the prediction precision grades can be obtained by using the correlation relations after the prediction precision grades required by the user are determined. Therefore, the pressure critical value calculated according to the preset coefficient can adapt to different hydrate formation environments, a mathematical model for prediction does not need to be designed for different scenes independently, the application range of the hydrate prediction method is expanded, the prediction difficulty and the required cost are reduced, and reliable data support is provided for natural gas transportation.
step 300, calculating a pressure critical value of the hydrate corresponding to each preset temperature interval according to a preset coefficient and temperature thresholds of a plurality of preset temperature intervals;
wherein, the pressure critical value is the pressure judgment basis for judging whether the generated hydrate amount is dangerous or not.
The temperature threshold may be a maximum value, a minimum value, an average value, a median value, or the like of a preset temperature interval, and the embodiment of the present application is not particularly limited. It should be noted that, in order to ensure consistency of the pressure critical value calculation process of each preset temperature interval, when one preset temperature interval selects the maximum value therein as the temperature threshold value for calculation, other preset temperature intervals also need to use the maximum value as the temperature threshold value.
In this embodiment, the preset coefficient required for calculation is determined by the preset correspondence between the water content and the preset coefficient of the hydrate. And respectively calculating the preset coefficients and the temperature threshold value of each preset temperature interval, and solving the pressure critical value of the hydrate corresponding to each preset temperature interval to determine the pressure critical values under different temperature conditions. Therefore, whether the hydrate generated in the environment where the natural gas is located can cause danger or not can be judged through the magnitude relation between the pressure critical value and the actual environment pressure, the danger situation can be conveniently and timely perceived in a crowded mode, corresponding measures can be taken, and important guarantee is provided for the flowing safety of the natural gas
Specifically, according to a preset coefficient and temperature thresholds of a plurality of preset temperature intervals, calculating a pressure critical value of a hydrate corresponding to each preset temperature interval by using the following formula:
wherein P represents a pressure threshold value, A 1 、A 2 、LOG t 01、LOG t 02、h 1 、h 2 Q represents a preset coefficient, and T represents a temperature threshold.
Specifically, for example, the prediction precision level includes a first precision level and a second precision level. When the prediction accuracy level is the first accuracy level, the hydrate dissociation pressure is used as the pressure critical value, and the corresponding relationship includes:
if the target water content is more than 200mg/m 3 ，A 1 The value range of (A) is 0.04902 +/-0.001 2 The value range of (A) is 145.80977 +/-10 and LOG t 01 is-2.02471 +/-0.1, LOG t 02 has a value range of 21.02167 +/-1 and h 1 The value range of (a) is 0.04694 +/-0.001, h 2 The value range of (a) is 0.08039 +/-0.001, and the value range of q is 0.04688 +/-0.001;
if the target water content is less than or equal to 200mg/m 3 And is greater than 150mg/m 3 ，A 1 The value range of (A) is 0.06218 +/-0.001 2 The value range of (a) is 146.30136 +/-10, LOG t 01 is-2.40621 +/-0.1, LOG t 02 has a value range of 21.0495 +/-1 and h 1 The value range of (a) is 0.04766 +/-0.001 and h 2 The value range of (a) is 0.08018 +/-0.001, and the value range of q is 0.04533 +/-0.001;
if the target water content is less than or equal to 150mg/m 3 And is more than 85mg/m 3 ，A 1 The value range of (A) is 0.00731 +/-0.0001, A 2 The value range of (a) is 2.20335 +/-0.1, LOG t 01 is-21.89319 +/-1, LOG t 02 is-17.98678 +/-1 and h 1 The value range of (a) is 0.05054 +/-0.001 and h 2 The value range of (a) is 0.13383 +/-0.01, and the value range of q is 0.57908 +/-0.01;
if the target water content is less than or equal to 85mg/m 3 ，A 1 The value range of (A) is 0.15407 +/-0.01 2 The value range of (a) is 263.70669 +/-10, LOG t 01 is 28.7588 +/-1, LOG t 02 is 6.54229 +/-0.1 and h 1 The value range of (a) is 0.04695 +/-0.001 and h 2 The value range of (a) is 0.33323 +/-0.01, and the value range of q is 0.80448 +/-0.01.
When the prediction accuracy level is the first accuracy level, pressure critical value curves of a plurality of temperature sections are calculated according to a preset coefficient as shown in fig. 3, wherein a part above the curve represents a hydrate dangerous area, and a part below the curve represents a hydrate safe area.
It will be understood that for the determination of the predetermined coefficient, a value may be randomly selected from the range of values, or the values may be selected according to the variation law of the target water content, for example, if the target water content is 210mg/m respectively 3 And 250mg/m 3 Are all more than 200mg/m 3 Determining A 1 The value range of (a) is 0.04902 +/-0.001, and the target water content is 210mg/m 3 Can be provided with A 1 0.04902, target water content 250mg/m 3 Can be provided with A 1 Is 0.04982.
When the prediction accuracy grade is a second accuracy grade, and the hydrate formation pressure is used as a pressure critical value, the corresponding relationship includes:
if the target water content is more than 200mg/m 3 ，A 1 The value range of (A) is-6.60181 +/-0.1 2 The value range of (A) is 800.83927 +/-10 and LOG t 01 is-66.89705 +/-1, LOG t 02 takingThe value range is 46.12825 +/-1, h 1 The value range of (A) is 0.0349 +/-0.001 and h 2 The value range of (a) is 0.05937 +/-0.001, and the value range of q is 0.00991 +/-0.0001;
if the target water content is less than or equal to 200mg/m 3 And is greater than 150mg/m 3 ，A 1 The value range of (A) is 0.96307 +/-0.01 2 The value range of (A) is 219.73946 +/-10 and LOG t 01 is 39.35777 +/-1, LOG t 02 is 22.28462 +/-1 and h 1 The value range of (a) is 0.04884 +/-0.001, h 2 The value range of (a) is 0.23263 +/-0.01, and the value range of q is 0.82284 +/-0.01;
if the target water content is less than or equal to 150mg/m 3 And is more than 85mg/m 3 ，A 1 The value range of (A) is 0.77791 +/-0.01 2 The value range of (A) is 182.12123 +/-10 and LOG t 01 is 28.84231 +/-1, LOG t 02 is 14.03702 +/-1 and h 1 The value range of (a) is 0.05156 +/-0.001 and h 2 The value range of (a) is 0.27971 +/-0.01, and the value range of q is 0.75716 +/-0.01;
if the target water content is less than or equal to 85mg/m 3 ，A 1 The value range of (A) is 0.69813 +/-0.01 2 The value range of (A) is 190.79597 +/-10 and LOG t 01 is 24.37341 +/-1, LOG t 02 is 8.75168 +/-0.1 and h 1 The value range of (a) is 0.05353 +/-0.001 and h 2 The value range of (a) is 0.33074 +/-0.01, and the value range of q is 0.76957 +/-0.01.
When the prediction accuracy grade is the second accuracy grade, pressure critical value curves of a plurality of temperature intervals are calculated according to the preset coefficient, as shown in fig. 4, wherein a part above the curve represents a hydrate dangerous area, and a part below the curve represents a hydrate safe area.
It should be noted that the environmental temperature of the natural gas environment is generally between-20 ℃ and 20 ℃, and the pressure of the sealwort is generally between 0.1MPa and 19 MPa.
In this embodiment, according to a comparison result between the environmental temperature of the environment where the natural gas is located and the preset temperature interval and a comparison result between the pressure critical value corresponding to the preset temperature interval and the environmental pressure of the environment where the natural gas is located, hydrate generation information indicating whether the environment where the natural gas is actually located can generate a large amount of hydrates can be determined. Therefore, the generation condition of the natural gas hydrate in the conveying environment is accurately and quickly predicted according to the water content of the natural gas and the environmental parameters, so that a user can visually know whether the current natural gas conveying environment is dangerous to block by the hydrate or not and timely take corresponding measures, the hydrate is effectively prevented from blocking a conveying channel, and an important guarantee is provided for the flowing safety of the natural gas.
Specifically, determining hydrate generation information of the environment where the natural gas is located according to a magnitude relation between a pressure critical value corresponding to any preset temperature interval and the environmental pressure of the environment where the natural gas is located includes: if the pressure critical value corresponding to any preset temperature interval is smaller than or equal to the environmental pressure, determining the hydrate generation information as that the environment of the natural gas meets the hydrate generation condition, and possibly having potential safety hazard. If the pressure critical value corresponding to any preset temperature interval is larger than the environmental pressure, the hydrate generation information is determined that the environment where the natural gas is located does not accord with the hydrate generation condition, namely the current environment is safer.
It is worth mentioning that the hydrate generation information can be determined according to the environmental pressure of the environment where the natural gas is located and the environmental temperature. For example, if the environmental pressure of the environment where the natural gas is located is between two adjacent pressure critical values, comparing a preset temperature interval corresponding to any one of the two adjacent pressure critical values with the environmental temperature of the environment where the natural gas is located, and if the environmental temperature is smaller than the minimum value of the preset temperature interval, determining hydrate generation information as that the environment where the natural gas is located meets hydrate generation conditions, which is dangerous; otherwise, determining the hydrate generation information that the natural gas environment does not meet the hydrate generation condition.
Further, as a refinement and an extension of the embodiments of the foregoing embodiments, in order to fully illustrate the implementation process of this embodiment, as shown in fig. 2, after step 400, the method for predicting natural gas hydrate further includes:
wherein the inhibitor is used for inhibiting the growth of hydrates so as to reduce the content of hydrates in the environment. The inhibitor can be methanol or triethylene glycol.
And step 600, outputting the addition amount of the hydrate inhibitor.
The method for outputting the addition amount may be displaying the addition amount, broadcasting the addition amount by voice, and the like, and the embodiment of the present application is not particularly limited.
In this embodiment, after it is determined that the hydrate generation information indicates that the environment of the natural gas meets the hydrate generation condition, it is indicated that the environment of the natural gas meets the hydrate generation condition, and the natural gas under the polygonatum would form a large amount of hydrates, which may cause problems such as blockage of a conveying pipeline. Therefore, the addition amount of the thermodynamic inhibitor can be rapidly calculated according to the temperature, the pressure and the water yield of the site and is output to prompt the inhibitor amount required by a user, the operation is simple, the hydrate problem can be timely relieved for the user, and the probability of occurrence of complete hidden danger is greatly reduced.
In an actual application scene, the addition amount of the hydrate inhibitor is calculated according to the environmental temperature, the environmental pressure and the liquid production amount of natural gas, and the following formula is adopted:
M＝g×(β×T+η×P 0 +c)；
wherein M represents the amount of inhibitor added in the unit of M 3 (ii) a g meterShows water yield in m 3 (ii) a T represents ambient temperature in units; p 0 Represents absolute pressure, in MPa; beta, eta and c are constants, and the values of the beta, eta and c are related to the types of the inhibitors.
Specifically, for example, the inhibitor is triethylene glycol, and the addition amount of triethylene glycol is M = g × (-0.1052687 × T +0.0772992 × P 0 +1.1465284). Taking the inhibitor as methanol as an example, the addition amount of the methanol is M = g × (-0.0362211 × T +0.0260991 × P 0 +0.396229)。
Further, as a refinement and an extension of the embodiments of the foregoing embodiments, in order to fully illustrate the implementation process of this embodiment, after step 300, the method for predicting natural gas hydrate further includes: establishing a coordinate system of temperature and pressure, wherein the coordinate system comprises a plurality of preset temperature intervals and pressure critical values; sequentially connecting pressure critical value coordinate points corresponding to a plurality of preset temperature intervals in a coordinate system to form a hydrate evolution curve; and generating and displaying the natural gas hydrate evolution image according to the evolution curve and the coordinate system.
In this embodiment, a plurality of coordinate systems of the preset temperature intervals and the corresponding pressure critical values are constructed, and a hydrate evolution curve is formed by sequentially connecting the coordinate points of each pressure critical value according to the temperature sequence, as shown in fig. 3 and 4. At this time, the coordinate system and the hydrate evolution curve are displayed as a natural gas hydrate evolution image. When the user predicts the hydrate generation condition under the same natural gas in the same environment again, the environment temperature and the environment pressure can be directly compared with the natural gas hydrate evolution image, the hydrate generation condition can be visually and clearly judged, the step of calculating the repeated calculation pressure critical value is omitted, and the hydrate prediction efficiency is effectively improved.
Further, as shown in fig. 5, as a specific implementation of the natural gas hydrate prediction method, an embodiment of the present application provides a natural gas hydrate prediction apparatus 800, where the natural gas hydrate prediction apparatus 800 includes: an acquisition module 801, a determination module 802, and a prediction module 803.
The acquiring module 801 is configured to acquire a target water content of the natural gas and a corresponding relationship between the water content and a preset coefficient of a hydrate; a determining module 802, configured to determine a preset coefficient corresponding to the target water content according to the corresponding relationship; calculating the pressure critical value of the hydrate corresponding to each preset temperature interval according to the preset coefficient and the temperature threshold values of the plurality of preset temperature intervals; the predicting module 803 is configured to determine, if the ambient temperature of the environment where the natural gas is located is within any preset temperature interval, hydrate generation information of the environment where the natural gas is located according to a size relationship between a pressure critical value corresponding to any preset temperature interval and the ambient pressure of the environment where the natural gas is located.
In the embodiment, the target water content of the natural gas meeting the accuracy requirement of the natural gas is determined based on the natural gas hydrate phase equilibrium principle, and the preset coefficient suitable for natural gas hydrate prediction is matched by utilizing the corresponding relation between the target water content and the preset coefficient of the hydrate and the preset water content. And respectively calculating pressure critical values of the hydrate which is possibly generated under the condition of a plurality of preset temperature intervals according to the preset coefficients so as to obtain the judgment standard of the hydrate generation condition. When the environmental temperature of the environment where the natural gas is located is in any preset temperature interval, the hydrate generation information of whether the actual environment where the natural gas is located can generate a large amount of hydrates or not can be determined by comparing the pressure critical value corresponding to any preset temperature interval with the environmental pressure of the environment where the natural gas is located. On the one hand, the generation condition of the natural gas hydrate in the conveying environment is accurately and quickly predicted according to the water content of the natural gas and the environmental parameters, so that a user can visually know whether the current natural gas conveying environment is dangerous to block by the hydrate or not, corresponding measures are taken in time, the hydrate is effectively prevented from blocking a conveying channel, and an important guarantee is provided for the flowing safety of the natural gas. On the other hand, the judgment standard of the hydrate generation condition is constructed by calculating the target water content of the natural gas with lower complexity, the complex hydrate model building and solving processes are not needed, the calculation difficulty is low, the prediction process is simplified, the operation threshold is low, the application range is wide, and the hydrate prediction cost is favorably reduced.
Further, the obtaining module 801 specifically includes: a first parameter obtaining module (not shown in the figure) for obtaining the random moisture content of the natural gas; a coefficient calculation module (not shown in the figure) for determining a gas phase fugacity coefficient and a liquid phase fugacity coefficient of the natural gas according to the gas phase component parameters of the natural gas; and the water content calculation module (not shown in the figure) is used for performing iterative operation on the random water content according to the gas phase fugacity coefficient and the liquid phase fugacity coefficient based on the fugacity equation of the natural gas hydrate phase equilibrium principle to determine the target water content.
Further, the obtaining module 801 specifically includes: a second parameter obtaining module (not shown in the figure) for obtaining the prediction precision level; and the matching module (not shown in the figure) is used for matching the corresponding relation according to the prediction precision grade.
Further, the prediction module 803 is specifically configured to determine hydrate generation information as that the environment where the natural gas is located meets hydrate generation conditions if the pressure critical value corresponding to any one of the preset temperature intervals is less than or equal to the environmental pressure; and if the pressure critical value corresponding to any preset temperature interval is greater than the environmental pressure, determining the hydrate generation information as that the natural gas environment does not accord with the hydrate generation condition.
Further, the natural gas hydrate prediction apparatus 800 further includes: the inhibition module (not shown in the figure) is used for calculating the addition amount of the hydrate inhibitor according to the environmental temperature, the environmental pressure and the liquid production amount of the natural gas if the hydrate generation information indicates that the environment of the natural gas meets the hydrate generation condition; and the output module (not shown in the figure) is used for outputting the addition amount of the hydrate inhibitor.
Further, the natural gas hydrate prediction apparatus 800 further includes: a generating module (not shown in the figure) for establishing a coordinate system of temperature and pressure, wherein the coordinate system comprises a plurality of preset temperature intervals and pressure critical values; sequentially connecting pressure critical value coordinate points corresponding to a plurality of preset temperature intervals in a coordinate system to form a hydrate evolution curve; generating a natural gas hydrate evolution image according to the evolution curve and the coordinate system; and the display module (not shown in the figure) is used for displaying the natural gas hydrate evolution image.
Specific limitations of the natural gas hydrate prediction device can be referred to the limitations of the natural gas hydrate prediction method in the above, and are not described in detail here. The various modules in the natural gas hydrate prediction apparatus described above may be implemented in whole or in part by software, hardware, and combinations thereof. The modules can be embedded in a hardware form or independent from a processor in the computer device, and can also be stored in a memory in the computer device in a software form, so that the processor can call and execute operations corresponding to the modules.
Based on the methods shown in fig. 1 and fig. 2, correspondingly, the present application further provides a readable storage medium, on which a computer program is stored, and when the computer program is executed by a processor, the method for predicting natural gas hydrates shown in fig. 1 and fig. 2 is implemented.
Based on such understanding, the technical solution of the present application may be embodied in the form of a software product, which may be stored in a non-volatile storage medium (which may be a CD-ROM, a usb disk, a removable hard disk, etc.), and includes several instructions for enabling a computer device (which may be a personal computer, a server, or a network device, etc.) to execute the method according to the implementation scenarios of the present application.
Based on the above methods shown in fig. 1 and fig. 2 and the virtual device embodiment shown in fig. 5, in order to achieve the above object, the present application further provides a computer device, which may specifically be a personal computer, a server, a network device, and the like, where the computer device includes a storage medium and a processor; a storage medium for storing a computer program; a processor for executing a computer program to implement the method for natural gas hydrate prediction as described above with reference to fig. 1 and 2.
Optionally, the computer device may also include a user interface, a network interface, a camera, radio Frequency (RF) circuitry, sensors, audio circuitry, a WI-FI module, and so forth. The user interface may include a Display screen (Display), an input unit such as a keypad (Keyboard), etc., and the optional user interface may also include a USB interface, a card reader interface, etc. The network interface may optionally include a standard wired interface, a wireless interface (e.g., a bluetooth interface, WI-FI interface), etc.
It will be appreciated by those skilled in the art that the present embodiment provides a computer device architecture that is not limiting of the computer device, and that may include more or fewer components, or some components in combination, or a different arrangement of components.
The storage medium may further include an operating system and a network communication module. An operating system is a program that manages and maintains the hardware and software resources of a computer device, supporting the operation of information handling programs, as well as other software and/or programs. The network communication module is used for realizing communication among components in the storage medium and other hardware and software in the entity device.
Through the description of the above embodiments, it is clear to those skilled in the art that the present application may be implemented by software plus a necessary general hardware platform, and may also be implemented by hardware to obtain a target water content of natural gas and a corresponding relationship between the water content and a preset coefficient of a hydrate; determining a preset coefficient corresponding to the target water content according to the corresponding relation; calculating the pressure critical value of the hydrate corresponding to each preset temperature interval according to the preset coefficient and the temperature threshold values of the plurality of preset temperature intervals; and if the environmental temperature of the environment where the natural gas is located is within any preset temperature interval, determining hydrate generation information of the environment where the natural gas is located according to the magnitude relation between the pressure critical value corresponding to any preset temperature interval and the environmental pressure of the environment where the natural gas is located. According to the embodiment of the application, on the one hand, the generation condition of the natural gas hydrate in the conveying environment is accurately and quickly predicted according to the water content of the natural gas and the environmental parameters, so that a user can visually know whether the hydrate blockage danger exists in the current natural gas conveying environment or not, corresponding measures are taken in time, the hydrate blockage of a conveying channel is effectively avoided, and an important guarantee is provided for the flowing safety of the natural gas. On the other hand, the judgment standard of the hydrate generation condition is constructed by calculating the target water content of the natural gas with lower complexity, the complex hydrate model building and solving processes are not needed, the calculation difficulty is low, the prediction process is simplified, the operation threshold is low, the application range is wide, and the hydrate prediction cost is favorably reduced.
Those skilled in the art will appreciate that the drawings are merely schematic representations of preferred embodiments and that the blocks or flowchart illustrations are not necessary to practice the present application. Those skilled in the art will appreciate that the modules in the devices in the implementation scenario may be distributed in the devices in the implementation scenario according to the description of the implementation scenario, or may be located in one or more devices different from the present implementation scenario with corresponding changes. The modules of the implementation scenario may be combined into one module, or may be further split into a plurality of sub-modules.
The above application serial numbers are for description purposes only and do not represent the superiority or inferiority of the implementation scenarios. The above disclosure is only a few specific implementation scenarios of the present application, but the present application is not limited thereto, and any variations that can be considered by those skilled in the art are intended to fall within the scope of the present application.
Claims (10)
1. A method for predicting gas hydrates, the method comprising:
acquiring a target water content of the natural gas and a corresponding relation between the water content and a preset coefficient of a hydrate;
determining a preset coefficient corresponding to the target water content according to the corresponding relation;
according to the preset coefficient and the temperature threshold values of the plurality of preset temperature intervals, calculating the pressure critical value of the hydrate corresponding to each preset temperature interval;
and if the environmental temperature of the environment where the natural gas is located is within any preset temperature interval, determining hydrate generation information of the environment where the natural gas is located according to the magnitude relation between the pressure critical value corresponding to any preset temperature interval and the environmental pressure of the environment where the natural gas is located.
2. The method for predicting natural gas hydrates according to claim 1, wherein the obtaining of the target water content of the natural gas specifically comprises:
acquiring the random water content of the natural gas;
determining a gas phase fugacity coefficient and a liquid phase fugacity coefficient of the natural gas according to the gas phase component parameters of the natural gas;
and performing iterative operation on the random water content according to the gas phase fugacity coefficient and the liquid phase fugacity coefficient based on the fugacity equation of the natural gas hydrate phase equilibrium principle to determine the target water content.
3. The natural gas hydrate prediction method according to claim 1, wherein the pressure critical value of the hydrate corresponding to each preset temperature interval is calculated according to the preset coefficient and the temperature threshold values of the plurality of preset temperature intervals, and the following formula is adopted:
wherein P represents a critical value of pressure, A 1 、A 2 、LOG t 01、LOG t 02、h 1 、h 2 Q represents a preset coefficient, and T represents a temperature threshold.
4. The natural gas hydrate prediction method according to claim 3, wherein the obtaining of the correspondence between the water content and the preset coefficient of the hydrate specifically includes:
obtaining a prediction precision grade, and matching the corresponding relation according to the prediction precision grade;
wherein, when the prediction accuracy level is a first accuracy level, the corresponding relationship includes:
if the target water content is more than 200mg/m 3 ，A 1 The value range of (A) is 0.04902 +/-0.001 2 The value range of (A) is 145.80977 +/-10 and LOG t 01 is-2.02471 +/-0.1, LOG t 02 is 21.02167 +/-1 and h 1 The value range of (a) is 0.04694 +/-0.001, h 2 The value range of (a) is 0.08039 +/-0.001, and the value range of q is 0.04688 +/-0.001;
if the target water content is less than or equal to 200mg/m 3 And is greater than 150mg/m 3 ，A 1 The value range of (A) is 0.06218 +/-0.001 2 The value range of (a) is 146.30136 +/-10, LOG t 01 is-2.40621 +/-0.1, LOG t 02 has a value range of 21.0495 +/-1 and h 1 The value range of (a) is 0.04766 +/-0.001 and h 2 The value range of (a) is 0.08018 +/-0.001, and the value range of q is 0.04533 +/-0.001;
if the target water content is less than or equal to 150mg/m 3 And more than 85mg/m 3 ，A 1 The value range of (A) is 0.00731 +/-0.0001, A 2 The value range of (A) is 2.20335 +/-0.1, LOG t 01 is-21.89319 +/-1, LOG t 02 is-17.98678 +/-1 and h 1 The value range of (a) is 0.05054 +/-0.001 and h 2 The value range of (a) is 0.13383 +/-0.01, and the value range of q is 0.57908 +/-0.01;
if the target water content is less than or equal to 85mg/m 3 ，A 1 The value range of (A) is 0.15407 +/-0.01 2 The value range of (A) is 263.70669 +/-10 and LOG t 01 is 28.7588 +/-1, LOG t 02 is 6.54229 +/-0.1 and h 1 The value range of (a) is 0.04695 +/-0.001 and h 2 The value range of (a) is 0.33323 +/-0.01, and the value range of q is 0.80448 +/-0.01;
when the prediction accuracy level is a second accuracy level, the correspondence relationship includes:
if the target water content is more than 200mg/m 3 ，A 1 The value range of (A) is-6.60181 +/-0.1 2 The value range of (A) is 800.83927 +/-10 and LOG t 01 is-66.89705 +/-1, LOG t 02 is 46.12825 +/-1 and h 1 The value range of (A) is 0.0349 +/-0.001 and h 2 The value range of (a) is 0.05937 +/-0.001, and the value range of q is 0.00991 +/-0.0001；
If the target water content is less than or equal to 200mg/m 3 And is more than 150mg/m 3 ，A 1 The value range of (A) is 0.96307 +/-0.01 2 The value range of (A) is 219.73946 +/-10 and LOG t 01 is 39.35777 +/-1, LOG t 02 is 22.28462 +/-1 and h 1 The value range of (a) is 0.04884 +/-0.001, h 2 The value range of (a) is 0.23263 +/-0.01, and the value range of q is 0.82284 +/-0.01;
if the target water content is less than or equal to 150mg/m 3 And is more than 85mg/m 3 ，A 1 The value range of (A) is 0.77791 +/-0.01 2 The value range of (a) is 182.12123 +/-10, LOG t 01 is 28.84231 +/-1, LOG t 02 is 14.03702 +/-1 and h 1 The value range of (a) is 0.05156 +/-0.001 and h 2 The value range of (a) is 0.27971 +/-0.01, and the value range of q is 0.75716 +/-0.01;
if the target water content is less than or equal to 85mg/m 3 ，A 1 The value range of (A) is 0.69813 +/-0.01 2 The value range of (A) is 190.79597 +/-10 and LOG t 01 is 24.37341 +/-1, LOG t 02 is 8.75168 +/-0.1 and h 1 The value range of (a) is 0.05353 +/-0.001, h 2 The value range of (a) is 0.33074 +/-0.01, and the value range of q is 0.76957 +/-0.01.
5. The method for predicting natural gas hydrates according to claim 1, wherein the determining hydrate formation information of the environment in which the natural gas is located according to a magnitude relation between a pressure critical value corresponding to any one of the preset temperature intervals and an environmental pressure of the environment in which the natural gas is located specifically includes:
if the pressure critical value corresponding to any preset temperature interval is smaller than or equal to the environmental pressure, determining hydrate generation information as that the environment of the natural gas meets hydrate generation conditions;
and if the pressure critical value corresponding to any preset temperature interval is larger than the environmental pressure, determining that the environment where the natural gas is located does not accord with hydrate generation conditions.
6. The method of predicting natural gas hydrates according to claim 5, further comprising:
if the hydrate generation information indicates that the environment of the natural gas meets the hydrate generation condition, calculating the addition amount of a hydrate inhibitor according to the environment temperature, the environment pressure and the liquid production amount of the natural gas;
and outputting the addition amount of the hydrate inhibitor.
7. The natural gas hydrate prediction method according to any one of claims 1 to 6, further comprising:
establishing a coordinate system of temperature and pressure, wherein the coordinate system comprises a plurality of preset temperature intervals and the pressure critical value;
sequentially connecting coordinate points of the pressure critical value corresponding to the plurality of preset temperature intervals in the coordinate system to form a hydrate evolution curve;
and generating and displaying a natural gas hydrate evolution image according to the evolution curve and the coordinate system.
8. An apparatus for predicting natural gas hydrates, the apparatus comprising:
the acquisition module is used for acquiring the target water content of the natural gas and the corresponding relation between the water content and the preset coefficient of the hydrate;
the determining module is used for determining a preset coefficient corresponding to the target water content according to the corresponding relation; and
calculating the pressure critical value of the hydrate corresponding to each preset temperature interval according to the preset coefficient and the temperature threshold values of the plurality of preset temperature intervals;
and the prediction module is used for determining hydrate generation information of the environment where the natural gas is located according to the size relation between the pressure critical value corresponding to any preset temperature interval and the environmental pressure of the environment where the natural gas is located if the environmental temperature of the environment where the natural gas is located is within any preset temperature interval.
9. A readable storage medium having stored thereon a program or instructions, which when executed by a processor, carries out the steps of the method of natural gas hydrate prediction according to any one of claims 1 to 7.
10. A computer device comprising a storage medium, a processor and a computer program stored on the storage medium and executable on the processor, wherein the processor when executing the program implements the method of natural gas hydrate prediction according to any one of claims 1 to 7.
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