CN117057283A - Method for judging time spent in shale gas horizontal well oil pipe descending - Google Patents
Method for judging time spent in shale gas horizontal well oil pipe descending Download PDFInfo
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Abstract
The application discloses a method for judging oil pipe descending time of a shale gas horizontal well, and belongs to the technical field of oil and gas well exploitation. The method comprises the following steps: s1: establishing a shale gas horizontal well oil pipe descending time judging function, wherein the shale gas horizontal well oil pipe descending time judging function is a wellhead oil pipe descending time judging function or a shaft oil pipe descending time judging function; s2: collecting basic parameters of a target well about a time-machine judging function of the shale gas horizontal well oil pipe descending; s3: and calculating a shale gas horizontal well oil pipe descending time judging function value of the target well according to the basic parameters, and judging that the moment corresponding to the corresponding basic parameters is the oil pipe descending time of the target well when the shale gas horizontal well oil pipe descending time judging function value is smaller than 0. The application can judge the corresponding oil pipe descending time according to the basic parameters of the shale gas horizontal well, has stronger adaptability and can provide technical support for oil gas exploitation.
Description
Technical Field
The application relates to the technical field of oil and gas exploitation, in particular to a method for judging the time spent in the oil pipe descending of a shale gas horizontal well.
Background
In the early stage of shale gas well production, casing production is often adopted to rapidly discharge stratum fracturing fluid, shale gas well productivity is released, the pressure, gas yield and liquid yield of a gas well are rapidly decreased in the later period of exploitation, the casing is large in size and weak in liquid carrying capacity, liquid film inversion occurs in a well shaft, and dropsy occurs in the horizontal section of the gas well. Shale gas wells are often subjected to a method of pressing down an oil pipe under pressure before a drainage and gas production process is implemented on site due to the influence of factors such as a complex well body structure and the liquid carrying capacity of a sleeve, so that the liquid carrying capacity of the gas well is improved, and stable production is ensured.
The method comprises the step of determining the oil pipe descending parameters of the horizontal well, wherein the oil pipe descending parameters mainly comprise the descending time, the descending depth and the size of the oil pipe, and the descending time of the oil pipe is a precondition of the oil pipe descending of the horizontal well. At present, the oil pipe running-in time of shale gas wells generally refers to foreign experience, when wellhead pressure is reduced to be within 10 MPa and then oil pipe production is carried out, but the energy, gas production and liquid production of each gas well are different, so that a method for judging the oil pipe running-in time of shale gas horizontal wells is needed, and the running-in time of the oil pipes is judged according to parameters of each well.
Disclosure of Invention
Aiming at the problems, the application aims to provide a method for judging the time spent in the oil pipe descending of the shale gas horizontal well.
The technical scheme of the application is as follows:
a method for judging the oil pipe descending time of a shale gas horizontal well comprises the following steps:
s1: establishing a shale gas horizontal well oil pipe descending time judging function, wherein the shale gas horizontal well oil pipe descending time judging function is a wellhead oil pipe descending time judging function or a shaft oil pipe descending time judging function;
s2: collecting basic parameters of a target well about a time-machine judging function of the shale gas horizontal well oil pipe descending;
s3: and calculating a shale gas horizontal well oil pipe descending time judging function value of the target well according to the basic parameters, and judging that the moment corresponding to the corresponding basic parameters is the oil pipe descending time of the target well when the shale gas horizontal well oil pipe descending time judging function value is smaller than 0.
Preferably, in step S1, when the oil pipe descending judgment function of the shale gas horizontal well is established, it is assumed that the liquid film of the shaft is attached to the pipe wall.
Preferably, in step S1, the wellhead oil pipe descending judgment function is:
（1）
wherein:judging a function value for a wellhead oil pipe descending time; />Is the friction coefficient between the liquid film and the pipe wall;is the liquid phase density of the shaft; />Is void fraction;/>is the friction coefficient between the gas core and the liquid film; />Is the gas phase density of the shaft;is wellbore pressure; />Is the gas phase density of the wellhead; />Is wellhead pressure; />Is the wellhead airflow rate; />Is the wellhead fluid flow rate; />Is the wellhead liquid phase density; />Is the gravity of the liquid film; />Inclination angle for the wellbore from the vertical axis; />Is along the direction of the symmetry axis of the inclined tube; />Is the diameter of the pipeline;
the judgment function of the oil pipe in the shaft during the descending is as follows:
（2）
wherein:judging a function value for the time of descending the oil pipe in the shaft; />Is the wellbore gas flow rate.
Preferably, the void fractionThe calculation is performed by the following formula:
（3）
wherein:is the thickness of the liquid film.
Preferably, the coefficient of friction between the gas core and the liquid filmThe calculation is performed by the following formula:
（4）
wherein:is the thickness of the liquid film.
Preferably, the wellbore gas flow rateThe calculation is performed by the following formula:
（5）
wherein:is a deviation factor; />Is the temperature; />Is the gas production rate; />Is the cross-sectional area of the wellbore.
Preferably, the liquid film is gravityThe calculation is performed by the following formula:
（6）
wherein:liquid holdup for the inclined section; />Gravitational acceleration.
Preferably, in step S3, the smaller the value of the oil pipe descending judgment function of the shale gas horizontal well is, the better the corresponding oil pipe descending judgment function is.
The beneficial effects of the application are as follows:
according to the application, through the oil pipe descending time judging function of the shale gas horizontal well, the function values are obtained by utilizing parameters such as wellhead pressure, liquid production, gas production and the like which are easy to obtain, so that the oil pipe descending time of the shale gas horizontal well is judged, and the adaptability of the oil pipe descending time judging function to each shale gas horizontal well is strong; and different from the single judgment critical liquid carrying flow in the prior art, the method can be used for carrying out combination optimization through the oil pipe descending time judgment function of the shale gas horizontal well, so that a three-dimensional curved surface is established, the relation among all parameters is more intuitively reflected, the descending time of the oil pipe can be more effectively judged, the liquid accumulation in a shaft can be eliminated, the self-injection duration of a gas well is prolonged, and technical support is provided for optimization of the specifications of the oil pipe when the oil pipe is descended in the follow-up oil well.
Drawings
In order to more clearly illustrate the embodiments of the application or the technical solutions of the prior art, the drawings which are used in the description of the embodiments or the prior art will be briefly described, it being obvious that the drawings in the description below are only some embodiments of the application, and that other drawings can be obtained according to these drawings without inventive faculty for a person skilled in the art.
FIG. 1 is a schematic diagram of a liquid film stress analysis;
FIG. 2 is a graph showing the results of the thickness of the liquid film as a function of the tilt angle;
FIG. 3 is a schematic diagram showing liquid film inversion;
FIG. 4 is a schematic diagram of the result of the wellhead oil pipe down time judgment chart;
FIG. 5 is a schematic diagram of the results of a timing judgment chart for the lowering of an oil pipe in a well bore;
FIG. 6 is a schematic diagram of calculation results according to an embodiment.
Detailed Description
The application will be further described with reference to the drawings and examples. It should be noted that, without conflict, the embodiments of the present application and the technical features of the embodiments may be combined with each other. It is noted that all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs unless otherwise indicated. The use of the terms "comprising" or "includes" and the like in this disclosure is intended to cover a member or article listed after that term and equivalents thereof without precluding other members or articles.
As shown in fig. 1, the application provides a method for judging the oil pipe descending time of a shale gas horizontal well, which comprises the following steps:
s1: and establishing a shale gas horizontal well oil pipe descending time judging function, wherein the shale gas horizontal well oil pipe descending time judging function is a wellhead oil pipe descending time judging function or a shaft oil pipe descending time judging function.
In a specific embodiment, when the oil pipe descending judgment function of the shale gas horizontal well is established, the shaft liquid is assumed to be attached to the pipe wall through a liquid film.
At present, the models for calculating critical liquid carrying flow are mainly a liquid drop model and a liquid film model, wherein the liquid drop model is simpler and widely applied to various large gas fields at home and abroad, and the liquid film model is more practical although the parameters are more involved. In the above embodiment, it is assumed that the wellbore liquid is a liquid film attached to the pipe wall, which can make the judgment result of the established and obtained shale gas horizontal well oil pipe descending time judging function more accurate.
In a specific embodiment, the wellhead tubing down time judgment function is:
（1）
wherein:judging a function value for a wellhead oil pipe descending time; />Is the friction coefficient between the liquid film and the pipe wall;is the liquid phase density of the shaft; />Is void fraction; />Is the friction coefficient between the gas core and the liquid film; />Is the gas phase density of the shaft;is wellbore pressure; />Is the gas phase density of the wellhead; />Is wellhead pressure; />Is the wellhead airflow rate; />Is the wellhead fluid flow rate; />Is the wellhead liquid phase density; />Is the gravity of the liquid film; />Inclination angle for the wellbore from the vertical axis; />Is along the direction of the symmetry axis of the inclined tube; />Is the diameter of the pipeline;
the judgment function of the oil pipe in the shaft during the descending is as follows:
（2）
wherein:judging a function value for the time of descending the oil pipe in the shaft; />Is the wellbore gas flow rate.
In the above embodiment, the shale gas horizontal well oil pipe descending time-machine judging function is obtained by establishing the following steps:
as shown in fig. 1, the force of the liquid film was analyzed. The analysis liquid film is mainly subject to the gravity of the liquid filmFriction force (dynamic force) of gas-liquid interface/>Friction force (resistance) between tube wall and liquid film>And pressure difference before and after liquid film +.>。
Force balance analysis is performed on the Z axis, as shown in the following formula:
（7）
a. and (3) carrying out liquid film stress balance analysis, and calculating the dynamic friction force between the pipe wall and the liquid film by adopting a local resistance calculation formula, wherein the dynamic friction force is shown in the following formula:
（8）
b. and (3) carrying out stress balance analysis on the gas core, wherein the gas-liquid interface is greatly different and is fluid, and local resistance calculation is adopted, so that the method is shown in the following formula:
（9）
c. calculating the front-back pressure difference of a liquid film in a shaft, wherein the front-back pressure difference is shown as the following formula:
（10）
simultaneous formulas (7) - (10) give the following formulas:
（11）
in the formula (11), the parameters to be calculated are、/>、/>、/>、/>、/>。
a. Flow velocity calculation
In general, wellhead data is easy to obtain, but the critical carrier flow rate is calculated only by considering the maximum critical flow rate in the shaft, so that similarity criterion calculation is adopted, and the gas flow rate and the liquid flow rate in the shaft are converted to the wellhead by using the euler number of the pressure similarity criterion, and the following formula is adopted:
（12）
wherein:is Euler number; />Is the pressure difference; />Is the density; />Is the flow rate.
（13）
（14）
b. Liquid film gravity calculation
For inclined tubes, the liquid film is no longer uniformly distributed along the circumference of the tube, but rather is angularly dependent. According to the application, the liquid film thickness in the inclined tube increases with the angle, increases and decreases, and reaches the maximum at 45 degrees, as shown in figure 2, and the liquid carrying difficulty is the maximum.
The liquid holdup of the vertical section and the inclined section is calculated by the following formula:
（15）
（16）
wherein:is the liquid holdup of the vertical section; />Liquid holdup for the inclined section; />And->Are angle correction terms.
When the liquid film falls back in the inclined section, the liquid holding phase difference of the vertical section is not large, and the liquid holding phase of the inclined section is corrected by calculating the liquid holding phase of the vertical pipe, and the liquid holding phase of the inclined section of the shaft is shown as follows:
（17）
and (3) taking the gravity of the air core and the liquid film into consideration to obtain a liquid film gravity calculation formula shown in a formula (6).
c. Friction coefficient and void fraction calculation
The flow pattern distribution in the shale gas well cylinder is mainly annular flow, when the annular flow direction is in a slug flow transition, liquid accumulation starts in the well cylinder, and an oil pipe needs to be lowered, so that only annular flow is considered.
Referring to the annular flow friction coefficient calculation formula, the gas-liquid interface friction coefficient can be obtained from the friction coefficient between the pipe wall and the liquid film, so that the friction coefficient calculation formula between the gas core and the liquid film shown in the formula (4) is obtained.
The liquid holdup is proportional to the liquid film thickness, and the liquid film thickness of the inclined tube is calculated by the following formula:
（18）
wherein:is the thickness of the liquid film of the inclined tube; />Is the thickness of the liquid film of the vertical tube.
The research shows that the relation shown in the formula (3) exists between the void ratio in the circulation and the ratio of the liquid film thickness to the pipeline diameter, and the void ratio can be calculated and obtained through the formula (3).
d. Liquid film inversion
From equation (7), whenDuring the process, the liquid film and the liquid drops in the shaft drop back, the internal flow type in the shaft is changed, and the following formula is shown:
（19）
simultaneous formulas (3), (4), (6), (11) - (14), (19), wherein>>/>The critical carrier flow rate is calculated as follows:
（20）
as can be seen from equation (20), the tubing run-in time is a polynomial inequality, and the relevant parameters are mainly fluid flow rate, gas flow rate and wellbore pressure, which can be obtained by converting the parameters of gas production, liquid production and wellhead pressure, which are easier to obtain in engineering applications. And (3) a wellhead oil pipe descending time judging function which is used for judging the wellhead oil pipe descending time is arranged on the left side of the formula (20).
In order to obtain the in-shaft oil pipe descending time judging function, the liquid film of the shaft is reversed at the position where the shaft is difficult to carry liquid, and the liquid flow rate is 0, so that the in-shaft oil pipe descending time judging function shown in the formula (2) can be deduced.
In a specific embodiment, the void fractionThe calculation is performed by the following formula:
（3）
wherein:is the thickness of the liquid film.
In a specific embodiment, the coefficient of friction between the gas core and the liquid filmThe calculation is performed by the following formula:
（4）
in a specific embodiment, the wellbore airflow rateThe calculation is performed by the following formula:
（5）
wherein:is a deviation factor; />Is the temperature; />Is the gas production rate; />Is the cross-sectional area of the wellbore.
In a specific embodiment, the liquid film is gravityThe calculation is performed by the following formula:
（6）
in a specific embodiment, the pressure drop is calculated by:
（21）
wherein:is the two-phase mixed density; />Is the angle between the pipeline/shaft and the horizontal direction; />Is friction coefficient; />Is the apparent velocity of the gas-liquid mixture.
It should be noted that the calculation formulas of void fraction, friction coefficient, gas phase apparent flow rate, and pressure drop in the above embodiments are only preferred calculation formulas of the present application, and other methods capable of obtaining the parameters in the prior art may be applied to the present application.
S2: and collecting basic parameters of a target well about the shale gas horizontal well oil pipe descending time judging function.
S3: and calculating a shale gas horizontal well oil pipe descending time judging function value of the target well according to the basic parameters, and judging that the moment corresponding to the corresponding basic parameters is the oil pipe descending time of the target well when the shale gas horizontal well oil pipe descending time judging function value is smaller than 0.
In the above embodiment, whenWhen the well bore is shown in figure 1, the gas well liquid film stably flows. When->At this point, the wellbore begins to fall back as shown in FIG. 3, with insufficient liquid carrying capacity (lighter colored indication flowing downward and darker colored indication flowing upward).
According to the wellhead oil pipe descending time judging function, wellhead parameters (wellhead pressure, gas production and liquid production) are drawn into a wellhead oil pipe descending time judging chart, and the result is shown in fig. 4. In fig. 4, the position below the curve is the well head oil pipe descending time; when (when)When the liquid carrying capacity of the shaft is high, the liquid can be stably carried, and the shaft is positioned above the curved surface, as shown by the data points with lighter colors. When->When the liquid carrying capacity of the shaft is insufficient, the liquid can not be carried stably, and the shaft is positioned below the curved surface, as shown by the darker data points.
According to the well bore oil pipe descending time judging function, a well bore oil pipe descending time judging chart is drawn, and the result is shown in fig. 5.
In a specific embodiment, the smaller the value of the oil pipe descending judgment function of the shale gas horizontal well is, the better the corresponding oil pipe descending judgment function is.
In a specific embodiment, taking a shale gas horizontal well as an example, the method for judging the oil pipe descending time of the shale gas horizontal well is adopted to judge the oil pipe descending time. In this example, the casing size was 139.7mm and the tubing size was 51mm. When the oil pipe is put down, the wellhead pressure is 6.82MPa, the gas production rate is 12 square meters, and the water production rate is 5 square meters.
Assume that in a wellbore，/>，/>，/>；/>；/>，/>Inclined section liquid holdup->And the pressure in the well bore is calculated by adopting an empirical pressure drop model shown in a formula (21), so that the pressure in the well bore is 10.78MPa.
According to the known parameters, the following formula is obtained by combining the wellhead oil pipe descending time-machine judging function:
（22）
according to the known parameters, the following formula is obtained by combining the time-machine judging function of the oil pipe in the shaft of the application:
（23）
in this embodiment, the calculation results of the partial wellhead parameters and the corresponding wellhead oil pipe down time judging function values are shown in fig. 6 and table 1:
table 1 results of partial wellhead parameter and corresponding function value calculations
From fig. 6 and table 1, it can be seen that when the comprehensive influence of wellhead pressure, gas production and liquid production results in that the oil pipe descending time machine judging function is smaller than 0, the oil pipe descending time can be judged, so that the method has persuasion to simply judge wellhead pressure, and the operability is stronger when judging at the wellhead.
In summary, the application can accurately judge the oil pipe descending time of the production well through the easily obtained production well parameters such as gas production, liquid production, wellhead pressure and the like. Compared with the prior art, the application has obvious progress.
The present application is not limited to the above-mentioned embodiments, but is intended to be limited to the following embodiments, and any modifications, equivalents and modifications can be made to the above-mentioned embodiments without departing from the scope of the application.
Claims (8)
1. The method for judging the time when the shale gas horizontal well oil pipe is put down is characterized by comprising the following steps of:
s1: establishing a shale gas horizontal well oil pipe descending time judging function, wherein the shale gas horizontal well oil pipe descending time judging function is a wellhead oil pipe descending time judging function or a shaft oil pipe descending time judging function;
s2: collecting basic parameters of a target well about a time-machine judging function of the shale gas horizontal well oil pipe descending;
s3: and calculating a shale gas horizontal well oil pipe descending time judging function value of the target well according to the basic parameters, and judging that the moment corresponding to the corresponding basic parameters is the oil pipe descending time of the target well when the shale gas horizontal well oil pipe descending time judging function value is smaller than 0.
2. The method for determining the time when the shale gas horizontal well is oil-pipe-down according to claim 1, wherein in step S1, when the time when the shale gas horizontal well is oil-pipe-down determination function is established, it is assumed that a liquid film of the well bore is attached to the pipe wall.
3. The method for determining the time spent in oil pipe descending of the shale gas horizontal well according to claim 2, wherein in step S1, the time spent in oil pipe descending of the wellhead is determined as:
（1）
wherein:judging a function value for a wellhead oil pipe descending time; />Is the friction coefficient between the liquid film and the pipe wall; />Is the liquid phase density of the shaft; />Is void fraction; />Is the friction coefficient between the gas core and the liquid film; />Is the gas phase density of the shaft; />Is wellbore pressure; />Is the gas phase density of the wellhead; />Is wellhead pressure; />Is the wellhead airflow rate; />Is the wellhead fluid flow rate; />Is the wellhead liquid phase density; />Is the gravity of the liquid film; />Inclination angle for the wellbore from the vertical axis; />Is along the direction of the symmetry axis of the inclined tube; />Is the diameter of the pipeline;
the judgment function of the oil pipe in the shaft during the descending is as follows:
（2）
wherein:judging a function value for the time of descending the oil pipe in the shaft; />Is the wellbore gas flow rate.
4. The method for determining the time for tubing down a shale gas horizontal well of claim 3, wherein the void fractionThe calculation is performed by the following formula:
（3）
wherein:is the thickness of the liquid film.
5. The method for determining the time when shale gas horizontal well oil pipe is lowered according to claim 3, wherein the friction coefficient between the gas core and the liquid filmThe calculation is performed by the following formula:
（4）
wherein:is the thickness of the liquid film.
6. The method of determining the timing of the shale gas horizontal well tubing run in of claim 3, wherein the wellbore gas flow rateThe calculation is performed by the following formula:
（5）
wherein:is a deviation factor; />Is the temperature; />Is the gas production rate; />Is the cross-sectional area of the wellbore.
7. The method for determining the time when shale gas horizontal well oil pipe is lowered in machine according to claim 3, wherein the liquid film gravity forceThe calculation is performed by the following formula:
（6）
wherein:liquid holdup for the inclined section; />Gravitational acceleration.
8. The method for determining the time for oil pipe descending of a shale gas horizontal well according to any one of claims 1 to 7, wherein in step S3, the smaller the value of the time determination function for oil pipe descending of the shale gas horizontal well is, the better the corresponding time for oil pipe descending is.
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