CN115142836B - Formation gas yield monitoring method, storage medium and equipment - Google Patents
Formation gas yield monitoring method, storage medium and equipment Download PDFInfo
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- E21B47/00—Survey of boreholes or wells
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- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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Abstract
The invention discloses a method for monitoring the yield of formation gas, a storage medium and equipment, which are applied to a gas drilling process and are used for acquiring the total hydrocarbon content of the formation gas; constructing a full hydrocarbon content model based on the mass of formation gas and the mass of injected gas in the gas drilling process; obtaining a stratum gas yield monitoring model based on the full hydrocarbon content model and introducing a gas state equation; the total hydrocarbon content, wellhead pressure, injected gas molar mass, injected gas compression factor, wellhead temperature, bottom hole pressure, stratum gas molar mass, stratum gas compression factor and bottom hole temperature are input into a stratum gas yield monitoring model, so that stratum gas yield is determined. According to the method, a gas state equation is introduced, the compressible characteristic of gas is fully considered, and a stratum gas yield monitoring model capable of carrying out dynamic analysis is constructed, so that stratum gas yield can be efficiently and accurately monitored, reliability of stratum gas yield monitoring is improved, and powerful guarantee is provided for subsequent efficient drilling.
Description
Technical Field
The invention relates to the technical field of exploration, in particular to a method for monitoring formation gas yield, a storage medium and equipment.
Background
With the development of oil and gas exploration and development, the geological environment encountered by petroleum engineering drilling is more and more complex, particularly a tight gas reservoir with low porosity and low permeability, a series of problems are faced by a conventional drilling mode, serious lost circulation is easy to occur, the mechanical drilling speed is low, the drilling period is long, the drilling operation cost is greatly increased, and the oil and gas exploration and development process and benefit are seriously influenced. The nitrogen drilling is used as one of gas drilling, inert gas nitrogen is used as a circulating medium, on one hand, the mechanical drilling speed can be greatly improved, on the other hand, the circulating medium density is low, the pressure formed on a well hole is low, and the pressure difference between the well hole and a stratum can be effectively reduced, so that the malignant leakage of drilling fluid is reduced, the reservoir is prevented from being damaged by the drilling fluid, and the oil and gas yield of the stratum is improved.
When nitrogen is used as a circulating medium to drill a gas well, the formation gas yield needs to be mastered in time, the next construction measure is judged according to the formation gas yield, the current monitoring method for the formation gas yield while drilling in nitrogen drilling is relatively simple, a sensor is arranged on a sand discharge pipeline of a wellhead, and the formation gas yield is estimated according to the gas component concentration and the experience of on-site drilling personnel by measuring the component concentration of returned gas. The monitoring method lacks theories, the estimated result has larger deviation from the actual production of the formation gas, and the subsequent drilling operation cannot be guided correctly. For example, if the formation gas production estimate is too large, it may mislead the on-site driller to make a decision to finish drilling ahead, losing a portion of the reservoir capacity; if the formation gas yield estimated value is too low, the on-site drilling personnel can be misled to give out a continuous drilling instruction, and the well control risk is increased.
Disclosure of Invention
The invention aims to solve the technical problems that: the method for monitoring the formation gas yield in the prior art has the problems of large deviation and low reliability.
In order to solve the technical problems, the invention provides a method for monitoring the formation gas yield, a storage medium and equipment.
In a first aspect of the present invention, there is provided a method of monitoring formation gas production, the method of monitoring formation gas production being applied to a gas drilling process, comprising:
Acquiring the total hydrocarbon content of formation gas;
Constructing a full hydrocarbon content model based on the mass of the formation gas and the mass of the injected gas during the gas drilling process;
obtaining a stratum gas yield monitoring model according to a gas state equation corrected based on the compression factor and the total hydrocarbon content model;
Inputting the total hydrocarbon content, wellhead pressure, injected gas molar mass, injected gas compression factor, wellhead temperature, bottom hole pressure, formation gas molar mass, formation gas compression factor, bottom hole temperature and injected gas volume into the formation gas yield monitoring model;
And determining the formation gas yield based on the formation gas yield monitoring model.
In some embodiments, constructing a full hydrocarbon content model based on the mass of the formation gas and the mass of injected gas during the gas drilling process includes:
The full hydrocarbon content model is constructed from the density and production of the formation gas and the density and volume of the injection gas using the following expression:
Where ρ 1 represents the density of the formation gas, v 1 represents the formation gas production, ρ 2 represents the density of the injected gas, v 2 represents the volume of the injected gas, and x represents the total hydrocarbon content of the formation gas.
In some embodiments, the deriving the formation gas production monitoring model from the compression factor-based modified gas state equation and the full hydrocarbon content model comprises:
determining the relationship between the density of the formation gas and the bottom hole pressure, the formation gas molar mass, the formation gas compression factor and the bottom hole temperature according to the gas state equation;
Determining a relationship between the density of the injected gas and the wellhead pressure, the injected gas molar mass, the injected gas compression factor, and the bottom hole temperature according to the gas state equation;
And obtaining the formation gas yield monitoring model based on the total hydrocarbon content model according to the relation between the density of the formation gas and the bottom hole pressure, the formation gas molar mass, the formation gas compression factor and the bottom hole temperature and the relation between the density of the injection gas and the wellhead pressure, the injection gas molar mass, the injection gas compression factor and the bottom hole temperature.
In some embodiments, the formation gas production monitoring model comprises:
Wherein P Well bottom represents bottom hole pressure, M 1 represents formation gas molar mass, Z 1 represents formation gas compression factor, T Well bottom represents bottom hole temperature, P Wellhead represents wellhead pressure, M 2 represents injection gas molar mass, Z 2 represents injection gas compression factor, T Wellhead represents wellhead temperature, and R represents gas constant.
In some embodiments, the bottom hole temperature is determined from a sum of the wellhead temperature and a temperature gradient.
In some embodiments, the bottom hole pressure is determined by:
Determining an average temperature according to the wellhead temperature and the bottom hole temperature;
Determining a target average compression factor: setting an average compression factor predicted value; determining a predicted value of the bottom hole pressure based on the relation between the wellhead pressure and the bottom hole pressure according to the average compression factor predicted value and the wellhead pressure; determining a predicted average pressure according to the predicted values of the wellhead pressure and the bottom hole pressure; determining an average compression factor table lookup value based on a table lookup method according to the average temperature and the predicted average pressure; when the error between the average compression factor table lookup value and the average compression factor predicted value is smaller than a preset value, determining the average compression factor table lookup value as the target average compression factor;
And determining the bottom hole pressure based on the relation between the wellhead pressure and the bottom hole pressure according to the average temperature, the target average compression factor and the wellhead pressure.
In some embodiments, the relationship of the wellhead pressure to the bottom hole pressure comprises:
where M represents the molar mass, D represents the bottom hole depth, Z avg represents the target average compression factor, and T avg represents the average temperature.
In some embodiments, the method of monitoring formation gas production further comprises: and when the formation gas yield is monitored to exceed the preset yield, well control risk early warning is carried out.
In a second aspect of the present invention, there is provided a storage medium having stored therein a computer program which, when executed by a processor, enables the method for monitoring formation gas production as described in any one of the above.
In a third aspect of the present invention, there is provided an apparatus comprising a memory and a processor, the memory having stored therein a computer program, the processor being capable of implementing a method of monitoring formation gas production as described in any one of the preceding claims when the computer program is executed.
One or more embodiments of the above-described solution may have the following advantages or benefits compared to the prior art:
The method is applied to a gas drilling process, and the total hydrocarbon content of the formation gas is obtained; constructing a full hydrocarbon content model based on the mass of formation gas and the mass of injected gas in the gas drilling process; obtaining a stratum gas yield monitoring model based on the full hydrocarbon content model and introducing a gas state equation corrected based on a compression factor; the formation gas yield is determined based on the formation gas yield monitoring model by inputting the total hydrocarbon content, wellhead pressure, injected gas molar mass, injected gas compression factor, wellhead temperature, bottom hole pressure, formation gas molar mass, formation gas compression factor and bottom hole temperature into the formation gas yield monitoring model. According to the method, a gas state equation is introduced, the compressible characteristic of gas is fully considered, and a stratum gas yield monitoring model capable of carrying out dynamic analysis is constructed, so that stratum gas yield can be efficiently and accurately monitored, reliability of stratum gas yield monitoring is improved, and powerful guarantee is provided for subsequent efficient drilling.
Drawings
The scope of the present disclosure may be better understood by reading the following detailed description of exemplary embodiments in conjunction with the accompanying drawings. The drawings included herein are:
FIG. 1 shows a schematic flow chart of a method for monitoring formation gas production according to an embodiment of the present invention;
FIG. 2 is a schematic diagram of a formation gas production monitoring system for a nitrogen drilling while drilling formation according to an embodiment of the present invention;
FIG. 3 is a schematic flow chart of a method for monitoring formation gas production according to another embodiment of the present invention;
FIG. 4 is a schematic flow chart of a method for determining bottom hole pressure according to an embodiment of the present invention;
FIG. 5 is a schematic flow chart of a method for monitoring formation gas production according to a third embodiment of the present invention;
FIG. 6 shows a schematic diagram of formation gas production of a target well 1 measured by a method for monitoring formation gas production provided in accordance with an embodiment of the present invention;
FIG. 7 is a schematic diagram of formation gas production from a target well 2 measured by a method for monitoring formation gas production according to an embodiment of the present invention;
fig. 8 shows a schematic diagram of an apparatus structure according to an embodiment of the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, the following detailed description of the implementation method of the present invention will be given with reference to the accompanying drawings and examples, by which the technical means are applied to solve the technical problems, and the implementation process for achieving the technical effects can be fully understood and implemented accordingly.
With the development of oil and gas exploration and development, the geological environment encountered by petroleum engineering drilling is more and more complex, particularly a tight gas reservoir with low porosity and low permeability, a series of problems are faced by a conventional drilling mode, serious lost circulation is easy to occur, the mechanical drilling speed is low, the drilling period is long, the drilling operation cost is greatly increased, and the oil and gas exploration and development process and benefit are seriously influenced. The nitrogen drilling is used as one of gas drilling, inert gas nitrogen is used as a circulating medium, on one hand, the mechanical drilling speed can be greatly improved, on the other hand, the circulating medium density is low, the pressure formed on a well hole is low, and the pressure difference between the well hole and a stratum can be effectively reduced, so that the malignant leakage of drilling fluid is reduced, the reservoir is prevented from being damaged by the drilling fluid, and the oil and gas yield of the stratum is improved.
When nitrogen is used as a circulating medium to drill a gas well, the formation gas yield needs to be mastered in time, the next construction measure is judged according to the formation gas yield, the current monitoring method for the formation gas yield while drilling in nitrogen drilling is relatively simple, a sensor is arranged on a sand discharge pipeline of a wellhead, and the formation gas yield is estimated according to the gas component concentration and the experience of on-site drilling personnel by measuring the component concentration of returned gas. The monitoring method lacks theories, the estimated result has larger deviation from the actual production of the formation gas, and the subsequent drilling operation cannot be guided correctly. For example, if the formation gas production estimate is too large, it may mislead the on-site driller to make a decision to finish drilling ahead, losing a portion of the reservoir capacity; if the formation gas yield estimated value is too low, the on-site drilling personnel can be misled to give out a continuous drilling instruction, and the well control risk is increased.
In view of the above, the present invention provides a method for monitoring formation gas production, which is applied to a gas drilling process by obtaining the total hydrocarbon content of formation gas; constructing a full hydrocarbon content model based on the mass of formation gas and the mass of injected gas in the gas drilling process; obtaining a stratum gas yield monitoring model based on the full hydrocarbon content model and introducing a gas state equation; the formation gas yield is determined based on the formation gas yield monitoring model by inputting the total hydrocarbon content, wellhead pressure, injected gas molar mass, injected gas compression factor, wellhead temperature, bottom hole pressure, formation gas molar mass, formation gas compression factor and bottom hole temperature into the formation gas yield monitoring model. According to the method, a gas state equation is introduced, the compressible characteristic of gas is fully considered, and a stratum gas yield monitoring model capable of carrying out dynamic analysis is constructed, so that stratum gas yield can be efficiently and accurately monitored, reliability of stratum gas yield monitoring is improved, and powerful guarantee is provided for subsequent efficient drilling.
It should be noted that the method for monitoring the formation gas yield provided by the embodiment of the invention can be suitable for monitoring the formation gas yield while drilling in gas drilling.
Example 1
Referring to fig. 1, fig. 1 shows a schematic flow chart of a method for monitoring formation gas production, which includes:
Step S101: the total hydrocarbon content of the formation gas is obtained.
Step S102: and constructing a full hydrocarbon content model based on the mass of the formation gas and the mass of the injected gas in the gas drilling process.
Step S103: and obtaining a stratum gas yield monitoring model according to the gas state equation and the full hydrocarbon content model.
Step S104: the total hydrocarbon content, wellhead pressure, injected gas molar mass, injected gas compression factor, wellhead temperature, bottom hole pressure, formation gas molar mass, formation gas compression factor, bottom hole temperature and injected gas volume are input into a formation gas production monitoring model.
Step S105: and determining the formation gas yield based on the formation gas yield monitoring model.
In the embodiment of the present invention, step S101 may specifically be: the total hydrocarbon content is collected using a total hydrocarbon concentration sensor, where the total hydrocarbon content may be expressed as x.
Based on the characteristic of constant gas mass at different pressures and temperatures, a model of the total hydrocarbon content is constructed from the mass of the formation gas and the mass of the injected gas in step S102.
In some embodiments, step S102 may be specifically configured to construct a full hydrocarbon content model according to the density and yield of formation gas and the density and volume of injected gas using the following expression:
Where ρ 1 represents the density of the formation gas, v 1 represents the formation gas production, ρ 2 represents the density of the injected gas, v 2 represents the volume of the injected gas, and x represents the total hydrocarbon content of the formation gas.
In some embodiments, the gas drilling may be nitrogen drilling, the injected gas is nitrogen, and the nitrogen is used as a circulation medium, so that leakage of drilling fluid can be effectively reduced, damage to the reservoir from the drilling fluid is avoided, and further accuracy and reliability of monitoring formation gas production are improved.
In an embodiment of the present invention, the gas state equation corrected based on the compression factor may be expressed as:
pv= ZnRT, where P represents gas pressure, V represents volume, Z represents compression factor, n represents amount of substance of gas, R represents gas constant, and T represents temperature.
In addition, the gas state equation can also be expressed as:
Pm=zρrt, where P represents gas pressure, M represents molar mass, ρ represents gas density.
In the embodiment of the present invention, step S103 may obtain a formation gas yield monitoring model according to the gas state equation corrected based on the compression factor and the full hydrocarbon content model:
Wherein P Well bottom represents bottom hole pressure, M 1 represents formation gas molar mass, Z 1 represents formation gas compression factor, T Well bottom represents bottom hole temperature, P Wellhead represents wellhead pressure, M 2 represents injection gas molar mass, Z 2 represents injection gas compression factor, T Wellhead represents wellhead temperature, and R represents gas constant.
When the formation gas yield monitoring model is obtained, the key factor of volume change under different temperatures and pressures is fully considered by introducing a gas state equation corrected based on a compression factor, so that the formation gas yield monitoring model which is more in line with actual conditions, accurate and reliable is obtained.
In some embodiments, step S104 may specifically be to input the total hydrocarbon content, the injected gas molar mass, the formation gas molar mass, the wellhead pressure, the wellhead temperature acquired in real time, and the bottom hole temperature determined in advance based on the wellhead temperature, the bottom hole pressure determined based on the wellhead pressure and the wellhead temperature, the formation gas compression factor determined based on the bottom hole pressure and the bottom hole temperature, and the injected gas compression factor determined based on the wellhead temperature and the wellhead pressure into the obtained formation gas yield monitoring model, so as to determine the formation gas yield based on the formation gas yield monitoring model.
It should be noted that, in the embodiment of the present invention, the wellhead pressure in the formation gas production monitoring model may be replaced by wellhead pressure, and the bottom hole pressure may be replaced by bottom hole pressure. Accordingly, the wellhead pressure and bottom hole pressure may also be input into the formation gas production monitoring model instead in step S104. The wellhead pressure can be collected by a pressure sensor arranged at the wellhead, and the bottom hole pressure can be determined based on the relationship between the bottom hole pressure and the wellhead pressure.
The method for monitoring the formation gas yield provided by the embodiment of the invention can be applied to a gas drilling process, and the total hydrocarbon content of the formation gas is obtained; constructing a full hydrocarbon content model based on the mass of formation gas and the mass of injected gas in the gas drilling process; obtaining a stratum gas yield monitoring model based on the full hydrocarbon content model and introducing a gas state equation corrected based on a compression factor; the formation gas yield is determined based on the formation gas yield monitoring model by inputting the total hydrocarbon content, wellhead pressure, injected gas molar mass, injected gas compression factor, wellhead temperature, bottom hole pressure, formation gas molar mass, formation gas compression factor and bottom hole temperature into the formation gas yield monitoring model. According to the method, a gas state equation is introduced, the compressible characteristic of gas is fully considered, and a stratum gas yield monitoring model capable of carrying out dynamic analysis is constructed, so that stratum gas yield can be efficiently and accurately monitored, reliability of stratum gas yield monitoring is improved, and powerful guarantee is provided for subsequent efficient drilling.
In the second embodiment of the present invention, the method for monitoring formation gas production provided by the present invention is used to monitor formation gas production while drilling in a nitrogen drilling well, and specifically please refer to the following description.
Example two
Referring to fig. 2, fig. 2 is a schematic diagram of a formation gas production monitoring system for a formation while drilling in nitrogen drilling according to an embodiment of the present invention.
The system for monitoring the formation gas yield of the formation while drilling through nitrogen drilling can comprise an air compressor unit, a membrane nitrogen generator unit and a pressurizing unit which are arranged at one end of a vertical pipe, wherein the other end of the vertical pipe is connected with a wellhead, and a temperature sensor and a pressure or pressure sensor are further arranged on the vertical pipe of the wellhead.
After the pressurized nitrogen is prepared by the air compressor unit, the membrane nitrogen making unit and the pressurizing unit, the nitrogen passes through the vertical pipe and the drill rod to reach the bottom of the well, and when the drill bit drills into a reservoir, the pressure in the well bore is higher than that of the stratum due to the density of the nitrogen, and stratum gas produced by the stratum enters the annular space and returns to the ground together with the nitrogen.
After the formation gas returns to the ground together with the nitrogen, the formation gas passes through a wellhead sand discharge pipeline, and a full hydrocarbon concentration sensor is arranged on the wellhead sand discharge pipeline and can be used for collecting the full hydrocarbon content in the gas returned from the bottom of the well. Because nitrogen is hydrocarbon free, the total hydrocarbon content is only related to formation gas.
The formation gas yield monitoring system based on the formation while drilling of the nitrogen drilling is used for monitoring the formation gas yield, firstly, an air compressor unit, a membrane nitrogen making unit and a pressurizing unit can be used for preparing pressurized nitrogen, and the nitrogen is used as injection gas to be introduced from a wellhead. Referring to fig. 3, fig. 3 shows a schematic flow chart of a method for monitoring formation gas production according to another embodiment of the present invention, which includes:
Step S201: and collecting wellhead pressure, wellhead temperature and injection amount of nitrogen.
Step S202: and determining the bottom hole temperature according to the wellhead temperature and the temperature gradient.
Step S203: and determining the bottom-hole pressure based on the relation between the wellhead pressure and the bottom-hole pressure according to the wellhead temperature, the bottom-hole temperature, the target average compression factor and the wellhead pressure.
Step S204: and obtaining the total hydrocarbon content of the wellhead.
Step S205: based on the mass of the formation gas and the mass of the nitrogen gas, a full hydrocarbon content model is constructed.
Step S206: and obtaining a stratum gas yield monitoring model according to the gas state equation corrected based on the compression factor and the full hydrocarbon content model.
Step S207: the total hydrocarbon content, wellhead pressure, nitrogen molar mass, nitrogen compression factor, wellhead temperature, bottom hole pressure, formation gas molar mass, formation gas compression factor, bottom hole temperature and injection amount of nitrogen are input into a formation gas yield monitoring model.
Step S208: and determining the formation gas yield based on the formation gas yield monitoring model.
In the embodiment of the present invention, step S201 may specifically be to acquire the wellhead temperature in real time by using a temperature sensor disposed at the wellhead, acquire the wellhead pressure in real time by using a pressure sensor disposed at the wellhead, and acquire the injection amount of nitrogen in real time.
In step S202, determining the bottom hole temperature from the wellhead temperature and the temperature gradient may be expressed as:
T Well bottom ＝T Wellhead +gG, wherein T Wellhead represents the wellhead temperature, T Well bottom represents the bottom hole temperature, and g G represents the temperature gradient.
In the embodiment of the present invention, referring to fig. 4, fig. 4 shows a schematic flow chart of a method for determining bottom hole pressure according to the embodiment of the present invention, and step S203 may specifically be:
step S2031: the average temperature is determined based on the wellhead temperature and the bottom hole temperature.
Step S2032: and setting an average compression factor predicted value, and determining a predicted value of bottom hole pressure based on the relation between the wellhead pressure and the bottom hole pressure according to the average compression factor predicted value and the wellhead pressure.
Step S2033: and determining the predicted average pressure according to the predicted values of the wellhead pressure and the bottom hole pressure.
Step S2034: and determining an average compression factor table lookup value based on a table lookup method according to the average temperature and the predicted average pressure.
Step S2035: when the error between the average compression factor table lookup value and the average compression factor predicted value is smaller than a preset value, determining the average compression factor table lookup value as a target average compression factor; when the error between the table lookup value of the average compression factor and the predicted value of the average compression factor is greater than or equal to the preset value, the step S2032 is returned.
Step S2036: and determining the bottom hole pressure based on the relation between the wellhead pressure and the bottom hole pressure according to the average temperature, the target average compression factor and the wellhead pressure.
Wherein the average temperature T avg can be determined by the following expression:
The average compression factor predictor may be expressed as The relationship of wellhead pressure to bottom hole pressure can be expressed as:
Wherein P Wellhead represents wellhead pressure, P Well bottom represents bottom hole pressure, M represents molar mass, D represents bottom hole depth, and the predicted value is based on average compression factor And wellhead pressure, and based on the relationship between wellhead pressure and bottom hole pressure, a predicted value P Well bottom 0 of bottom hole pressure can be determined.
Based on the determined predicted value P Well bottom 0 of bottom hole pressure and wellhead pressure, a predicted average pressure may be determined using the following expression
The temperature and the pressure are in one-to-one correspondence with the compression factors, and the average temperature T avg and the predicted average pressure are determined according to a pre-established relation table of the temperature, the pressure and the compression factorsThe average temperature T avg and the predicted average pressure can be determined by a table look-up modeCorresponding average compression factor table look-up value
In the embodiment of the invention, the average compression factor table look-up value can also be judgedAnd average compression factor predictorWhether the error is less than a preset value. When the average compression factor looks up the tableAnd average compression factor predictorWhen the error of (a) is smaller than the preset value, the average compression factor is checked into a tableThe target average compression factor is determined. When the average compression factor looks up the tableAnd average compression factor predictorIf the error of (a) is greater than or equal to the preset value, the step S2032 may be returned to reset the average compression factor predicted value until the average compression factor table look-up valueAnd average compression factor predictorThe error of (2) is less than a preset value.
By averaging the determined average temperature T avg and the target average compression factorAnd wellhead pressure P Wellhead into the expression: The bottom hole pressure may be determined.
Step S204 may specifically be to obtain the full hydrocarbon content of the wellhead using a full hydrocarbon concentration sensor.
In the embodiment of the present invention, step S205 may specifically construct a full hydrocarbon content model according to the density and yield of formation gas and the density and volume of injected gas by using the following expression:
Where ρ 1 represents the density of the formation gas, v 1 represents the formation gas production, ρ 2 represents the density of the injected gas, v 2 represents the volume of the injected gas, and x represents the total hydrocarbon content of the formation gas.
In an embodiment of the present invention, the gas state equation corrected based on the compression factor may be expressed as:
pv= ZnRT, where P represents gas pressure, V represents volume, Z represents compression factor, n represents amount of substance of gas, R represents gas constant, and T represents temperature.
In addition, the gas state equation can also be expressed as:
Pm=zρrt, where P represents gas pressure, M represents molar mass, ρ represents gas density.
In the embodiment of the present invention, step S206 may obtain a formation gas yield monitoring model according to the gas state equation corrected based on the compression factor and the full hydrocarbon content model:
Wherein P Well bottom represents bottom hole pressure, M 1 represents formation gas molar mass, Z 1 represents formation gas compression factor, T Well bottom represents bottom hole temperature, P Wellhead represents wellhead pressure, M 2 represents injection gas molar mass, Z 2 represents injection gas compression factor, T Wellhead represents wellhead temperature, and R represents gas constant.
When the formation gas yield monitoring model is obtained, the key factor of volume change under different temperatures and pressures is fully considered by introducing a gas state equation corrected based on a compression factor, so that the formation gas yield monitoring model which is more in line with actual conditions, accurate and reliable is obtained.
In some embodiments, step S207 may specifically be to input the nitrogen molar mass, the formation gas molar mass, the total hydrocarbon content, the wellhead pressure, the wellhead temperature acquired in real time, and the bottom hole temperature determined in advance based on the wellhead temperature, the bottom hole pressure determined based on the wellhead pressure and the wellhead temperature, the formation gas compression factor determined based on the bottom hole pressure and the bottom hole temperature, and the nitrogen compression factor determined based on the wellhead temperature and the wellhead pressure into the obtained formation gas yield monitoring model to determine the formation gas yield based on the formation gas yield monitoring model.
The formation gas compression factor can be obtained by a table look-up mode based on the corresponding relation between the pre-established bottom hole pressure and bottom hole temperature and the formation gas compression factor; similarly, the nitrogen compression factor can also be obtained by a table look-up method based on the pre-established corresponding relationship between wellhead temperature and wellhead pressure and the nitrogen compression factor.
It should be noted that, in the embodiment of the present invention, the wellhead pressure in the formation gas production monitoring model may be replaced by wellhead pressure, and the bottom hole pressure may be replaced by bottom hole pressure. Accordingly, the wellhead pressure and bottom hole pressure may also be input into the formation gas production monitoring model instead in step S207. The wellhead pressure can be collected by a pressure sensor arranged at the wellhead, and the bottom hole pressure can be determined based on the relationship between the bottom hole pressure and the wellhead pressure.
The method for monitoring the formation gas yield provided by the embodiment of the invention can be applied to monitoring the formation gas yield of the formation while drilling during nitrogen drilling, and a full hydrocarbon content model is constructed based on the quality of the formation gas and the quality of injected gas in the gas drilling process; obtaining a stratum gas yield monitoring model based on the full hydrocarbon content model and introducing a gas state equation corrected based on a compression factor; and inputting the nitrogen molar mass, the formation gas molar mass, the total hydrocarbon content, the wellhead pressure and the wellhead temperature acquired in real time, and the bottom hole temperature determined in advance based on the wellhead temperature, the bottom hole pressure determined based on the wellhead pressure and the wellhead temperature, the formation gas compression factor determined based on the bottom hole pressure and the bottom hole temperature, and the nitrogen compression factor determined based on the wellhead temperature and the wellhead pressure into an obtained formation gas yield monitoring model, and determining the formation gas yield based on the formation gas yield monitoring model. According to the method, a gas state equation is introduced, the compressible characteristic of gas is fully considered, and a stratum gas yield monitoring model capable of carrying out dynamic analysis is constructed, so that stratum gas yield can be efficiently and accurately monitored, reliability of stratum gas yield monitoring is improved, and powerful guarantee is provided for subsequent efficient drilling.
In the embodiment of the invention, the formation gas yield is determined by applying the formation gas yield monitoring method provided by the invention, and when the formation gas yield is monitored to exceed the preset yield, well control risk early warning can be performed, and the method is specifically described in the third embodiment below.
Example III
It should be noted that, the third embodiment may be implemented based on the first embodiment or the second embodiment, and the third embodiment of the present invention will be described based on the second embodiment.
Referring to fig. 5, fig. 5 shows a schematic flow chart of a method for monitoring formation gas production according to a third embodiment of the present invention, which includes:
step S301: and collecting wellhead pressure, wellhead temperature and injection amount of nitrogen.
Step S302: and determining the bottom hole temperature according to the wellhead temperature and the temperature gradient.
Step S303: and determining the bottom-hole pressure based on the relation between the wellhead pressure and the bottom-hole pressure according to the wellhead temperature, the bottom-hole temperature, the target average compression factor and the wellhead pressure.
Step S304: and obtaining the total hydrocarbon content of the wellhead.
Step S305: based on the mass of the formation gas and the mass of the nitrogen gas, a full hydrocarbon content model is constructed.
Step S306: and obtaining a stratum gas yield monitoring model according to the gas state equation corrected based on the compression factor and the full hydrocarbon content model.
Step S307: the total hydrocarbon content, wellhead pressure, nitrogen molar mass, nitrogen compression factor, wellhead temperature, bottom hole pressure, formation gas molar mass, formation gas compression factor, bottom hole temperature and injection amount of nitrogen are input into a formation gas yield monitoring model.
Step S308: and determining the formation gas yield based on the formation gas yield monitoring model.
Step S309: and when the formation gas yield is monitored to exceed the preset yield, well control risk early warning is carried out.
In the embodiment of the present invention, step S301 may specifically be to acquire the wellhead temperature in real time by using a temperature sensor disposed at the wellhead, acquire the wellhead pressure in real time by using a pressure sensor disposed at the wellhead, and acquire the injection amount of nitrogen in real time.
In step S302, determining the bottom hole temperature from the wellhead temperature and the temperature gradient may be expressed as:
T Well bottom ＝T Wellhead +gG, wherein T Wellhead represents the wellhead temperature, T Well bottom represents the bottom hole temperature, and g G represents the temperature gradient.
In the embodiment of the present invention, step S303 may specifically be: determining an average temperature according to the wellhead temperature and the bottom hole temperature; setting an average compression factor predicted value, and determining a predicted value of bottom hole pressure based on the relation between the wellhead pressure and the bottom hole pressure according to the average compression factor predicted value and the wellhead pressure; determining a predicted average pressure according to predicted values of wellhead pressure and bottom hole pressure; determining an average compression factor table lookup value based on a table lookup method according to the average temperature and the predicted average pressure; when the error between the average compression factor table lookup value and the average compression factor predicted value is smaller than a preset value, determining the average compression factor table lookup value as a target average compression factor; and determining the bottom hole pressure based on the relation between the wellhead pressure and the bottom hole pressure according to the average temperature, the target average compression factor and the wellhead pressure.
When the error between the average compression factor table lookup value and the average compression factor predicted value is greater than or equal to the preset value, resetting the average compression factor predicted value, and determining the average compression factor table lookup value corresponding to the resetting average compression factor predicted value based on the resetting average compression factor predicted value until the error between the average compression factor table lookup value and the average compression factor predicted value corresponding to the resetting average compression factor table lookup value is smaller than the preset value.
Wherein the average temperature T avg can be determined by the following expression:
The average compression factor predictor may be expressed as The relationship of wellhead pressure to bottom hole pressure can be expressed as: Wherein P Wellhead represents wellhead pressure, P Well bottom represents bottom hole pressure, M represents molar mass, D represents bottom hole depth, and the predicted value is based on average compression factor And wellhead pressure, based on the relationship between wellhead pressure and bottom pressure, the predicted value of bottom pressure can be determined
Predicted value based on determined bottom hole pressureAnd wellhead pressure, the predicted average pressure Pavg 0 may be determined using the following expression:
The temperature and the pressure are in one-to-one correspondence with the compression factors, and the average temperature T avg and the predicted average pressure are determined according to a pre-established relation table of the temperature, the pressure and the compression factors The average temperature T avg and the predicted average pressure can be determined by a table look-up modeCorresponding average compression factor table look-up value
In the embodiment of the invention, the average compression factor table look-up value can also be judgedAnd average compression factor predictorWhether the error is less than a preset value. When the average compression factor looks up the tableAnd average compression factor predictorWhen the error of (a) is smaller than the preset value, the average compression factor is checked into a tableThe target average compression factor is determined.
By averaging the determined average temperature T avg and the target average compression factorAnd wellhead pressure P Wellhead into the expression: The bottom hole pressure may be determined.
Step S304 may specifically be to obtain the full hydrocarbon content of the wellhead using a full hydrocarbon concentration sensor.
In the embodiment of the present invention, step S305 may specifically construct a full hydrocarbon content model according to the density and yield of formation gas and the density and volume of injected gas by using the following expression:
Where ρ 1 represents the density of the formation gas, v 1 represents the formation gas production, ρ 2 represents the density of the injected gas, v 2 represents the volume of the injected gas, and x represents the total hydrocarbon content of the formation gas.
In an embodiment of the present invention, the gas state equation corrected based on the compression factor may be expressed as:
pv= ZnRT, where P represents gas pressure, V represents volume, Z represents compression factor, n represents amount of substance of gas, R represents gas constant, and T represents temperature.
In addition, the gas state equation can also be expressed as:
Pm=zρrt, where P represents gas pressure, M represents molar mass, ρ represents gas density.
In the embodiment of the present invention, step S306 may obtain a formation gas yield monitoring model according to the gas state equation corrected based on the compression factor and the full hydrocarbon content model:
Wherein P Well bottom represents bottom hole pressure, M 1 represents formation gas molar mass, Z 1 represents formation gas compression factor, T Well bottom represents bottom hole temperature, P Wellhead represents wellhead pressure, M 2 represents injection gas molar mass, Z 2 represents injection gas compression factor, T Wellhead represents wellhead temperature, and R represents gas constant.
When the formation gas yield monitoring model is obtained, the key factor of volume change under different temperatures and pressures is fully considered by introducing a gas state equation corrected based on a compression factor, so that the formation gas yield monitoring model which is more in line with actual conditions, accurate and reliable is obtained.
In some embodiments, step S307 may specifically be to input the nitrogen molar mass, the formation gas molar mass, the total hydrocarbon content, the wellhead pressure, the wellhead temperature acquired in real time, and the bottom hole temperature determined in advance based on the wellhead temperature, the bottom hole pressure determined based on the wellhead pressure and the wellhead temperature, the formation gas compression factor determined based on the bottom hole pressure and the bottom hole temperature, and the nitrogen compression factor determined based on the wellhead temperature and the wellhead pressure into the obtained formation gas yield monitoring model to determine the formation gas yield based on the formation gas yield monitoring model.
The formation gas compression factor can be obtained by a table look-up mode based on the corresponding relation between the pre-established bottom hole pressure and bottom hole temperature and the formation gas compression factor; similarly, the nitrogen compression factor can also be obtained by a table look-up method based on the pre-established corresponding relationship between wellhead temperature and wellhead pressure and the nitrogen compression factor.
It should be noted that, in the embodiment of the present invention, the wellhead pressure in the formation gas production monitoring model may be replaced by wellhead pressure, and the bottom hole pressure may be replaced by bottom hole pressure. Accordingly, the wellhead pressure and bottom hole pressure may also be input into the formation gas production monitoring model instead in step S307. The wellhead pressure can be collected by a pressure sensor arranged at the wellhead, and the bottom hole pressure can be determined based on the relationship between the bottom hole pressure and the wellhead pressure.
After the formation gas yield is determined, the real-time determined gas yield can be compared with the preset yield, wherein the preset yield can be set according to the actual conditions of the formation, when the formation gas yield is monitored to exceed the preset yield, well control risk early warning is carried out, drilling is recommended to be stopped, and a drill pipe well completion gas production mode is adopted. When the formation gas yield is monitored to be smaller than the preset yield, the well control risk is lower, drilling can be continued until the designed well depth is reached, and then the well is completed.
The method for monitoring the formation gas yield provided by the embodiment of the invention constructs a full hydrocarbon content model based on the mass of formation gas and the mass of injected gas in the gas drilling process; obtaining a stratum gas yield monitoring model based on the full hydrocarbon content model and introducing a gas state equation corrected based on a compression factor; and inputting the nitrogen molar mass, the formation gas molar mass, the total hydrocarbon content, the wellhead pressure and the wellhead temperature acquired in real time, and the bottom hole temperature determined in advance based on the wellhead temperature, the bottom hole pressure determined based on the wellhead pressure and the wellhead temperature, the formation gas compression factor determined based on the bottom hole pressure and the bottom hole temperature, and the nitrogen compression factor determined based on the wellhead temperature and the wellhead pressure into an obtained formation gas yield monitoring model, and determining the formation gas yield based on the formation gas yield monitoring model. And when the formation gas yield is monitored to exceed the preset yield, well control risk early warning can be performed. According to the method, a gas state equation is introduced, the compressible characteristic of gas is fully considered, and a stratum gas yield monitoring model capable of carrying out dynamic analysis is constructed, so that stratum gas yield can be efficiently and accurately monitored, reliability of stratum gas yield monitoring is improved, and powerful guarantee is provided for subsequent efficient drilling. In addition, through carrying out well control risk early warning, powerful guarantee is provided for safe drilling.
DETAILED DESCRIPTION OF EMBODIMENT (S) OF INVENTION
Referring to fig. 6, fig. 6 shows a schematic diagram of formation gas production of the target well 1 measured by the method for monitoring formation gas production according to the embodiment of the present invention.
And (3) carrying out nitrogen drilling aiming at the target well 1, installing a pressure sensor and a temperature sensor on a vertical pipe arranged on the target well 1, and recording dynamic parameters such as wellhead pressure, wellhead temperature, nitrogen volume and the like in the nitrogen drilling process. Determining the bottom hole temperature according to the wellhead temperature and the temperature gradient; determining an average temperature according to the wellhead temperature and the bottom hole temperature; setting an average compression factor predicted value, and determining a predicted value of bottom hole pressure based on the relation between the wellhead pressure and the bottom hole pressure according to the average compression factor predicted value and the wellhead pressure; determining a predicted average pressure according to predicted values of wellhead pressure and bottom hole pressure; determining an average compression factor table lookup value based on a table lookup method according to the average temperature and the predicted average pressure; when the error between the average compression factor table lookup value and the average compression factor predicted value is smaller than a preset value, determining the average compression factor table lookup value as a target average compression factor; and determining the bottom hole pressure based on the relation between the wellhead pressure and the bottom hole pressure according to the average temperature, the target average compression factor and the wellhead pressure.
The preset value can be set according to actual needs, and when the error between the average compression factor table lookup value and the average compression factor predicted value is greater than or equal to the preset value, the average compression factor predicted value can be reset until the error between the average compression factor table lookup value and the average compression factor predicted value is smaller than the preset value.
A total hydrocarbon concentration sensor may also be installed on the corresponding sand removal line of the target well 1 to record the total hydrocarbon concentration of the return gas.
And finally, inputting the obtained total hydrocarbon content, wellhead pressure, wellhead temperature, nitrogen molar mass, formation gas molar mass, and the bottom hole temperature determined in advance based on the wellhead temperature, the bottom hole pressure determined based on the wellhead pressure and the wellhead temperature, the formation gas compression factor determined based on the bottom hole pressure and the bottom hole temperature, and the nitrogen compression factor determined based on the wellhead temperature and the wellhead pressure into a formation gas yield monitoring model below, so as to determine the yield of formation gas:
in addition, according to the formation gas yield monitored in real time, whether the formation gas yield exceeds the preset yield can be judged, as a specific example, the preset yield can be set to be 5×10 5m3/d, the formation gas yield monitored by the target well 1 is smaller than the preset yield, the well control risk is lower, drilling to the designed well depth can be suggested based on the monitoring result, and well completion is completed by casing.
Referring to fig. 7, fig. 7 shows a schematic diagram of formation gas yield of the target well 2 measured by the method for monitoring formation gas yield according to the embodiment of the present invention.
And (3) carrying out nitrogen drilling aiming at the target well 2, installing a pressure sensor and a temperature sensor on a vertical pipe arranged on the target well 2, and recording dynamic parameters such as wellhead pressure, wellhead temperature, nitrogen volume and the like in the nitrogen drilling process. Determining the bottom hole temperature according to the wellhead temperature and the temperature gradient; determining an average temperature according to the wellhead temperature and the bottom hole temperature; setting an average compression factor predicted value, and determining a predicted value of bottom hole pressure based on the relation between the wellhead pressure and the bottom hole pressure according to the average compression factor predicted value and the wellhead pressure; determining a predicted average pressure according to predicted values of wellhead pressure and bottom hole pressure; determining an average compression factor table lookup value based on a table lookup method according to the average temperature and the predicted average pressure; when the error between the average compression factor table lookup value and the average compression factor predicted value is smaller than a preset value, determining the average compression factor table lookup value as a target average compression factor; and determining the bottom hole pressure based on the relation between the wellhead pressure and the bottom hole pressure according to the average temperature, the target average compression factor and the wellhead pressure.
The preset value can be set according to actual needs, and when the error between the average compression factor table lookup value and the average compression factor predicted value is greater than or equal to the preset value, the average compression factor predicted value can be reset until the error between the average compression factor table lookup value and the average compression factor predicted value is smaller than the preset value.
A total hydrocarbon concentration sensor may also be installed on the corresponding sand removal line of the target well 2 to record the total hydrocarbon concentration of the return gas.
And finally, inputting the obtained total hydrocarbon content, wellhead pressure, wellhead temperature, nitrogen molar mass, formation gas molar mass, and the bottom hole temperature determined in advance based on the wellhead temperature, the bottom hole pressure determined based on the wellhead pressure and the wellhead temperature, the formation gas compression factor determined based on the bottom hole pressure and the bottom hole temperature, and the nitrogen compression factor determined based on the wellhead temperature and the wellhead pressure into a formation gas yield monitoring model below, so as to determine the yield of formation gas:
in addition, according to the formation gas yield monitored in real time, whether the formation gas yield exceeds the preset yield can be judged, as a specific example, the preset yield can be set to be 5×10 5m3/d, as shown in fig. 7, the formation gas yield monitored by the target well 2 suddenly increases after 600min, the formation gas yield exceeds the preset yield, the wellhead risk increases, and at the moment, well control risk early warning can be performed to remind that drilling is stopped, and a drill pipe well completion gas production mode is adopted.
Example IV
In another aspect of the present invention, a storage medium is provided, where a computer program is stored, where the computer program, when executed by a processor, can implement the method for monitoring formation gas production according to any one of the foregoing embodiments one to three.
The processes, functions, methods and/or software described above may be recorded, stored or fixed in one or more computer-readable storage media that include program instructions that are to be computer-implemented to cause a processor to execute the program instructions. The storage media may also include program instructions, data files, data structures, and the like, alone or in combination. The storage media or program instructions may be specially designed and construed by those skilled in the computer software arts, or it may be of the kind well known and available to those having skill in the computer software arts. Examples of the computer readable medium include: magnetic media such as hard disks, floppy disks, and magnetic tape; optical media such as CDROM discs and DVDs; magneto-optical media, such as optical disks; and hardware devices, specifically configured to store and execute program instructions, such as read-only memory (ROM), random Access Memory (RAM), flash memory, and the like. Examples of program instructions include both machine code, such as produced by a compiler, and files containing higher level code that may be executed by the computer using an interpreter. The described hardware devices may be configured to act as one or more software modules to perform the operations and methods described above, and vice versa. In addition, the computer readable storage medium may be distributed among networked computer systems, and the computer readable code or program instructions may be stored and executed in a decentralized manner.
The storage medium provided by the embodiment of the invention can realize the same beneficial effects as any one of the first to third embodiments, and can obtain the total hydrocarbon content of formation gas by being applied to the gas drilling process; constructing a full hydrocarbon content model based on the mass of formation gas and the mass of injected gas in the gas drilling process; obtaining a stratum gas yield monitoring model based on the full hydrocarbon content model and introducing a gas state equation; the formation gas yield is determined based on the formation gas yield monitoring model by inputting the total hydrocarbon content, wellhead pressure, injected gas molar mass, injected gas compression factor, wellhead temperature, bottom hole pressure, formation gas molar mass, formation gas compression factor and bottom hole temperature into the formation gas yield monitoring model. According to the method, a gas state equation is introduced, the compressible characteristic of gas is fully considered, and a stratum gas yield monitoring model capable of carrying out dynamic analysis is constructed, so that stratum gas yield can be efficiently and accurately monitored, reliability of stratum gas yield monitoring is improved, and powerful guarantee is provided for subsequent efficient drilling.
Example five
In another aspect of the present invention, an apparatus is provided, and referring to fig. 8, fig. 8 shows a schematic structural diagram of an apparatus provided by an embodiment of the present invention.
The apparatus may comprise a processor 80 and a memory 81, wherein the memory 81 stores a computer program, and wherein the processor 80 is capable of implementing the formation gas production monitoring method according to any one of the first to third embodiments when executing the computer program stored in the memory 81.
It should be noted that the device may include one or more processors 80 and a memory 81, and the processor 80 and the memory 81 may be connected by a bus or other means. The memory 81 is a type of nonvolatile computer-readable storage medium that can be used to store nonvolatile software programs, nonvolatile computer-executable programs, and modules. The processor 80 performs various functional applications of the apparatus and data processing, i.e. implements the method of flow direction determination of an invading rock mass as described above, by running non-volatile software programs, instructions and modules stored in a memory.
By applying the equipment provided by the embodiment of the invention, the same beneficial effects as those of any one of the first to third embodiments can be realized, and the total hydrocarbon content of the formation gas can be obtained by applying the equipment to the gas drilling process; constructing a full hydrocarbon content model based on the mass of formation gas and the mass of injected gas in the gas drilling process; obtaining a stratum gas yield monitoring model based on the full hydrocarbon content model and introducing a gas state equation; the formation gas yield is determined based on the formation gas yield monitoring model by inputting the total hydrocarbon content, wellhead pressure, injected gas molar mass, injected gas compression factor, wellhead temperature, bottom hole pressure, formation gas molar mass, formation gas compression factor and bottom hole temperature into the formation gas yield monitoring model. According to the method, a gas state equation is introduced, the compressible characteristic of gas is fully considered, and a stratum gas yield monitoring model capable of carrying out dynamic analysis is constructed, so that stratum gas yield can be efficiently and accurately monitored, reliability of stratum gas yield monitoring is improved, and powerful guarantee is provided for subsequent efficient drilling.
Although the embodiments of the present invention are disclosed above, the embodiments are only used for the convenience of understanding the present invention, and are not intended to limit the present invention. Any person skilled in the art can make any modification and variation in form and detail without departing from the spirit and scope of the present disclosure, but the scope of the present disclosure is still subject to the scope of the present disclosure as defined by the appended claims.
Claims (7)
1. A method for monitoring formation gas production, wherein the method for monitoring formation gas production is applied to a gas drilling process and comprises the following steps:
Acquiring the total hydrocarbon content of formation gas;
Constructing a full hydrocarbon content model based on the mass of the formation gas and the mass of the injected gas during the gas drilling process;
obtaining a stratum gas yield monitoring model according to a gas state equation corrected based on the compression factor and the total hydrocarbon content model;
Inputting the total hydrocarbon content, wellhead pressure, injected gas molar mass, injected gas compression factor, wellhead temperature, bottom hole pressure, formation gas molar mass, formation gas compression factor, bottom hole temperature and injected gas volume into the formation gas yield monitoring model;
determining the formation gas yield based on the formation gas yield monitoring model;
wherein constructing a full hydrocarbon content model based on the mass of the formation gas and the mass of injected gas during the gas drilling process, comprises:
The full hydrocarbon content model is constructed from the density and production of the formation gas and the density and volume of the injection gas using the following expression:
Wherein, the method comprises the steps of, wherein, Representing the density of the formation gas,Representing the production of formation gas,Representing the density of the injected gas,Representing the volume of injected gas, x representing the total hydrocarbon content of the formation gas;
Wherein the formation gas yield monitoring model is obtained according to the gas state equation corrected based on the compression factor and the full hydrocarbon content model, and comprises the following steps:
determining the relationship between the density of the formation gas and the bottom hole pressure, the formation gas molar mass, the formation gas compression factor and the bottom hole temperature according to the gas state equation;
Determining a relationship between the density of the injected gas and the wellhead pressure, the injected gas molar mass, the injected gas compression factor, and the bottom hole temperature according to the gas state equation;
Obtaining the formation gas yield monitoring model based on the total hydrocarbon content model according to the relation between the density of the formation gas and the bottom hole pressure, the formation gas molar mass, the formation gas compression factor and the bottom hole temperature and the relation between the density of the injection gas and the wellhead pressure, the injection gas molar mass, the injection gas compression factor and the bottom hole temperature;
wherein the formation gas production monitoring model comprises:
Wherein P Well bottom represents bottom hole pressure, M 1 represents formation gas molar mass, Z 1 represents formation gas compression factor, T Well bottom represents bottom hole temperature, P Wellhead represents wellhead pressure, M 2 represents injection gas molar mass, Z 2 represents injection gas compression factor, T Wellhead represents wellhead temperature, and R represents gas constant.
2. A method of monitoring formation gas production as claimed in claim 1 wherein the bottom hole temperature is determined from the sum of the wellhead temperature and the temperature gradient.
3. A method of monitoring formation gas production as claimed in claim 2, wherein the bottom hole pressure is determined by:
Determining an average temperature according to the wellhead temperature and the bottom hole temperature;
Determining a target average compression factor: setting an average compression factor predicted value; determining a predicted value of the bottom hole pressure based on the relation between the wellhead pressure and the bottom hole pressure according to the average compression factor predicted value and the wellhead pressure; determining a predicted average pressure according to the predicted values of the wellhead pressure and the bottom hole pressure; determining an average compression factor table lookup value based on a table lookup method according to the average temperature and the predicted average pressure; when the error between the average compression factor table lookup value and the average compression factor predicted value is smaller than a preset value, determining the average compression factor table lookup value as the target average compression factor;
And determining the bottom hole pressure based on the relation between the wellhead pressure and the bottom hole pressure according to the average temperature, the target average compression factor and the wellhead pressure.
4. A method of monitoring formation gas production as claimed in claim 3, wherein the relationship of the wellhead pressure to the bottom hole pressure comprises:
Where M represents the molar mass, D represents the bottom hole depth, Z avg represents the target average compression factor, and T avg represents the average temperature.
5. A method of monitoring formation gas production as claimed in claim 1, further comprising: and when the formation gas yield is monitored to exceed the preset yield, well control risk early warning is carried out.
6. A storage medium having stored therein a computer program which, when executed by a processor, is capable of carrying out the formation gas production monitoring method of any one of claims 1 to 5.
7. An apparatus comprising a memory and a processor, the memory having stored therein a computer program, the processor being capable of implementing a method of monitoring formation gas production as claimed in any one of claims 1 to 5 when the computer program is executed.
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| RU2486337C1 (en) * | 2012-08-24 | 2013-06-27 | Открытое акционерное общество "Татнефть" им. В.Д. Шашина | Method for determination of stratum productivity in process of well drilling |
| CN108643887B (en) * | 2018-04-26 | 2020-02-21 | 中国石油大学(华东) | Control method and control device for drilling operation |
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| CN111119864B (en) * | 2018-11-01 | 2023-05-05 | 中国石油化工股份有限公司 | Overflow monitoring method and system based on gas invasion pressure characteristics |
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| CN108150161A (en) * | 2017-12-27 | 2018-06-12 | 中国石油化工股份有限公司江汉油田分公司勘探开发研究院 | Shale gassiness evaluation square law device |
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