CN111255434B

CN111255434B - Well testing method, device and computer storage medium for gas well

Info

Publication number: CN111255434B
Application number: CN201811452621.8A
Authority: CN
Inventors: 邓惠; 彭先; 冯曦; 朱斌; 姚宏宇; 鲁杰; 杨泽恩; 张岩; 鄢友军; 朱讯
Original assignee: Petrochina Co Ltd
Current assignee: Petrochina Co Ltd
Priority date: 2018-11-30
Filing date: 2018-11-30
Publication date: 2023-05-26
Anticipated expiration: 2038-11-30
Also published as: CN111255434A

Abstract

The invention discloses a well testing method of a gas well, and belongs to the field of gas well exploitation. The method comprises the following steps: acquiring the oil test yield and the wellhead oil pressure of a gas well in the oil test opening process, and acquiring the wellhead oil pressure of the gas well in the oil test closing process; determining the bottom hole flow pressure of the gas well according to the wellhead oil pressure of the gas well in the process of opening the test oil; determining the stratum static pressure of the gas well according to the wellhead oil pressure of the gas well in the well closing process of the test oil; determining the production range of the gas well according to the oil testing yield of the gas well in the oil testing well opening process, the bottom hole flow pressure and the stratum static pressure of the gas well; and (5) testing the gas well according to the yield range of the gas well. According to the invention, the data obtained in the oil testing process of the gas well is used as the basis to predict the yield range of the gas well, so that the well testing of the gas well can be carried out after the oil testing of the gas well is completed and before the gas well is put into production, the production time of the gas well is not required to be occupied in the well testing process of the gas well, and the normal production of the gas well is not influenced.

Description

Well testing method, device and computer storage medium for gas well

Technical Field

The invention relates to the field of gas well exploitation, in particular to a well testing method, a well testing device and a computer storage medium of a gas well.

Background

In order to evaluate the productivity of a gas well, it is often necessary to test the well. Well testing is the determination of the production capacity of a gas well by measuring parameters such as the production and pressure of the gas well over a period of time and analyzing these parameters.

Currently, methods for testing gas wells generally include a back pressure test method and an isochronal test method. The back pressure well testing method comprises the following steps: determining a yield range of a well test according to the yield of the gas well after the gas well is put into production, selecting a plurality of yields from the yield range, respectively and stably producing the gas well according to the yields, recording data such as bottom hole flow pressure, used duration and the like in the production process, drawing a well test curve according to the recorded data, deducing a productivity equation of the gas well according to the well test curve, and determining the productivity of the gas well according to the productivity equation. The isochronous well testing method comprises the following steps: determining a production range of a well test according to production data of a gas well after the gas well is put into production, selecting a plurality of production from the production range, respectively producing the gas well with the plurality of production for equal time, then carrying out stable production with a smaller production for longer time, recording data such as bottom hole flow pressure and used time in the whole production process, finally drawing a well test curve according to the recorded data, deducing a production capacity equation of the gas well according to the well test curve, and determining the production capacity of the gas well according to the production capacity equation.

However, in the well test method, the production range of the well test needs to be determined based on the production of the gas well after the production of the gas well, so the well test method needs to be performed after the production of the gas well, and the normal production of the gas well is greatly affected because the time required for the well test process is often longer.

Disclosure of Invention

The embodiment of the invention provides a well testing method, a well testing device and a computer storage medium for a gas well, which can solve the problem that the well testing method in the related art can not be executed until the gas well is put into production. The technical scheme is as follows:

in a first aspect, there is provided a method of testing a gas well, the method comprising:

acquiring oil test yield and wellhead oil pressure of a gas well in the process of opening oil test, and acquiring wellhead oil pressure of the gas well in the process of closing the oil test;

determining the bottom hole flow pressure of the gas well according to the wellhead oil pressure of the gas well in the oil test well opening process;

determining the stratum static pressure of the gas well according to the wellhead oil pressure of the gas well in the well closing process of the test oil;

determining the production range of the gas well according to the oil test yield of the gas well in the oil test well opening process, the bottom hole flow pressure and the stratum static pressure of the gas well;

And testing the gas well according to the production range of the gas well.

Optionally, the determining the bottom hole flow pressure of the gas well according to the wellhead oil pressure of the gas well in the process of opening the test oil comprises the following steps:

acquiring the distance between the wellhead of the gas well and the gas layer where the gas well is located;

multiplying the distance between the wellhead and the gas layer by a preset flow pressure gradient to obtain a first pressure increment;

and adding the stable value of the wellhead oil pressure of the gas well in the well opening process of the oil test to the first pressure increment to obtain the bottom hole flow pressure of the gas well.

Optionally, the determining the formation static pressure of the gas well according to the wellhead oil pressure of the gas well in the well closing process of oil test comprises the following steps:

multiplying the distance between the wellhead and the gas layer by a preset static pressure gradient to obtain a second pressure increment;

and adding the maximum value of wellhead oil pressure of the gas well in the well closing process of oil test to the second pressure increment to obtain the stratum static pressure of the gas well.

Optionally, the determining the production range of the gas well according to the test oil yield of the gas well during the test oil opening process, the bottom hole flow pressure and the formation static pressure of the gas well comprises the following steps:

Determining a first unimpeded flow rate of the gas well according to the oil test yield of the gas well in the oil test well opening process, the bottom hole flow pressure and the stratum static pressure of the gas well;

multiplying the first choked flow of the gas well by a first ratio to obtain a first value; multiplying the first choked flow of the gas well by a second ratio to obtain a second value, wherein the second ratio is greater than the first ratio;

a production range having a minimum value of the first value and a maximum value of the second value is determined as the production range of the gas well.

Optionally, the testing the gas well according to the production range of the gas well comprises:

selecting a production from a production range of the gas well as a first production;

carrying out well opening production on the gas well within a first preset time period with the first yield, and recording the bottom hole flow pressure of the gas well within the first preset time period in the well opening production process;

closing the gas well within a second preset time period, and recording the bottom hole flow pressure of the gas well within the second preset time period in the closing process;

acquiring logging data of the gas well;

acquiring a well test model of the gas well and reservoir parameters of a gas layer where the gas well is located according to the bottom hole flow pressure of the gas well in the first preset time period, the bottom hole flow pressure of the gas well in the second preset time period and logging data of the gas well;

A second unobstructed flow rate of the gas well is determined based on the production range of the gas well, the well test model, and the reservoir parameters.

Optionally, the determining the second unobstructed flow rate of the gas well according to the production range of the gas well, the well test model and the reservoir parameters includes:

selecting n yields from the yield range of the gas well as n second yields, wherein n is an integer greater than or equal to 2;

determining turbulence coefficients in a binomial productivity equation based on the n second yields and the formation static pressure included in the reservoir parameters;

obtaining the minimum yield and the maximum yield of the n second yields;

determining a yield range having a minimum value of the minimum yield and a maximum value of the maximum yield as a target yield range;

selecting one yield from the target yield range as a third yield;

determining a laminar flow coefficient in the binomial productivity equation according to the third yield, the well test model, the turbulence coefficient, and the formation static pressure included in the reservoir parameter;

and determining a second unobstructed flow rate of the gas well through the binomial capacity equation according to the turbulence coefficient, the laminar flow coefficient and the formation static pressure included in the reservoir parameter.

Optionally, the determining turbulence coefficient in the binomial productivity equation according to the n second productivities and the formation static pressure included in the reservoir parameters includes:

taking an ith second yield of the n second yields as a target yield, wherein i is greater than or equal to 1 and less than or equal to n;

carrying out ith open-hole production on the gas well within a third preset time period according to the target production, and determining the instant bottom-hole flow pressure from the ith-1 open-hole production to the ith open-hole production as a first bottom-hole flow pressure corresponding to the ith-1 second production when i is not 1;

when the ith well opening production is completed, judging whether i is equal to n; if i is equal to n, determining the instant bottom hole flow pressure when the ith well opening production is completed as the first bottom hole flow pressure corresponding to the ith second production; if i is not equal to n, let i = i +1, return to said step of taking the i-th yield of said n second yields as the target yield;

determining n coordinate points corresponding to the n second yields one by one according to the n second yields, the first bottom hole flow pressure corresponding to each of the n second yields and the stratum static pressure included in the reservoir parameters;

Performing curve fitting on the n coordinate points to obtain a first curve;

the slope of the first curve is determined as a turbulence coefficient in a binomial capacity equation.

Optionally, the determining n coordinate points corresponding to the n second yields one-to-one according to the n second yields, the first bottom hole flow pressure corresponding to each of the n second yields, and the formation static pressure included in the reservoir parameter includes:

determining an ith second yield in the n second yields as an abscissa of a coordinate point corresponding to the ith second yield;

and dividing the square of the stratum static pressure included in the reservoir parameter by the square of the first bottom hole flow pressure corresponding to the ith second yield to obtain the ordinate of the coordinate point corresponding to the ith second yield.

Optionally, the determining the laminar flow coefficient in the binomial productivity equation according to the third production, the well test model, the turbulent flow coefficient, and the formation static pressure included in the reservoir parameter includes:

inputting the third yield into the well test model, simulating well production of the gas well with the third yield in a fourth preset time period by the well test model, and outputting simulated bottom hole flow pressure of the gas well in the fourth preset time period;

Determining a target coordinate point according to the third yield, the simulated bottom hole flow pressure output by the well test model and the stratum static pressure included in the reservoir parameters;

determining a curve passing through the target coordinate point and having a slope of the turbulence coefficient as a second curve;

and determining the intercept of the second curve on the horizontal axis as a laminar flow coefficient in the binomial capacity equation.

In a second aspect, there is provided a well testing apparatus for a gas well, the apparatus comprising:

the acquisition module is used for acquiring the oil test yield and the wellhead oil pressure of the gas well in the oil test opening process and acquiring the wellhead oil pressure of the gas well in the oil test closing process;

the first determining module is used for determining the bottom hole flow pressure of the gas well according to the wellhead oil pressure of the gas well in the well opening process of oil test;

the second determining module is used for determining the stratum static pressure of the gas well according to the wellhead oil pressure of the gas well in the well closing process of the test oil;

the third determining module is used for determining the production range of the gas well according to the oil test yield of the gas well in the oil test well opening process, the bottom hole flow pressure and the stratum static pressure of the gas well;

and the well testing module is used for testing the gas well according to the yield range of the gas well.

Optionally, the first determining module includes:

the first acquisition unit is used for acquiring the distance between the wellhead of the gas well and the gas layer where the gas well is located;

the first calculation unit is used for multiplying the distance between the wellhead and the gas layer by a preset flow pressure gradient to obtain a first pressure increment;

and the second calculation unit is used for adding the stable value of the wellhead oil pressure of the gas well in the well opening process of the oil test to the first pressure increment to obtain the bottom hole flow pressure of the gas well.

Optionally, the second determining module includes:

the second acquisition unit is used for acquiring the distance between the wellhead of the gas well and the gas layer where the gas well is located;

the third calculation unit is used for multiplying the distance between the wellhead and the gas layer by a preset static pressure gradient to obtain a second pressure increment;

and the fourth calculation unit is used for adding the maximum value of the wellhead oil pressure of the gas well in the well closing process of the test oil to the second pressure increment to obtain the stratum static pressure of the gas well.

Optionally, the third determining module includes:

a first determining unit, configured to determine a first unobstructed flow rate of the gas well according to a test oil yield of the gas well during a well opening process of a test oil, a bottom hole flow pressure of the gas well, and a formation static pressure;

A fourth calculation unit for multiplying the first choked flow of the gas well by a first ratio to obtain a first value; multiplying the first choked flow of the gas well by a second ratio to obtain a second value, wherein the second ratio is greater than the first ratio;

and a second determining unit for determining a production range with a minimum value of the first value and a maximum value of the second value as the production range of the gas well.

Optionally, the well testing module comprises:

a selection unit for selecting one production from a production range of the gas well as a first production;

the first recording unit is used for carrying out open-hole production on the gas well within a first preset time period with the first yield, and recording the bottom hole flow pressure of the gas well within the first preset time period in the open-hole production process;

the second recording unit is used for closing the gas well within a second preset time period and recording the bottom hole flow pressure of the gas well within the second preset time period in the closing process;

the third acquisition unit is used for acquiring logging data of the gas well;

a fourth obtaining unit, configured to obtain a well test model of the gas well and reservoir parameters of a gas layer where the gas well is located according to a bottom hole flow pressure of the gas well in the first preset duration, a bottom hole flow pressure of the gas well in the second preset duration, and logging data of the gas well;

And a third determining unit for determining a second unobstructed flow rate of the gas well according to the production range of the gas well, the well test model and the reservoir parameters.

Optionally, the third determining unit includes:

a first selection subunit, configured to select n yields from the production range of the gas well, where n is an integer greater than or equal to 2, as n second yields;

a first determination subunit configured to determine turbulence coefficients in a binomial productivity equation according to the n second yields and the formation static pressures included in the reservoir parameters;

an acquisition subunit configured to acquire a minimum yield and a maximum yield among the n second yields;

a second determining subunit configured to determine, as a target yield range, a yield range having a minimum value of the minimum yield and a maximum value of the maximum yield;

a second selecting subunit selecting one yield from the target yield range as a third yield;

a third determination subunit configured to determine a laminar flow coefficient in the binomial productivity equation according to the third yield, the well test model, the turbulence coefficient, and a formation static pressure included in the reservoir parameter;

and a fourth determination subunit configured to determine a second unobstructed flow rate of the gas well according to the turbulence coefficient, the laminar coefficient, and a formation static pressure included in the reservoir parameter through the binomial productivity equation.

Optionally, the first determining subunit is configured to:

performing curve fitting on the n coordinate points to obtain a first curve;

Optionally, the first determining subunit is configured to:

Optionally, the third determining subunit is configured to:

In a third aspect, there is provided a well testing apparatus for a gas well, the apparatus comprising a processor, a memory and program code stored on the memory and executable on the processor, the processor implementing the well testing method of the first aspect described above when executing the program code.

In a fourth aspect, there is provided a computer readable storage medium having instructions stored thereon which when executed by a processor perform the steps of the well testing method of a gas well of the first aspect described above.

The technical scheme provided by the embodiment of the invention at least has the following beneficial effects:

in the embodiment of the invention, the oil test yield and the wellhead oil pressure of the gas well in the oil test well opening process are firstly obtained, the wellhead oil pressure of the gas well in the oil test well closing process is obtained, the bottom hole flowing pressure of the gas well is then determined according to the wellhead oil pressure of the gas well in the oil test well opening process, and the stratum static pressure of the gas well is then determined according to the wellhead oil pressure of the gas well in the oil test well closing process. And determining the yield range of the gas well according to the oil testing yield of the gas well in the oil testing process, the bottom hole flow pressure and the stratum static pressure of the gas well, and finally testing the gas well according to the yield range of the gas well. According to the embodiment of the invention, the data obtained in the oil testing process of the gas well is used as the basis to predict the yield range of the gas well, so that the well testing of the gas well can be carried out after the oil testing of the gas well is completed and before the gas well is put into production, the production time of the gas well is not required to be occupied in the well testing process of the gas well, and the normal production of the gas well is not influenced.

Drawings

In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings required for the description of the embodiments will be briefly described below, and it is apparent that the drawings in the following description are only some embodiments of the present invention, and other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.

FIG. 1 is a flow chart of a method for testing a gas well provided by an embodiment of the present invention;

FIG. 2 is a flow chart of another method of well testing for a gas well provided by an embodiment of the present invention;

FIG. 3 is a flow chart of one operation of determining a second unobstructed flow rate for a gas well provided by an embodiment of the present invention;

FIG. 4 is a schematic structural view of a well testing device for a gas well according to an embodiment of the present invention;

fig. 5 is a schematic structural diagram of another well testing device for a gas well according to an embodiment of the present invention.

Detailed Description

For the purpose of making the objects, technical solutions and advantages of the present invention more apparent, the embodiments of the present invention will be described in further detail with reference to the accompanying drawings.

FIG. 1 is a flow chart of a well testing method for a gas well provided by an embodiment of the invention. Referring to fig. 1, the method includes:

Step 101: obtaining the oil test yield and the wellhead oil pressure of the gas well in the oil test opening process, and obtaining the wellhead oil pressure of the gas well in the oil test closing process.

Step 102: and determining the bottom hole flow pressure of the gas well according to the wellhead oil pressure of the gas well in the oil test well opening process.

Step 103: and determining the stratum static pressure of the gas well according to the wellhead oil pressure of the gas well in the well closing process of the test oil.

Step 104: and determining the production range of the gas well according to the oil testing yield of the gas well in the oil testing process, the bottom hole flow pressure and the stratum static pressure of the gas well.

Step 105: and (5) testing the gas well according to the yield range of the gas well.

Optionally, determining the bottom hole flow pressure of the gas well according to the wellhead oil pressure of the gas well in the oil test well opening process comprises the following steps:

acquiring the distance between the wellhead of a gas well and the gas layer where the gas well is located;

Optionally, determining the formation static pressure of the gas well according to the wellhead oil pressure of the gas well in the well closing process of the test oil comprises:

and adding the maximum value of wellhead oil pressure of the gas well in the well closing process of the test oil to the second pressure increment to obtain the stratum static pressure of the gas well.

Optionally, determining the production range of the gas well according to the oil test production of the gas well during the oil test well opening process, the bottom hole flow pressure and the formation static pressure of the gas well comprises:

determining a first unimpeded flow rate of the gas well according to the oil testing yield of the gas well in the oil testing process, the bottom hole flow pressure and the stratum static pressure of the gas well;

Multiplying a first choked flow of the gas well by a first ratio to obtain a first value; multiplying the first choked flow of the gas well by a second ratio to obtain a second value, wherein the second ratio is greater than the first ratio;

the production range having a minimum value of the first value and a maximum value of the second value is determined as the production range of the gas well.

Optionally, testing the gas well according to the production range of the gas well comprises:

selecting one production from a range of production from a gas well as a first production;

carrying out well opening production on the gas well in a first preset time period with a first yield, and recording the bottom hole flow pressure of the gas well in the first preset time period in the well opening production process;

acquiring logging data of a gas well;

acquiring a well testing model of the gas well and reservoir parameters of a gas layer where the gas well is located according to the bottom hole flow pressure of the gas well in a first preset time period, the bottom hole flow pressure of the gas well in a second preset time period and logging data of the gas well;

Optionally, determining a second unobstructed flow rate for the gas well based on the production range of the gas well, the well test model, and the reservoir parameters, comprising:

determining turbulence coefficients in a binomial productivity equation based on the n second productivities and the formation static pressures included in the reservoir parameters;

obtaining the minimum yield and the maximum yield in the n second yields;

determining a yield range with a minimum value of minimum yield and a maximum value of maximum yield as a target yield range;

selecting one yield from the target yield range as a third yield;

determining a laminar flow coefficient in a binomial productivity equation according to the third yield, the well test model, the turbulence coefficient and the stratum static pressure included in the reservoir parameters;

and determining a second unobstructed flow rate of the gas well by a binomial productivity equation according to the turbulence coefficient, the laminar flow coefficient and the formation static pressure included in the reservoir parameters.

Optionally, determining the turbulence factor in the binomial productivity equation based on the n second productivities and the formation static pressures included in the reservoir parameters comprises:

carrying out ith well opening production on the gas well in a third preset time period with target production, and determining the instant bottom hole flow pressure from the ith well opening production to the ith well opening production as a first bottom hole flow pressure corresponding to the ith second production of 1 when i is not 1;

When the production of the ith open well is completed, judging whether i is equal to n; if i is equal to n, determining the instant bottom-hole flow pressure when the ith open-hole production is completed as the first bottom-hole flow pressure corresponding to the ith second production; if i is not equal to n, let i=i+1, return to the step of taking the i-th yield of the n second yields as the target yield;

determining n coordinate points corresponding to the n second yields one to one according to the n second yields, the first bottom hole flow pressure corresponding to each of the n second yields and the stratum static pressure included in the reservoir parameters;

performing curve fitting on the n coordinate points to obtain a first curve;

the slope of the first curve is determined as a turbulence factor in the binomial capacity equation.

Optionally, determining n coordinate points corresponding to the n second yields one-to-one according to the n second yields, the first bottom hole flow pressure corresponding to each of the n second yields, and the formation static pressure included in the reservoir parameters, including:

dividing the square of the formation static pressure included in the reservoir parameter by the square of the first bottom hole flow pressure corresponding to the ith second yield, and obtaining the ordinate of the coordinate point corresponding to the ith second yield.

Optionally, determining the laminar flow coefficient in the binomial productivity equation based on the third production, the well test model, the turbulence coefficient, and the formation static pressure included in the reservoir parameters comprises:

inputting the third yield into a well test model, simulating well production of the gas well with the third yield in a fourth preset time period by the well test model, and outputting simulated bottom hole flow pressure of the gas well in the fourth preset time period;

determining a curve passing through the target coordinate point and having a slope of a turbulence coefficient as a second curve;

the intercept of the second curve on the horizontal axis is determined as the laminar coefficient in the binomial capacity equation.

All the above optional technical solutions may be combined according to any choice to form an optional embodiment of the present invention, and the embodiments of the present invention will not be described in detail.

Fig. 2 is a flow chart of a well testing method for a gas well according to an embodiment of the present invention. Referring to fig. 2, the method includes:

step 201: obtaining the oil test yield and the wellhead oil pressure of the gas well in the oil test opening process, and obtaining the wellhead oil pressure of the gas well in the oil test closing process.

A gas well is a well drilled from the surface to the gas formation for the production of natural gas. The oil test is to measure the pressure, temperature and other parameters in the gas well and to detect the properties of gas and oil in the gas well to recognize and identify the gas storage layer.

In addition, the test oil yield is a gas well yield obtained during the well opening process when testing the gas well, and the test oil yield may be an average value of the gas well yields obtained during the well opening process of the test oil.

Further, wellhead oil pressure is the residual pressure of natural gas after it rises from the bottom of the well to the wellhead of the well.

Step 202: and determining the bottom hole flow pressure of the gas well according to the wellhead oil pressure of the gas well in the oil test well opening process.

The bottom hole flow pressure is the residual pressure after natural gas flows from the gas layer to the bottom of the gas well.

Specifically, the operations of step 202 may include steps 2021-2023 as follows:

step 2021: and obtaining the distance between the wellhead of the gas well and the gas layer where the gas well is located.

It should be noted that, the gas layer is a stratum storing natural gas, and because the gas layer has a certain thickness, and the middle part of the gas layer is a position where the natural gas storage is mainly concentrated and distributed, and is also a position which can accurately indicate the bottom hole flow pressure of the gas well, when the distance between the wellhead of the gas well and the gas layer where the gas well is located is obtained, the distance between the wellhead of the gas well and the middle part of the gas layer where the gas well is located can be obtained, so that the bottom hole flow pressure of the gas well can be obtained more accurately in the follow-up process.

Step 2022: multiplying the distance between the wellhead and the gas formation by a preset flow pressure gradient to obtain a first pressure increment.

It should be noted that the preset fluid pressure gradient may be preset to indicate a fluid pressure value that increases per unit depth over the distance from the wellhead to the formation in the gas well. In order to obtain the preset flow pressure gradient more quickly, the flow pressure gradient of the adjacent gas well can be used as the preset flow pressure gradient.

Step 2023: and adding the stable value of the wellhead oil pressure of the gas well in the well opening process of the oil test to the first pressure increment to obtain the bottom hole flow pressure of the gas well.

When the well is just opened, the wellhead oil pressure is in an unstable state, the fluctuation range of the wellhead oil pressure is larger, and the unstable wellhead oil pressure cannot accurately indicate the bottom hole flowing pressure of the well, so that the embodiment of the invention adds the stable value of the wellhead oil pressure of the well when the wellhead oil pressure of the well reaches the stability in the oil test opening process to the first pressure added value to obtain the bottom hole flowing pressure of the well, and the accuracy of the determined bottom hole flowing pressure of the well is ensured.

Step 203: and determining the stratum static pressure of the gas well according to the wellhead oil pressure of the gas well in the well closing process of the test oil.

The formation static pressure is a static column pressure at which the gas layer communicates with the surface, and is generally a pressure in the middle of the gas layer when the pressure in the gas well returns to a steady state after the gas well is shut in.

Specifically, the operations of step 203 may include the following steps 2031-2033:

step 2031: and obtaining the distance between the wellhead of the gas well and the gas layer where the gas well is located.

It should be noted that, the operation of step 2031 is similar to that of step 2021, and the description of the embodiment of the invention is omitted.

Step 2032: multiplying the distance between the wellhead and the gas formation by a preset static pressure gradient to obtain a second pressure increment.

It should be noted that the preset static pressure gradient may be preset to indicate a static pressure value that increases per unit depth over the distance from the wellhead to the formation in the gas well. In order to obtain the preset static pressure gradient more quickly, the static pressure gradient of the adjacent gas well can be used as the preset static pressure gradient.

Step 2033: and adding the maximum value of wellhead oil pressure of the gas well in the well closing process of the test oil to the second pressure increment to obtain the stratum static pressure of the gas well.

It should be noted that, since the formation static pressure is the pressure in the middle of the gas layer when the pressure in the gas well is restored to a steady state after the gas well is shut in. The pressure in the gas well usually needs longer time to recover to the stable state after the gas well is shut in, and the time for recovering the pressure in the gas well to the stable state is usually smaller than the time for recovering the pressure in the gas well in the well shutting process of the test oil.

Step 204: and determining the production range of the gas well according to the oil testing yield of the gas well in the oil testing process, the bottom hole flow pressure and the stratum static pressure of the gas well.

The production range of a gas well is a range between the minimum production rate and the maximum production rate of natural gas that can be produced by the gas well.

The method for testing the gas well provided by the embodiment of the invention can be carried out after the completion of the oil testing of the gas well and before the production of the gas well, and under such conditions, the production time of the gas well is not required to be occupied in the well testing process, and the normal production of the gas well is not affected.

Specifically, the operations of step 204 may include the following steps 2041-2043:

step 2041: and determining a first unobstructed flow rate of the gas well according to the oil testing yield of the gas well in the oil testing process, the bottom hole flow pressure and the stratum static pressure of the gas well.

The first unobstructed flow rate is the maximum theoretical yield of the gas well determined according to the oil test yield of the gas well during the oil test opening process, the bottom hole flow pressure of the gas well and the formation static pressure. Because the gas well is not in a production stage during oil testing, the first unobstructed flow rate determined according to the oil testing yield of the gas well in the oil testing process, the bottom hole flow pressure of the gas well and the formation static pressure is estimated unobstructed flow rate, and the estimated unobstructed flow rate can be used for subsequently predicting the yield range of the gas well.

Specifically, the first unobstructed flow rate of the gas well can be determined according to the oil test yield of the gas well in the oil test well opening process, the bottom hole flow pressure of the gas well and the formation static pressure, and the following formula is adopted:

wherein q _AOF For the first unobstructed flow rate, the unit is 10 ⁴ m ³ /d(10 ⁴ Cubic meters per day); q _g For yield, the unit is 10 ⁴ m ³ /d(10 ⁴ Cubic meters per day); p (P) _R Is the static pressure of the stratum, and the unit is MPa; p (P) _wf Is the bottom hole flow pressure in MPa (megapascals).

Step 2042: multiplying a first choked flow of the gas well by a first ratio to obtain a first value; multiplying the first choked flow of the gas well by a second ratio to obtain a second value, the second ratio being greater than the first ratio.

It should be noted that the first ratio and the second ratio may be set in advance, which is not particularly limited in the embodiment of the present invention. For example, the first ratio may be 10% or the like, and the second ratio may be 50% or the like.

Step 2043: the production range having a minimum value of the first value and a maximum value of the second value is determined as the production range of the gas well.

Step 205: and (5) testing the gas well according to the yield range of the gas well.

It should be noted that, well test is to measure parameters such as the production and the pressure of a gas well in a period of time, and analyze these parameters to determine the production capacity of the gas well.

It should be noted that, because the fracturing and acidizing are performed on the gas layer where the gas well is located to increase the gas production channel during the oil testing, and the acid solution used therein may affect the well testing of the gas well, before step 205, the gas well may be opened to drain the acid solution in the gas well to the ground, after the acid solution is drained, the gas well is closed to make the pressure in the gas well reach a stable state, and then step 205 is performed.

Specifically, the operations of step 205 may include the following steps 2051-2056:

step 2051: one production is selected from a range of production for gas wells as a first production.

It is noted that the first production rate may be a randomly selected production rate from a range of production rates from gas wells.

Step 2052: and (3) carrying out well opening production on the gas well in a first preset time period with a first yield, and recording the bottom hole flow pressure of the gas well in the first preset time period in the well opening production process.

It should be noted that the first preset duration may be preset, which is not specifically limited in the embodiment of the present invention. For example, the first preset duration may be 10 hours, 12 hours, etc.

In addition, the recording of the bottom hole flow pressure of the gas well in the first preset time period in the well opening production process can be finished through a testing instrument which is arranged at the bottom of the gas well in advance, the testing instrument can transmit the recorded bottom hole flow pressure and other data to a terminal positioned on the ground in a mode of optical fiber and the like, and the bottom hole flow pressure and other data recorded by the testing instrument can be directly obtained from the terminal.

It is worth noting that a testing instrument for recording data such as pressure, temperature and the like of a gas layer where the gas well is located is usually arranged at the bottom of the gas well before the gas well performs oil testing, and the well testing process of the gas well in the embodiment of the invention can be directly performed after the oil testing is completed, so that the testing instrument arranged at the bottom of the gas well during oil testing can be used for recording data such as bottom hole flowing pressure and the like during oil testing of the gas well, and a new testing instrument does not need to be lowered to the bottom of the gas well again, so that the well testing process is simpler, more convenient and time-saving.

Step 2053: and closing the gas well within a second preset time period, and recording the bottom hole flow pressure of the gas well within the second preset time period in the closing process.

It should be noted that the second preset duration may be preset, and because the gas well needs a longer time to reach the stability of the bottom hole flow pressure after closing the well, the second preset duration may be set longer, for example, the second preset duration may be 5 days, 6 days, and so on.

In addition, the operation of recording the bottom hole flow pressure of the gas well in the second preset time period in the well closing process is similar to the operation of recording the bottom hole flow pressure of the gas well in the first preset time period in the well opening production process, and the embodiment of the invention is not repeated.

Step 2054: logging data of the gas well is obtained.

It should be noted that, in the logging process, the formation parameter is measured after drilling to the designed depth of the well, and the logging data may include the effective thickness of the gas layer, the porosity, the gas saturation, etc.

Step 2055: and acquiring a well testing model of the gas well and reservoir parameters of a gas layer where the gas well is located according to the bottom hole flow pressure of the gas well in the first preset time period, the bottom hole flow pressure of the gas well in the second preset time period and logging data of the gas well.

It should be noted that the well test model of the gas well is a mathematical model for describing the gas layer dynamics of the gas well during the well test process, and the well test model of the gas well can simulate the well production process of the gas well with one production during a period of time, and obtain the bottom hole flow pressure of the gas well during the period of time.

In addition, reservoir parameters are parameters used to evaluate the properties of the reservoir. Reservoir parameters may include formation static pressure, skin factor, permeability and productivity factor, etc.

Specifically, the bottom hole flow pressure of the gas well in a first preset time period, the bottom hole flow pressure of the gas well in a second preset time period and logging data of the gas well can be input into preset well testing software, and the well testing model of the gas well and reservoir parameters of a gas layer where the gas well is located are output through the preset well testing software.

It should be noted that the preset well test software may be preset, which is not particularly limited in the embodiment of the present invention. For example, the pre-set well test software may be PanSystem software, saphir software, or the like.

Step 2056: a second unobstructed flow rate of the gas well is determined based on the production range of the gas well, the well test model, and the reservoir parameters.

The second unobstructed flow rate is the maximum theoretical production of the gas well determined from the production range of the gas well, the well test model, and the reservoir parameters. The second unobstructed flow rate may be used to evaluate the production capacity of the gas well.

The operations of step 2056 may include, among others, the following steps (1) -step (7):

(1) And selecting n yields from the yield range of the gas well as n second yields, wherein n is an integer greater than or equal to 2.

It should be noted that the n second yields may be n yields randomly selected from a range of yields of the gas well, and a difference between two adjacent second yields in the n second yields may be equal.

(2) Turbulence coefficients in the binomial productivity equation are determined based on the n second productivities and the formation static pressures included in the reservoir parameters.

It should be noted that, the binomial productivity equation is an equation for calculating productivity of the gas well, and the binomial productivity equation may be:

Wherein q _g For yield, the unit is 10 ⁴ m ³ /d；P _R Static pressure of stratum, wherein the unit is MPa; p (P) _wf Is the bottom hole flow pressure, and the unit is MPa; a is a laminar flow coefficient; b is the turbulence coefficient.

In addition, the laminar flow coefficient is a characteristic coefficient representing complementary doping of natural gas micelles in a gas well, and flowing in an orderly manner. The turbulence coefficient is a characteristic coefficient that is indicative of the flow of a natural gas jet in a gas well.

Specifically, the operation of step (2) may include the following steps a-F:

step A: taking the ith second yield of the n second yields as a target yield, i is greater than or equal to 1 and less than or equal to n.

And (B) step (B): and (3) carrying out the ith well opening production of the gas well in a third preset time period with the target production rate, and determining the instant bottom hole flow pressure from the ith well opening production to the ith well opening production as the first bottom hole flow pressure corresponding to the ith second production rate to the ith well opening production rate to the 1 st well opening production rate when the i is not 1.

It should be noted that the third preset duration may be preset, and the third preset duration may be set shorter. For example, the third preset time period may be 3 hours, 5 hours, or the like.

It is noted that, when the well testing process in the embodiment of the present invention is performed after the completion of the oil testing of the gas well and before the production of the gas well, the wellhead of the gas well is not equipped with the complete pipeline equipment for conveying the natural gas, and toxic and corrosive gases such as hydrogen sulfide contained in the gas well are easy to corrode the testing instrument arranged at the bottom of the well, and when the gases enter the air at the ground through the wellhead, the gases are easy to damage the organisms around the gas well, so that the third preset duration can be set to be shorter to reduce unnecessary loss or damage.

Step C: when the production of the ith open well is completed, judging whether i is equal to n; if i is equal to n, determining the instant bottom-hole flow pressure when the ith open-hole production is completed as the first bottom-hole flow pressure corresponding to the ith second production; if i is not equal to n, let i=i+1, return to step a.

For example, 4 yields from the production range of a gas well are selected as 4 second yields, which are 15×10, respectively ⁴ m ³ /d、20×10 ⁴ m ³ /d、25×10 ⁴ m ³ /d and 30X 10 ⁴ m ³ /d, 15X 10 ⁴ m ³ As a first and second yield, 20X 10 ⁴ m ³ As a second yield, 25X 10 ⁴ m ³ As a third second yield, 30X 10 ⁴ m ³ And/d as a fourth second yield. The third preset time period was then set to 3 hours and the gas well was set at 15 x 10 ⁴ m ³ /d for 3 hours, and directly converting the gas well to 20×10 when the first well production is completed ⁴ m ³ And/d continuing the second open-hole production for 3 hours, and recording the instantaneous bottom hole pressure from the first open-hole production to the second open-hole production, wherein the instantaneous bottom hole pressure is 15×10 ⁴ m ³ A first bottom hole flow pressure corresponding to/d; then when the second production is completed, the gas well is directly replaced by 25×10 ⁴ m ³ And/d continuing the third open production for 3 hours, and recording the instantaneous bottom hole pressure from the second open production to the third open production, wherein the instantaneous bottom hole pressure is 25×10 ⁴ m ³ The first bottom hole flow pressure corresponding to/d is analogically calculated until the fourth time of well opening production is completed, and the instant bottom hole flow pressure when the fourth time of well opening production is completed is taken as 30 multiplied by 10 ⁴ m ³ First corresponding to/dBottom hole flow pressure. Thus, a first bottom hole pressure corresponding to each of the 4 second yields is obtained.

It should be noted that, in the embodiment of the invention, only n yields are selected from the yield range of the gas well to serve as n second yields one by one, then the gas well is subjected to uninterrupted well opening production for a third preset time period respectively according to each second yield in the n second yields, and the first bottom hole flow pressure corresponding to each second yield in the n second yields can be obtained, so that the process of determining the turbulence coefficient in the binomial productivity equation is more time-saving and faster, and the well testing period of the gas well is shortened.

Step D: and determining n coordinate points corresponding to the n second yields one-to-one according to the n second yields, the first bottom hole flow pressure corresponding to each of the n second yields and the stratum static pressure included in the reservoir parameters.

The coordinate point is a point having an abscissa and an ordinate in a two-dimensional coordinate system.

Specifically, the operation of step D may include the following steps a-b:

Step a: and determining the ith second yield in the n second yields as the abscissa of the coordinate point corresponding to the ith second yield.

Step b: dividing the square of the formation static pressure included in the reservoir parameter by the square of the first bottom hole flow pressure corresponding to the ith second yield, and obtaining the ordinate of the coordinate point corresponding to the ith second yield.

After determining the abscissa and the ordinate of the coordinate point corresponding to the ith second yield, the coordinate point corresponding to the ith second yield is determined.

Step E: and performing curve fitting on the n coordinate points to obtain a first curve.

It should be noted that, the operation of curve fitting n coordinate points may refer to the related art, and this will not be described in detail in the embodiments of the present invention.

Step F: the slope of the first curve is determined as a turbulence factor in the binomial capacity equation.

It should be noted that, when the binomial capacity equation is

When then the equation can become

Will q _g As abscissa, ++>

As ordinate, a straight line can be obtained, the slope of which is B, and since B is expressed as a turbulence coefficient, the slope of the first curve can be determined as a turbulence coefficient in the binomial capacity equation.

(3) The minimum yield and the maximum yield among the n second yields are obtained.

(4) A yield range having a minimum value of the minimum yield and a maximum value of the maximum yield is determined as a target yield range.

The target production range is included in the production range of the gas well.

(5) One yield is selected from the target yield range as the third yield.

The third yield may be a yield selected randomly from the target yield range, or may be the same as one of the n second yields.

(6) And determining the laminar flow coefficient in the binomial productivity equation according to the third yield, the well test model, the turbulence coefficient and the stratum static pressure included in the reservoir parameters.

Wherein the operation of step (6) may comprise steps (61) -step (64):

(61) Inputting the third yield into a well test model, simulating well production of the gas well with the third yield in a fourth preset time period by the well test model, and outputting the simulated bottom hole flow pressure of the gas well in the fourth preset time period.

It should be noted that, the fourth preset duration may be preset, and in order to make the simulated bottom hole flow pressure output by the well test model after the well is started with the third production of the simulated gas well more accurate, the fourth preset duration may be set longer, for example, the fourth preset duration may be 2 days, 3 days, and so on.

(62) And determining a target coordinate point according to the third yield, the simulated bottom hole flow pressure output by the well test model and the stratum static pressure included in the reservoir parameters.

Specifically, the third yield may be taken as an abscissa of the target coordinate point, and the square of the formation static pressure included in the reservoir parameter minus the square of the simulated bottom hole flow pressure output by the well test model is divided by the third yield to obtain an ordinate of the target coordinate point, and the target coordinate point is determined after the abscissa and the ordinate of the target coordinate point are determined.

(63) A curve passing through the target coordinate point and having a slope of turbulence coefficient is determined as a second curve.

The second curve is a curve parallel to the first curve, and the second curve has an intercept on the horizontal axis.

(64) The intercept of the second curve on the horizontal axis is determined as the laminar coefficient in the binomial capacity equation.

It should be noted that, when the binomial capacity equation is

The equation can be changed to

Will q _g As abscissa, ++>

As the ordinate, a straight line with an intercept a on the horizontal axis can be obtained, and since a is expressed as a laminar flow coefficient, the intercept of the second curve on the horizontal axis can be determined as a laminar flow coefficient in the binomial capacity equation.

(7) And determining a second unobstructed flow rate of the gas well by a binomial productivity equation according to the turbulence coefficient, the laminar flow coefficient and the formation static pressure included in the reservoir parameters.

It should be noted that the number of the substrates,when the binomial capacity equation is

When B is expressed as turbulence coefficient, A is expressed as laminar flow coefficient, P _R Represents the static pressure of the stratum, P _wf Expressed as bottom hole flow pressure, at this time, let P _wf ＝101.325×10 ^-3 MPa, i.e. q obtained when the bottom hole flow pressure is equal to the atmospheric pressure _g I.e., the second unobstructed flow rate of the gas well, i.e., the maximum theoretical production that the gas well can achieve.

It is worth to say that, the well testing method of the gas well provided by the embodiment of the invention takes the data in the oil testing period as the basis for predicting the yield range of the gas well, and tests the gas well according to the yield range of the gas well, and finally determines the second unimpeded flow which can be used for evaluating the productivity of the gas well.

For ease of understanding, the above step 2056 is described below in connection with fig. 3. Referring to fig. 3, step 2056 may specifically include steps 301-317 as follows.

Step 301: n production rates are selected from the production rate range of the gas well as n second production rates.

Step 302: the ith second yield of the n second yields is taken as the target yield.

Step 303: and (3) carrying out the ith well opening production of the gas well in a third preset time period with the target production rate, and determining the instant bottom hole flow pressure from the ith well opening production to the ith well opening production as the first bottom hole flow pressure corresponding to the ith second production rate to the ith well opening production rate to the 1 st well opening production rate when the i is not 1.

Step 304: and when the production of the ith open well is completed, judging whether i and n are equal.

If not, let i=i+1, return to step 302.

If so, steps 305-317 are performed.

Step 305: and determining the instant bottom hole flow pressure at the completion of the ith well opening production as the first bottom hole flow pressure corresponding to the ith second production.

Step 306: and determining the ith second yield in the n second yields as the abscissa of the coordinate point corresponding to the ith second yield.

Step 307: dividing the square of the formation static pressure included in the reservoir parameter by the square of the first bottom hole flow pressure corresponding to the ith second yield, and obtaining the ordinate of the coordinate point corresponding to the ith second yield.

Step 308: and performing curve fitting on n coordinate points corresponding to the n second yields one by one to obtain a first curve.

Step 309: the slope of the first curve is determined as a turbulence factor in the binomial capacity equation.

Step 310: the minimum yield and the maximum yield among the n second yields are obtained.

Step 311: a yield range having a minimum value of the minimum yield and a maximum value of the maximum yield is determined as a target yield range.

Step 312: one yield is selected from the target yield range as the third yield.

Step 313: inputting the third yield into a well test model, simulating well production of the gas well with the third yield in a fourth preset time period by the well test model, and outputting the simulated bottom hole flow pressure of the gas well in the fourth preset time period.

Step 314: and determining a target coordinate point according to the third yield, the simulated bottom hole flow pressure output by the well test model and the stratum static pressure included in the reservoir parameters.

Step 315: a curve passing through the target coordinate point and having a slope of turbulence coefficient is determined as a second curve.

Step 316: the intercept of the second curve on the horizontal axis is determined as the laminar coefficient in the binomial capacity equation.

Step 317: and determining a second unobstructed flow rate of the gas well by a binomial productivity equation according to the turbulence coefficient, the laminar flow coefficient and the formation static pressure included in the reservoir parameters.

Fig. 4 is a well testing device for a gas well according to an embodiment of the present invention, referring to fig. 4, the device includes: an acquisition module 401, a first determination module 402, a second determination module 403, a third determination module 404, and a well test module 405;

An obtaining module 401, configured to obtain an oil test yield and a wellhead oil pressure of the gas well during a well opening process of the oil test, and obtain a wellhead oil pressure of the gas well during a well closing process of the oil test;

a first determining module 402, configured to determine a bottom hole flow pressure of the gas well according to a wellhead oil pressure of the gas well during a well opening process of the test oil;

a second determining module 403, configured to determine a formation static pressure of the gas well according to a wellhead oil pressure of the gas well during a closing process of the test oil;

a third determining module 404, configured to determine a production range of the gas well according to a test oil yield of the gas well during a test oil opening process, a bottom hole flow pressure of the gas well, and a formation static pressure;

a well testing module 405 for testing a gas well according to a production range of the gas well.

Optionally, the first determining module 402 includes:

and the second calculation unit is used for adding the stable value of the wellhead oil pressure of the gas well with the first pressure increment in the well opening process of the oil test to obtain the bottom hole flow pressure of the gas well.

Optionally, the second determining module 403 includes:

and the fourth calculation unit is used for adding the maximum value of wellhead oil pressure of the gas well in the well closing process of the test oil to the second pressure increment to obtain the stratum static pressure of the gas well.

Optionally, the third determining module 404 includes:

the first determining unit is used for determining a first unimpeded flow rate of the gas well according to the oil test yield of the gas well in the oil test opening process, the bottom hole flow pressure and the stratum static pressure of the gas well;

the fourth calculation unit is used for multiplying the first choked flow quantity of the gas well by the first proportion to obtain a first numerical value; multiplying the first choked flow of the gas well by a second ratio to obtain a second value, wherein the second ratio is greater than the first ratio;

and the second determining unit is used for determining the production range with the minimum value being a first value and the maximum value being a second value as the production range of the gas well.

Optionally, the well testing module 405 includes:

a selection unit for selecting one production from a production range of gas wells as a first production;

The first recording unit is used for carrying out well opening production on the gas well in a first preset time period with a first yield, and recording the bottom hole flow pressure of the gas well in the first preset time period in the well opening production process;

the third acquisition unit is used for acquiring logging data of the gas well;

the fourth acquisition unit is used for acquiring a well test model of the gas well and reservoir parameters of a gas layer where the gas well is located according to the bottom hole flow pressure of the gas well in the first preset time period, the bottom hole flow pressure of the gas well in the second preset time period and logging data of the gas well;

and the third determining unit is used for determining a second unobstructed flow rate of the gas well according to the production range of the gas well, the well test model and the reservoir parameters.

Optionally, the third determining unit includes:

a first selection subunit for selecting n yields from the yield range of the gas well as n second yields, wherein n is an integer greater than or equal to 2;

a first determination subunit configured to determine a turbulence coefficient in the binomial productivity equation according to the n second productivities and the formation static pressures included in the reservoir parameters;

a second determining subunit configured to determine, as the target yield range, a yield range having a minimum value of minimum yield and a maximum value of maximum yield;

a third determination subunit configured to determine a laminar flow coefficient in the binomial productivity equation according to the third yield, the well test model, the turbulence coefficient, and the formation static pressure included in the reservoir parameter;

and a fourth determination subunit configured to determine a second unobstructed flow rate of the gas well according to the turbulence coefficient, the laminar flow coefficient, and the formation static pressure included in the reservoir parameter by using the binomial capacity equation.

Optionally, the first determining subunit is configured to:

performing curve fitting on the n coordinate points to obtain a first curve;

Optionally, the first determining subunit is configured to:

Optionally, the third determining subunit is configured to:

It should be noted that: in the well testing device for a gas well provided in the foregoing embodiment, only the division of the foregoing functional modules is used as an example for illustrating the well testing of the gas well, and in practical application, the foregoing functional allocation may be performed by different functional modules according to needs, that is, the internal structure of the device is divided into different functional modules to perform all or part of the functions described above. In addition, the well testing device of the gas well provided by the embodiment and the well testing method embodiment of the gas well belong to the same conception, and the specific implementation process is detailed in the method embodiment, and is not repeated here.

Fig. 5 is a schematic structural diagram of a well testing device for a gas well according to an embodiment of the present invention. Referring to fig. 5, the apparatus may be a terminal 500, and the terminal 500 may be: a smart phone, a tablet computer, an MP3 player (Moving Picture Experts Group Audio Layer III, motion picture expert compression standard audio plane 3), an MP4 (Moving Picture Experts Group Audio Layer IV, motion picture expert compression standard audio plane 4) player, a notebook computer, or a desktop computer. The terminal 500 may also be referred to by other names of user devices, portable terminals, laptop terminals, desktop terminals, etc.

In general, the terminal 500 includes: a processor 501 and a memory 502.

Processor 501 may include one or more processing cores, such as a 4-core processor, an 8-core processor, and the like. The processor 501 may be implemented in at least one hardware form of DSP (Digital Signal Processing ), FPGA (Field-Programmable Gate Array, field programmable gate array), PLA (Programmable Logic Array ). The processor 501 may also include a main processor and a coprocessor, the main processor being a processor for processing data in an awake state, also referred to as a CPU (Central Processing Unit ); a coprocessor is a low-power processor for processing data in a standby state. In some embodiments, the processor 501 may be integrated with a GPU (Graphics Processing Unit, image processor) for taking care of rendering and rendering of content that the display screen is required to display. In some embodiments, the processor 501 may also include an AI (Artificial Intelligence ) processor for processing computing operations related to machine learning.

Memory 502 may include one or more computer-readable storage media, which may be non-transitory. Memory 502 may also include high-speed random access memory as well as non-volatile memory, such as one or more magnetic disk storage devices, flash memory storage devices. In some embodiments, a non-transitory computer readable storage medium in memory 502 is used to store at least one instruction for execution by processor 501 to implement a well testing method for a gas well provided by a method embodiment in the present application.

In some embodiments, the terminal 500 may further optionally include: a peripheral interface 503 and at least one peripheral. The processor 501, memory 502, and peripheral interface 503 may be connected by buses or signal lines. The individual peripheral devices may be connected to the peripheral device interface 503 by buses, signal lines or circuit boards. Specifically, the peripheral device includes: at least one of radio frequency circuitry 504, touch display 505, camera 506, audio circuitry 507, positioning component 508, and power supply 509.

Peripheral interface 503 may be used to connect at least one Input/Output (I/O) related peripheral to processor 501 and memory 502. In some embodiments, processor 501, memory 502, and peripheral interface 503 are integrated on the same chip or circuit board; in some other embodiments, either or both of the processor 501, memory 502, and peripheral interface 503 may be implemented on separate chips or circuit boards, which is not limited in this application.

The Radio Frequency circuit 504 is configured to receive and transmit RF (Radio Frequency) signals, also known as electromagnetic signals. The radio frequency circuitry 504 communicates with a communication network and other communication devices via electromagnetic signals. The radio frequency circuit 504 converts an electrical signal into an electromagnetic signal for transmission, or converts a received electromagnetic signal into an electrical signal. Optionally, the radio frequency circuit 504 includes: an antenna system, an RF transceiver, one or more amplifiers, a tuner, an oscillator, a digital signal processor, a codec chipset, a subscriber identity module card, etc. The radio frequency circuitry 504 may communicate with other terminals via at least one wireless communication protocol. The wireless communication protocol includes, but is not limited to: metropolitan area networks, various generations of mobile communication networks (2G, 3G, 4G, and 5G), wireless local area networks, and/or WiFi (Wireless Fidelity ) networks. In some embodiments, the radio frequency circuitry 504 may also include NFC (Near Field Communication ) related circuitry, which is not limited in this application.

The display 505 is used to display a UI (User Interface). The UI may include graphics, text, icons, video, and any combination thereof. When the display 505 is a touch display, the display 505 also has the ability to collect touch signals at or above the surface of the display 505. The touch signal may be input as a control signal to the processor 501 for processing. At this time, the display 505 may also be used to provide virtual buttons and/or virtual keyboards, also referred to as soft buttons and/or soft keyboards. In some embodiments, the display 505 may be one, and disposed on the front panel of the terminal 500; in other embodiments, the display 505 may be at least two, respectively disposed on different surfaces of the terminal 500 or in a folded design; in still other embodiments, the display 505 may be a flexible display disposed on a curved surface or a folded surface of the terminal 500. Even more, the display 505 may be arranged in a non-rectangular irregular pattern, i.e., a shaped screen. The display 505 may be made of LCD (Liquid Crystal Display ), OLED (Organic Light-Emitting Diode) or other materials.

The camera assembly 506 is used to capture images or video. Optionally, the camera assembly 506 includes a front camera and a rear camera. Typically, the front camera is disposed on the front panel of the terminal and the rear camera is disposed on the rear surface of the terminal. In some embodiments, the at least two rear cameras are any one of a main camera, a depth camera, a wide-angle camera and a tele camera, so as to realize that the main camera and the depth camera are fused to realize a background blurring function, and the main camera and the wide-angle camera are fused to realize a panoramic shooting and Virtual Reality (VR) shooting function or other fusion shooting functions. In some embodiments, camera assembly 506 may also include a flash. The flash lamp can be a single-color temperature flash lamp or a double-color temperature flash lamp. The dual-color temperature flash lamp refers to a combination of a warm light flash lamp and a cold light flash lamp, and can be used for light compensation under different color temperatures.

The audio circuitry 507 may include a microphone and a speaker. The microphone is used for collecting sound waves of users and environments, converting the sound waves into electric signals, and inputting the electric signals to the processor 501 for processing, or inputting the electric signals to the radio frequency circuit 504 for voice communication. For the purpose of stereo acquisition or noise reduction, a plurality of microphones may be respectively disposed at different portions of the terminal 500. The microphone may also be an array microphone or an omni-directional pickup microphone. The speaker is used to convert electrical signals from the processor 501 or the radio frequency circuit 504 into sound waves. The speaker may be a conventional thin film speaker or a piezoelectric ceramic speaker. When the speaker is a piezoelectric ceramic speaker, not only the electric signal can be converted into a sound wave audible to humans, but also the electric signal can be converted into a sound wave inaudible to humans for ranging and other purposes. In some embodiments, audio circuitry 507 may also include a headphone jack.

The location component 508 is used to locate the current geographic location of the terminal 500 to enable navigation or LBS (Location Based Service, location-based services). The positioning component 508 may be a positioning component based on the United states GPS (Global Positioning System ), the Beidou system of China, the Granati system of Russia, or the Galileo system of the European Union.

A power supply 509 is used to power the various components in the terminal 500. The power supply 509 may be an alternating current, a direct current, a disposable battery, or a rechargeable battery. When the power supply 509 comprises a rechargeable battery, the rechargeable battery may support wired or wireless charging. The rechargeable battery may also be used to support fast charge technology.

In some embodiments, the terminal 500 further includes one or more sensors 510. The one or more sensors 510 include, but are not limited to: an acceleration sensor 511, a gyro sensor 512, a pressure sensor 513, a fingerprint sensor 514, an optical sensor 515, and a proximity sensor 516.

The acceleration sensor 511 can detect the magnitudes of accelerations on three coordinate axes of the coordinate system established with the terminal 500. For example, the acceleration sensor 511 may be used to detect components of gravitational acceleration on three coordinate axes. The processor 501 may control the touch display 505 to display a user interface in a landscape view or a portrait view according to a gravitational acceleration signal acquired by the acceleration sensor 511. The acceleration sensor 511 may also be used for acquisition of motion data of a game or a user.

The gyro sensor 512 may detect a body direction and a rotation angle of the terminal 500, and the gyro sensor 512 may collect a 3D motion of the user to the terminal 500 in cooperation with the acceleration sensor 511. The processor 501 may implement the following functions based on the data collected by the gyro sensor 512: motion sensing (e.g., changing UI according to a tilting operation by a user), image stabilization at shooting, game control, and inertial navigation.

The pressure sensor 513 may be disposed at a side frame of the terminal 500 and/or at a lower layer of the touch display 505. When the pressure sensor 513 is disposed at a side frame of the terminal 500, a grip signal of the user to the terminal 500 may be detected, and the processor 501 performs left-right hand recognition or quick operation according to the grip signal collected by the pressure sensor 513. When the pressure sensor 513 is disposed at the lower layer of the touch display screen 505, the processor 501 controls the operability control on the UI interface according to the pressure operation of the user on the touch display screen 505. The operability controls include at least one of a button control, a scroll bar control, an icon control, and a menu control.

The fingerprint sensor 514 is used for collecting the fingerprint of the user, and the processor 501 identifies the identity of the user according to the fingerprint collected by the fingerprint sensor 514, or the fingerprint sensor 514 identifies the identity of the user according to the collected fingerprint. Upon recognizing that the user's identity is a trusted identity, the user is authorized by the processor 501 to perform relevant sensitive operations including unlocking the screen, viewing encrypted information, downloading software, paying for and changing settings, etc. The fingerprint sensor 514 may be provided at the front, rear or side of the terminal 500. When a physical key or a vendor Logo is provided on the terminal 500, the fingerprint sensor 514 may be integrated with the physical key or the vendor Logo.

The optical sensor 515 is used to collect the ambient light intensity. In one embodiment, the processor 501 may control the display brightness of the touch screen 505 based on the ambient light intensity collected by the optical sensor 515. Specifically, when the intensity of the ambient light is high, the display brightness of the touch display screen 505 is turned up; when the ambient light intensity is low, the display brightness of the touch display screen 505 is turned down. In another embodiment, the processor 501 may also dynamically adjust the shooting parameters of the camera assembly 506 based on the ambient light intensity collected by the optical sensor 515.

The proximity sensor 516, also referred to as a distance sensor, is typically disposed on the front panel of the terminal 500. The proximity sensor 516 serves to collect a distance between the user and the front surface of the terminal 500. In one embodiment, when the proximity sensor 516 detects that the distance between the user and the front of the terminal 500 gradually decreases, the processor 501 controls the touch display 505 to switch from the bright screen state to the off screen state; when the proximity sensor 516 detects that the distance between the user and the front surface of the terminal 500 gradually increases, the processor 501 controls the touch display 505 to switch from the off-screen state to the on-screen state.

Those skilled in the art will appreciate that the structure shown in fig. 5 is not limiting and that more or fewer components than shown may be included or certain components may be combined or a different arrangement of components may be employed.

It will be understood by those skilled in the art that all or part of the steps for implementing the above embodiments may be implemented by hardware, or may be implemented by a program for instructing relevant hardware, where the program may be stored in a computer readable storage medium, and the storage medium may be a read-only memory, a magnetic disk or an optical disk, etc.

The foregoing description of the preferred embodiments of the invention is not intended to limit the invention to the precise form disclosed, and any such modifications, equivalents, and alternatives falling within the spirit and scope of the invention are intended to be included within the scope of the invention.

Claims

1. A method of testing a gas well, the method comprising:

According to the production range of the gas well, testing the gas well; wherein the testing the gas well according to the production range of the gas well comprises the following steps: selecting a production from a production range of the gas well as a first production; carrying out well opening production on the gas well within a first preset time period with the first yield, and recording the bottom hole flow pressure of the gas well within the first preset time period in the well opening production process; closing the gas well within a second preset time period, and recording the bottom hole flow pressure of the gas well within the second preset time period in the closing process; acquiring logging data of the gas well; acquiring a well test model of the gas well and reservoir parameters of a gas layer where the gas well is located according to the bottom hole flow pressure of the gas well in the first preset time period, the bottom hole flow pressure of the gas well in the second preset time period and logging data of the gas well; a second unobstructed flow rate of the gas well is determined based on the production range of the gas well, the well test model, and the reservoir parameters.

2. The method of claim 1, wherein determining the bottom hole flow pressure of the gas well based on the wellhead oil pressure of the gas well during the opening of the test oil comprises:

3. The method of claim 1, wherein determining the formation static pressure of the gas well based on the wellhead oil pressure of the gas well during shut-in of the test oil comprises:

4. The method of claim 1, wherein the determining the production range of the gas well based on the test oil production of the gas well during the open-loop of test oil, the bottom hole flow pressure of the gas well, and the formation static pressure comprises:

5. The method of claim 1, wherein the determining a second unobstructed flow rate for the gas well based on the production range of the gas well, the well test model, and the reservoir parameters comprises:

obtaining the minimum yield and the maximum yield of the n second yields;

selecting one yield from the target yield range as a third yield;

6. The method of claim 5, wherein determining turbulence factors in a binomial productivity equation based on the n second productivities and the formation static pressure included in the reservoir parameters comprises:

performing curve fitting on the n coordinate points to obtain a first curve;

7. The method of claim 6, wherein the determining n coordinate points in one-to-one correspondence with the n second yields based on the n second yields, the first bottom hole flow pressure corresponding to each of the n second yields, and the formation static pressure included in the reservoir parameters comprises:

8. The method of any of claims 5-7, wherein determining the laminar flow coefficients in the binomial productivity equation based on the third production volume, the well test model, the turbulence coefficients, and the formation static pressure included in the reservoir parameters comprises:

9. A well testing apparatus for a gas well, the apparatus comprising:

the well testing module is used for testing the well according to the yield range of the gas well; wherein, the well testing module includes: a selection unit for selecting one production from a production range of the gas well as a first production; the recording unit is used for carrying out open-hole production on the gas well in a first preset time period with the first yield, and recording the bottom hole flow pressure of the gas well in the first preset time period in the open-hole production process; the second recording unit is used for closing the gas well within a second preset time period and recording the bottom hole flow pressure of the gas well within the second preset time period in the closing process; the third acquisition unit is used for acquiring logging data of the gas well; a fourth obtaining unit, configured to obtain a well test model of the gas well and reservoir parameters of a gas layer where the gas well is located according to a bottom hole flow pressure of the gas well in the first preset duration, a bottom hole flow pressure of the gas well in the second preset duration, and logging data of the gas well; and a third determining unit for determining a second unobstructed flow rate of the gas well according to the production range of the gas well, the well test model and the reservoir parameters.

10. The apparatus of claim 9, wherein the first determination module comprises:

11. The apparatus of claim 9, wherein the second determination module comprises:

12. The apparatus of claim 9, wherein the third determination module comprises:

13. The apparatus of claim 9, wherein the third determining unit comprises:

14. The apparatus of claim 13, wherein the first determination subunit is to:

performing curve fitting on the n coordinate points to obtain a first curve;

15. The apparatus of claim 14, wherein the first determination subunit is to:

16. The apparatus of any of claims 13-15, wherein the third determination subunit is configured to:

17. A computer readable storage medium having stored thereon instructions, which when executed by a processor, implement the steps of the method of any of claims 1-8.