CN114060018B - Reservoir dynamic reserve determination method, system, equipment and readable storage medium - Google Patents
Reservoir dynamic reserve determination method, system, equipment and readable storage medium Download PDFInfo
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Abstract
The application discloses a method, a system, equipment and a readable storage medium for determining dynamic reserves of a reservoir, wherein the method comprises the following steps: acquiring pressure data of a gas reservoir well test stratum at different time points; determining a logarithmic pressure derivative curve from the pressure data; calculating the dynamic reserve of the gas reservoir well test changing along with time according to the pressure derivative logarithmic curve; and calculating the dynamic reserve of the gas reservoir well test changing along with time according to the pressure derivative logarithmic curve. The method reduces the safety risk and the test cost of long-time test, and simply, conveniently and accurately calculates the dynamic reserve of the reservoir.
Description
Technical Field
The application relates to the technical field of exploitation and analysis of petroleum and natural gas, in particular to a method, a system, equipment and a readable storage medium for determining dynamic reserves of a reservoir.
Background
This section is intended to provide a background or context to the embodiments of the application that are recited in the claims. The description herein is not admitted to be prior art by inclusion in this section.
The gas reservoir dynamic reserve is an important basis for the reasonable production allocation of a single well, the formulation of reasonable development technical policies and the adjustment of middle and later development schemes, and the high-pressure, ultra-high-pressure or fractured gas reservoir dynamic reserve evaluation is a challenging work faced by gas reservoir engineers.
The method for calculating the dynamic reserves of the gas reservoirs mainly comprises a material balance method and a modern yield decreasing analysis method. The mass balance reserves calculation can be divided into two types, wherein the type 1 needs parameters such as rock and fluid compression coefficient (the parameters are also used by the modern yield decreasing analysis method), and the type 2 only needs production data. Because of the uncertainty of accumulating effective compression coefficients, a material balance method which does not consider the compression coefficients should be preferred to calculate the dynamic reserves of such reservoirs. According to the statistical analysis of 20 foreign developed high-pressure and ultrahigh-pressure gas reservoir examples, the error of the reservoir calculation result is less than 10% when the reservoir pressure failure degree is 0.23-0.50 and the average is 0.33, but the corresponding recovery degree is 0.45, and the reservoir pressure failure degree is at the middle and later stages of development.
Early dynamic reserve evaluation in development has been a critical issue for developers.
For an ultrahigh-pressure fractured tight sandstone gas reservoir, a straight line with a slope of 1.0 can appear in the middle and later stages of the well test derivative curve, and the size of the dynamic reserve can be determined according to the well test method.
Disclosure of Invention
The embodiment of the application provides a method, a system, equipment and a readable storage medium for determining dynamic reserves of a reservoir, which can accurately obtain the size of the dynamic reserves of a single well in early development and lay a foundation for the establishment of development technical policies.
In a first aspect, an embodiment of the present application provides a method for determining a dynamic reserve of a reservoir, including:
acquiring pressure data of a gas reservoir well test stratum at different time points;
Determining a logarithmic pressure derivative curve from the pressure data;
and calculating the dynamic reserve of the gas reservoir well test changing along with time according to the pressure derivative logarithmic curve.
In certain embodiments, the calculating the dynamic reserve of the gas reservoir test from the log pressure derivative curve comprises:
Judging whether the slope of the curve segment after the set time point of the pressure derivative logarithmic curve is within an error range defined by a set value;
if yes, generating a change line of the pressure derivative along with time according to the slope and a curve segment of the logarithmic pressure derivative curve after a set time point;
and calculating the dynamic reserve of the gas reservoir well test changing along with time according to the change line.
In certain embodiments, the dynamic reserves include dynamic treatments under formation conditions and dynamic reserves under surface conditions; the calculating the dynamic reserve of the gas reservoir well test changing along with time according to the change line comprises the following steps:
Intercepting coordinate information corresponding to any abscissa on the change line;
And calculating the dynamic reserve of the gas reservoir well test over time according to the gas well yield, the coordinate information, the original stratum pressure and the gas volume coefficient.
In certain embodiments, the dynamic reserve of the gas reservoir test over time is calculated from the gas well production, the coordinate information, the raw formation pressure, the gas volume coefficient according to the following formula:
V＝Cpi
Wherein, C is the wellbore reservoir effect, the unit is m 3/MPa;qg is the gas well yield, the unit is m 3/d;Bgi is the gas volume coefficient, and the unit is m 3/m3; [ delta ] is the abscissa of any point on the derivative curve of slope 1.0 in h; [ Δm' ] is the ordinate of any point on the derivative curve of slope 1.0 in MPa; p i is the original formation pressure in MPa; v is the volume (dynamic reserve) of the stratum under the condition, and the unit is m 3; OGIP is the subsurface volume (dynamic reserve), unit m 3.
In a second aspect, a reservoir dynamic reserve determination system, comprising:
the data acquisition module is used for acquiring pressure data of the gas reservoir well test stratum at different time points;
The curve drawing module is used for determining a pressure derivative logarithmic curve according to the pressure data;
And the reservoir dynamic reserve determining module is used for calculating the dynamic reserve of the gas reservoir well test changing along with time according to the pressure derivative logarithmic curve.
In certain embodiments, the reservoir dynamic reserve determination module is specifically configured to:
Judging whether the slope of the curve segment after the set time point of the pressure derivative logarithmic curve is within an error range defined by a set value;
if yes, generating a change line of the pressure derivative along with time according to the slope and a curve segment of the logarithmic pressure derivative curve after a set time point;
and calculating the dynamic reserve of the gas reservoir well test changing along with time according to the change line.
In certain embodiments, the dynamic reserves include dynamic treatments under formation conditions and dynamic reserves under surface conditions; the reservoir dynamic reserve determination module is specifically configured to:
Intercepting coordinate information corresponding to any abscissa on the change line;
And calculating the dynamic reserve of the gas reservoir well test over time according to the gas well yield, the coordinate information, the original stratum pressure and the gas volume coefficient.
In certain embodiments, the dynamic reserve of the gas reservoir test over time is calculated from the gas well production, the coordinate information, the raw formation pressure, the gas volume coefficient according to the following formula:
V＝Cpi
Wherein, C is the wellbore reservoir effect, the unit is m 3/MPa;qg is the gas well yield, the unit is m 3/d;Bgi is the gas volume coefficient, and the unit is m 3/m3; [ delta ] is the abscissa of any point on the derivative curve of slope 1.0 in h; [ Δm' ] is the ordinate of any point on the derivative curve of slope 1.0 in MPa; p i is the original formation pressure in MPa; v is the volume (dynamic reserve) of the stratum under the condition, and the unit is m 3; OGIP is the subsurface volume (dynamic reserve), unit m 3.
In a third aspect, an embodiment of the present application further provides a computer device, including a memory, a processor, and a computer program stored on the memory and executable on the processor, where the processor implements the method of any of the first aspects when the processor executes the computer program.
In a fourth aspect, embodiments of the present application also provide a computer readable storage medium storing a computer program for performing any one of the methods of the first aspect.
In summary, the application discloses a method, a system, a device and a readable storage medium for determining dynamic reserves of a reservoir, which are implemented by acquiring pressure data of gas reservoir well test formations at different time points; then determining a logarithmic pressure derivative curve according to the pressure data; and finally, calculating the dynamic reserve of the gas reservoir well test along with the time change according to the logarithmic curve of the pressure derivative. The method can accurately obtain the size of the single-well dynamic reserves in early development, lays a foundation for the establishment of development technical policies, and solves the difficult problem of evaluating the dynamic reserves of the ultra-high pressure and fractured tight sandstone gas reservoir in early development.
Drawings
In order to more clearly illustrate the embodiments of the application or the technical solutions in the prior art, the drawings that are required in the embodiments or the description of the prior art will be briefly described, it being obvious that the drawings in the following description are only some embodiments of the application, and that other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art. In the drawings:
FIG. 1 is a schematic flow chart of a method for determining dynamic reserves of a reservoir according to an embodiment of the present application;
FIG. 2 is a schematic diagram of an embodiment provided in an embodiment of the present application;
FIG. 3 is a block diagram of a reservoir dynamic reserve determination system provided in an embodiment of the present application.
Detailed Description
The following description of the embodiments of the present application will be made clearly and fully with reference to the accompanying drawings, in which some, but not all embodiments of the application are shown. All other embodiments, which can be made by those skilled in the art based on the embodiments of the application without making any inventive effort, are intended to be within the scope of the application.
The principles and spirit of the present application are explained in detail below with reference to several representative embodiments thereof.
Although the application provides a method operation or apparatus structure as shown in the following examples or figures, more or fewer operation steps or module units may be included in the method or apparatus based on routine or non-inventive labor. In the steps or the structures of the apparatuses in which there is no necessary cause and effect logically, the execution order of the steps or the structure of the modules is not limited to the execution order or the structure of the modules shown in the embodiments or the drawings of the present application. The method or module structure described may be performed sequentially or in parallel according to the embodiment or the method or module structure shown in the drawings when applied to a device or an end product in practice.
FIG. 1 shows a schematic flow diagram of a method for reservoir dynamic reserve determination, the method comprising the steps of:
Step 101: acquiring pressure data of a gas reservoir well test stratum at different time points;
step 102: determining a logarithmic pressure derivative curve from the pressure data;
step 103: calculating the dynamic reserve of the gas reservoir well test changing along with time according to the pressure derivative logarithmic curve;
in one possible implementation, in step 103, specifically includes:
Judging whether the slope of the curve segment after the set time point of the pressure derivative logarithmic curve is within an error range defined by a set value;
if yes, generating a change line of the pressure derivative along with time according to the slope and a curve segment of the logarithmic pressure derivative curve after a set time point;
and calculating the dynamic reserve of the gas reservoir well test changing along with time according to the change line.
In one possible embodiment, the set point is 1, and if the derivative curve slope is 1.0, the flow characteristics can be considered a wellbore effect, with
The volume (dynamic reserve) under the stratum condition is
V＝Cpi (2)
The volume (dynamic reserve) under the ground condition is
Bringing equation (1) into equation (3) with
Wherein: c is the wellbore reservoir effect in m 3/MPa;qg is the gas well yield in m 3/d;Bgi is the gas volume coefficient in m 3/m3; [ delta ] is the abscissa of any point on the derivative curve of slope 1.0 in h; [ Δm' ] is the ordinate of any point on the derivative curve of slope 1.0 in MPa; p i is the original formation pressure in MPa; v is the volume (dynamic reserve) of the stratum under the condition, and the unit is m 3; OGIP is the subsurface volume (dynamic reserve), unit m 3.
In one possible embodiment, in step 103, the dynamic reserves include dynamic treatments under formation conditions and dynamic reserves under surface conditions; the calculating the dynamic reserve of the gas reservoir well test changing along with time according to the change line comprises the following steps:
Intercepting coordinate information corresponding to any abscissa on the change line;
And calculating the dynamic reserve of the gas reservoir well test over time according to the gas well yield, the coordinate information, the original stratum pressure and the gas volume coefficient.
Specifically, the dynamic reserve of the gas reservoir well test over time is calculated according to the following formula according to the gas well yield, the coordinate information, the original stratum pressure and the gas volume coefficient:
V＝Cpi
FIG. 2 is a graph of pressure and pressure derivative versus time, in this example, a gas well production of 75X 10 4m3/d; the original pressure of the air layer is 104MPa; the coordinates of point A in FIG. 2 are (10, 5X 10 -3). Bringing the above values into formula (4) has
From the above embodiments, it can be seen that by analyzing the characteristics of the pressure and pressure derivative double logarithmic curve, the magnitude of the single well control reserve can be calculated by using the coordinates of any point on the derivative curve with a slope of 1.0. The method solves the problem of evaluating dynamic reserves of the ultra-high pressure and fractured tight sandstone gas reservoir in early development.
In summary, the application discloses a reservoir dynamic reserve determining method, which comprises the steps of obtaining pressure data of a gas reservoir well test stratum at different time points; then determining a logarithmic pressure derivative curve according to the pressure data; and finally, calculating the dynamic reserve of the gas reservoir with time change according to the logarithmic curve of the pressure derivative, wherein the method can accurately obtain the size of the single-well dynamic reserve in early development, lays a foundation for the formulation of development technical policy, and solves the difficult problem of evaluating the dynamic reserve of the ultra-high pressure and fractured tight sandstone gas reservoir in early development.
Based on the same technical concept, the embodiment of the application also provides a reservoir dynamic reserve determining system, as shown in fig. 3, which comprises:
the data acquisition module 1 is used for acquiring pressure data of the gas reservoir well test stratum at different time points;
a curve drawing module 2, configured to determine a logarithmic curve of the pressure derivative according to the pressure data;
and the reservoir dynamic reserve determining module 3 is used for calculating the dynamic reserve of the gas reservoir well test changing along with time according to the logarithmic curve of the pressure derivative.
Optionally, the reservoir dynamic reserve determination module is specifically configured to:
Judging whether the slope of the curve segment after the set time point of the pressure derivative logarithmic curve is within an error range defined by a set value;
if yes, generating a change line of the pressure derivative along with time according to the slope and a curve segment of the logarithmic pressure derivative curve after a set time point;
and calculating the dynamic reserve of the gas reservoir well test changing along with time according to the change line.
Optionally, the dynamic reserves include dynamic treatments under formation conditions and dynamic reserves under surface conditions; the reservoir dynamic reserve determination module is specifically configured to:
Intercepting coordinate information corresponding to any abscissa on the change line;
And calculating the dynamic reserve of the gas reservoir well test over time according to the gas well yield, the coordinate information, the original stratum pressure and the gas volume coefficient.
Optionally, the dynamic reserve of the gas reservoir test over time is calculated from the gas well production, the coordinate information, the raw formation pressure, the gas volume coefficient according to the following formula:
V＝Cpi
Wherein, C is the wellbore reservoir effect, the unit is m 3/MPa;qg is the gas well yield, the unit is m 3/d;Bgi is the gas volume coefficient, and the unit is m 3/m3; [ delta ] is the abscissa of any point on the derivative curve of slope 1.0 in h; [ Δm' ] is the ordinate of any point on the derivative curve of slope 1.0 in MPa; p i is the original formation pressure in MPa; v is the volume (dynamic reserve) of the stratum under the condition, and the unit is m 3; OGIP is the subsurface volume (dynamic reserve), unit m 3.
It will be appreciated by those skilled in the art that embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present application is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
The foregoing description of the embodiments has been provided for the purpose of illustrating the general principles of the application, and is not meant to limit the scope of the application, but to limit the application to the particular embodiments, and any modifications, equivalents, improvements, etc. that fall within the spirit and principles of the application are intended to be included within the scope of the application.
Claims (4)
1. A method of reservoir dynamic reserve determination, comprising:
acquiring pressure data of a gas reservoir well test stratum at different time points;
Determining a logarithmic pressure derivative curve from the pressure data;
calculating the dynamic reserve of the gas reservoir well test changing along with time according to the pressure derivative logarithmic curve;
The calculating the dynamic reserve of the gas reservoir well test changing along with time according to the logarithmic curve of the pressure derivative comprises the following steps:
Judging whether the slope of the curve segment after the set time point of the pressure derivative logarithmic curve is within an error range defined by a set value;
if yes, generating a change line of the pressure derivative along with time according to the slope and a curve segment of the logarithmic pressure derivative curve after a set time point;
Calculating the dynamic reserve of the gas reservoir well test changing along with time according to the change line;
the dynamic reserves comprise dynamic treatment under stratum conditions and dynamic reserves under ground conditions; the calculating the dynamic reserve of the gas reservoir well test changing along with time according to the change line comprises the following steps:
Intercepting coordinate information corresponding to any abscissa on the change line;
calculating dynamic reserves of the gas reservoir well test changing along with time according to the gas well yield, the coordinate information, the original stratum pressure and the gas volume coefficient;
Calculating the dynamic reserve of the gas reservoir well test over time according to the gas well yield, the coordinate information, the original stratum pressure and the gas volume coefficient according to the following formula:
V＝Cpi
Wherein, C is the wellbore reservoir effect in m 3/MPa;qg is the gas well production in m 3/d; [ delta ] is the abscissa of any point on the derivative curve of slope 1.0 in h; [ Δm' ] is the ordinate of any point on the derivative curve of slope 1.0 in MPa; p i is the original formation pressure in MPa; v is dynamic reserve under stratum conditions, unit m 3; OGIP is the dynamic reserve under surface conditions, unit m 3.
2. A reservoir dynamic reserve determination system, comprising:
the data acquisition module is used for acquiring pressure data of the gas reservoir well test stratum at different time points;
The curve drawing module is used for determining a pressure derivative logarithmic curve according to the pressure data;
The reservoir dynamic reserve determining module is used for calculating the dynamic reserve of the gas reservoir well test changing along with time according to the pressure derivative logarithmic curve;
The reservoir dynamic reserve determination module is specifically configured to:
Judging whether the slope of the curve segment after the set time point of the pressure derivative logarithmic curve is within an error range defined by a set value;
if yes, generating a change line of the pressure derivative along with time according to the slope and a curve segment of the logarithmic pressure derivative curve after a set time point;
Calculating the dynamic reserve of the gas reservoir well test changing along with time according to the change line;
the dynamic reserves comprise dynamic treatment under stratum conditions and dynamic reserves under ground conditions; the reservoir dynamic reserve determination module is specifically configured to:
Intercepting coordinate information corresponding to any abscissa on the change line;
calculating dynamic reserves of the gas reservoir well test changing along with time according to the gas well yield, the coordinate information, the original stratum pressure and the gas volume coefficient;
Calculating the dynamic reserve of the gas reservoir well test over time according to the gas well yield, the coordinate information, the original stratum pressure and the gas volume coefficient according to the following formula:
V＝Cpi
Wherein, C is the wellbore reservoir effect in m 3/MPa;qg is the gas well production in m 3/d; [ delta ] is the abscissa of any point on the derivative curve of slope 1.0 in h; [ Δm' ] is the ordinate of any point on the derivative curve of slope 1.0 in MPa; p i is the original formation pressure in MPa; v is dynamic reserve under stratum conditions, unit m 3; OGIP is the dynamic reserve under surface conditions, unit m 3.
3. A computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, characterized in that the processor implements the method of claim 1 when executing the computer program.
4. A computer readable storage medium, characterized in that the computer readable storage medium stores a computer program for executing the method of claim 1.
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