CN113622902B - Method and device for determining natural gas density of condensate gas reservoir stratum - Google Patents
Method and device for determining natural gas density of condensate gas reservoir stratum Download PDFInfo
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Abstract
The application provides a method and a device for determining the natural gas density of a condensate gas reservoir stratum, wherein the method comprises the following steps: acquiring the stratum temperature and stratum pressure of a target condensate gas reservoir; obtaining the condensate oil content of the target condensate gas reservoir according to the accumulated production of condensate oil and natural gas of a gas well produced in the target condensate gas reservoir within a set period of time; analyzing a condensate oil sample and a natural gas sample of a wellhead of a production gas well in a target condensate gas reservoir to obtain condensate oil density and condensate oil components of the target condensate gas reservoir and natural gas components under ground standard conditions; and obtaining the formation natural gas density according to the formation temperature, formation pressure, condensate content, condensate density and condensate composition of the target condensate reservoir and the natural gas composition under the ground standard condition. The method can determine the natural gas density of the condensate gas reservoir stratum, and is simple and high in accuracy.
Description
Technical Field
The application relates to the field of oil and gas field exploration and development, in particular to a method and a device for determining the natural gas density of a condensate gas reservoir stratum.
Background
Formation natural gas density is the core parameter for evaluating natural gas volume coefficient, which is in turn the core parameter for evaluating natural gas reserves.
Analysis of natural gas high pressure physical Properties (PVT) samples by laboratory is the most accurate and effective method for obtaining the formation natural gas density, but is difficult to realize for most condensate gas reservoir evaluation units; when the condensate gas reservoir evaluation unit does not have a stratum natural gas density analysis value, the stratum natural gas density is calculated only by analogy or by means of a conventional gas reservoir, the accuracy is low, and an effective method for calculating the stratum natural gas density of the condensate gas reservoir is not provided.
Disclosure of Invention
The embodiment of the application provides a method for determining the natural gas density of a condensate gas reservoir stratum, which is used for determining the natural gas density of the condensate gas reservoir stratum, and is simple in method and high in accuracy, and comprises the following steps:
acquiring the stratum temperature and stratum pressure of a target condensate gas reservoir;
obtaining the condensate oil content of the target condensate gas reservoir according to the accumulated production of condensate oil and natural gas of a gas well produced in the target condensate gas reservoir within a set period of time;
analyzing a condensate oil sample and a natural gas sample of a wellhead of a production gas well in a target condensate gas reservoir to obtain condensate oil density and condensate oil components of the target condensate gas reservoir and natural gas components under ground standard conditions;
and obtaining the formation natural gas density according to the formation temperature, formation pressure, condensate content, condensate density and condensate composition of the target condensate reservoir and the natural gas composition under the ground standard condition.
The embodiment of the application provides a device for determining the natural gas density of a condensate gas reservoir stratum, which is used for determining the natural gas density of the condensate gas reservoir stratum, and has the advantages of simple method and high accuracy, and the device comprises:
a first module for acquiring formation temperature and formation pressure of a target condensate reservoir;
the second module is used for obtaining the condensate oil content of the target condensate gas reservoir according to the accumulated production of the condensate oil and the natural gas of the gas well produced in the target condensate gas reservoir within a set period of time;
the third module is used for analyzing a condensate sample and a natural gas sample at the wellhead of the production gas well in the target condensate gas reservoir to obtain condensate density and condensate components of the target condensate gas reservoir and natural gas components under ground standard conditions;
and the fourth module is used for obtaining the stratum natural gas density according to the stratum temperature, stratum pressure, condensate content, condensate density and condensate composition of the target condensate reservoir and the natural gas composition under the ground standard condition.
The embodiment of the application also provides computer equipment, which comprises a memory, a processor and a computer program stored on the memory and capable of running on the processor, wherein the method for determining the natural gas density of the condensate gas reservoir stratum is realized when the processor executes the computer program.
The embodiment of the application also provides a computer readable storage medium, which stores a computer program for executing the determination of the natural gas density of the condensate gas reservoir stratum.
In the embodiment of the application, the stratum temperature and the stratum pressure of the target condensate gas reservoir are obtained; obtaining the condensate oil content of the target condensate gas reservoir according to the accumulated production of condensate oil and natural gas of a gas well produced in the target condensate gas reservoir within a set period of time; analyzing a condensate oil sample and a natural gas sample of a wellhead of a production gas well in a target condensate gas reservoir to obtain condensate oil density and condensate oil components of the target condensate gas reservoir and natural gas components under ground standard conditions; and obtaining the formation natural gas density according to the formation temperature, formation pressure, condensate content, condensate density and condensate composition of the target condensate reservoir and the natural gas composition under the ground standard condition. In the process, the stratum temperature, stratum pressure, condensate content, condensate density, condensate composition and other easily-obtained parameters of the natural gas composition under the ground standard condition are adopted for the target condensate gas reservoir, so that the stratum natural gas density can be directly obtained; compared with the method for calculating the formation natural gas density by analogy or conventional gas reservoirs, the accuracy of the formation natural gas density determined by the embodiment of the application is high.
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 flow chart of a method of determining natural gas density in a condensate gas reservoir formation in accordance with an embodiment of the present application;
FIG. 2 is a schematic illustration of a holding-Katz plate in accordance with an embodiment of the present application;
FIG. 3 is a detailed flow chart of a method for determining the natural gas density of a condensate reservoir formation according to an embodiment of the present application;
FIG. 4 is a schematic diagram of a condensate reservoir formation natural gas density determination device in accordance with an embodiment of the present application;
fig. 5 is a schematic diagram of a computer device according to an embodiment of the present application.
Detailed Description
For the purpose of making the objects, technical solutions and advantages of the embodiments of the present application more apparent, the embodiments of the present application will be described in further detail with reference to the accompanying drawings. The exemplary embodiments of the present application and their descriptions herein are for the purpose of explaining the present application, but are not to be construed as limiting the application.
In the description of the present specification, the terms "comprising," "including," "having," "containing," and the like are open-ended terms, meaning including, but not limited to. The description of the reference terms "one embodiment," "a particular embodiment," "some embodiments," "for example," etc., means that a particular feature, structure, or characteristic described in connection with the embodiment or example is included in at least one embodiment or example of the application. In this specification, schematic representations of the above terms do not necessarily refer to the same embodiments or examples. Furthermore, the particular features, structures, or characteristics described may be combined in any suitable manner in any one or more embodiments or examples. The order of steps involved in the embodiments is illustrative of the practice of the application, and is not limited and may be suitably modified as desired.
FIG. 1 is a flow chart of a method for determining natural gas density in a condensate gas reservoir formation according to an embodiment of the present application, as shown in FIG. 1, the method comprising:
step 101, acquiring the stratum temperature and stratum pressure of a target condensate gas reservoir;
102, obtaining the condensate content of a target condensate gas reservoir according to the accumulated production of condensate oil and natural gas of a gas well produced in the target condensate gas reservoir within a set period of time;
step 103, analyzing a condensate sample and a natural gas sample of a wellhead of a production gas well in a target condensate reservoir to obtain condensate density and condensate components of the target condensate reservoir and natural gas components under ground standard conditions;
and 104, obtaining the formation natural gas density according to the formation temperature, formation pressure, condensate content, condensate density and condensate composition of the target condensate reservoir and the natural gas composition under the ground standard condition.
In the method provided by the embodiment of the application, the stratum natural gas density can be directly obtained by adopting the stratum temperature, stratum pressure, condensate content, condensate density, condensate composition and other easily-obtained parameters of the natural gas composition under the ground standard condition of the target condensate gas reservoir, and compared with the prior art, the method has the advantages that a natural gas high-pressure physical Property (PVT) sample is not analyzed through a laboratory, and the gas reservoir exploration, development and sampling analysis cost is reduced; compared with the method for calculating the formation natural gas density by analogy or conventional gas reservoirs, the accuracy of the formation natural gas density determined by the embodiment of the application is high.
In specific implementation, in step 101, the formation temperature and the formation pressure of the target condensate gas reservoir need to be obtained, where the target condensate gas reservoir includes a probe well, an evaluation well or a development well, and a production gas well, and the formation temperature and the formation pressure may be obtained by using corresponding test equipment, and in addition, the measured temperature and the measured pressure in the pipeline during gathering and transportation of the natural gas may be obtained as the formation temperature and the formation pressure.
In step 102, obtaining the condensate content of the target condensate reservoir according to the accumulated yields of the condensate and the natural gas of the production gas well in the target condensate reservoir in a set period, wherein the natural gas and the condensate of the production gas well in the target condensate reservoir can be firstly obtained through gas reservoir development equipment and corresponding production modes and are obtained through corresponding storage and transportation equipment, the stable daily yield is analyzed, so that the accumulated yield in the set period is obtained, and then the condensate content of the target condensate reservoir can be obtained, and in one embodiment, the condensate content of the target condensate reservoir is obtained according to the accumulated yields of the condensate and the natural gas of the production gas well in the target condensate reservoir by adopting the following formula;
wherein sigma is condensate oil content, and the unit is cm 3 /m 3 ；N c For cumulative production of condensate in cm for a set period of time 3 ；G g For the cumulative production of natural gas over a set period of time, the unit is m 3 ；V c Is the volume of condensate oil precipitated from natural gas under the standard ground condition, and the unit is cm 3 。
In step 103, the condensate sample and the natural gas sample at the wellhead of the production gas well in the target condensate gas reservoir are required to be analyzed to obtain the condensate density, the condensate component and the natural gas component of the target condensate gas reservoir under the ground standard condition, firstly, the condensate sample and the natural gas sample meeting the analysis requirement are obtained at the wellhead of the production gas well by adopting laboratory sampling equipment, the condensate density, the condensate component and the natural gas component of the target condensate gas reservoir under the ground standard condition are obtained through analysis, the analysis method can adopt corresponding experimental analysis equipment, and related variation examples fall into the protection scope of the application.
Finally, step 104 may be entered to obtain a formation natural gas density based on the formation temperature, formation pressure, condensate content, condensate density and condensate composition of the target condensate reservoir, and the natural gas composition under ground standard conditions. While in particular processes, the process by which formation natural gas density can be obtained from the data described above can be varied, one example of which is set forth below.
In one embodiment, before obtaining the formation natural gas density based on the formation temperature, formation pressure, condensate content, condensate density and condensate composition of the target condensate reservoir, and the natural gas composition at surface standard conditions, further comprising:
according to the natural gas composition under the ground standard condition, the natural gas density and the natural gas molar mass under the ground standard condition are obtained;
obtaining condensate molar mass of the target condensate gas reservoir according to condensate density and condensate components of the target condensate gas reservoir;
determining a gas deviation coefficient according to the stratum temperature, stratum pressure and natural gas composition of the target condensate gas reservoir under the ground standard condition;
obtaining a formation natural gas density according to a formation temperature, a formation pressure, a condensate content, a condensate density and a condensate composition of the target condensate reservoir and a natural gas composition under ground standard conditions, comprising:
and obtaining the stratum natural gas density of the target condensate gas reservoir according to the stratum temperature, stratum pressure, condensate content, condensate density and condensate composition of the target condensate gas reservoir and the natural gas composition under the ground standard condition.
In the above embodiment, the calculation process is simple, and no further experiment is required.
In one embodiment, the following formula is used to obtain the natural gas density and the natural gas molar mass under the ground standard condition according to the natural gas composition under the ground standard condition:
wherein M is g The unit is g/mol of the natural gas molar mass under the ground standard condition; m is M i For the i (i=1, 2,3, …, N) th natural gas component molar mass in g/mol; n is the number of the components of the natural gas; v (V) sc Is 1mol of natural gas in the volume of standard state, V sc ＝2.2413996×10 4 cm 3 /mol；x i The unit is f, which is the mole fraction of the ith natural gas component; ρ g Is the natural gas density under the standard ground condition, and has the unit of g/cm 3 。
In one embodiment, the following formula is adopted to obtain the condensate molar mass of the target condensate reservoir according to the condensate density and condensate composition of the target condensate reservoir:
wherein M is c The unit is g/mol for condensate oil mol mass; m is M k The molar mass of the condensate oil component of the kth (k=1, 2,3, …, N') is expressed in g/mol; is the condensate component category number; x is x k The mole fraction of the kth condensate component is given in f.
By the above examples, the natural gas density and the natural gas molar mass and condensate molar mass under the ground standard conditions were obtained, and then, the gas deviation coefficient was also required to be determined.
In one embodiment, determining the gas deviation factor based on the formation temperature, formation pressure, and natural gas composition at the surface standard conditions of the target condensate reservoir comprises:
and determining a gas deviation coefficient according to the formation temperature, the formation pressure of the target condensate gas reservoir and the natural gas composition under the ground standard condition by combining with a standard-Katz chart.
In the above embodiment, the method for determining the gas deviation coefficient is more accurate and can be intuitively and quickly determined by combining the holding-Katz plate, and fig. 2 is a schematic diagram of the holding-Katz plate in the embodiment of the present application.
In one embodiment, the formation natural gas density of the target condensate gas reservoir is obtained according to the formation temperature, formation pressure, condensate content, condensate density and condensate composition of the target condensate gas reservoir, and the natural gas composition under ground standard conditions using the following formula:
wherein ρ is gf Is the density of the stratum natural gas, and the unit is g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the p is the formation pressure in MPa; z is a gas deviation coefficient, and is dimensionless; t stratum temperature, the unit is K; m is M g The unit is g/mol of the natural gas molar mass under the ground standard condition; ρ g Is the natural gas density under the standard ground condition, and has the unit of g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the Sigma is the condensate content in cm 3 /m 3 The method comprises the steps of carrying out a first treatment on the surface of the R is the molar gas constant, r= 8.314472432J/(mol·k); ρ c Is condensate density in g/cm 3 ；M c The unit is g/mol for condensate molar mass.
The derivation of the above formula is as follows:
according to a gas state equation under stratum conditions;
pV gf ＝nRZT (6)
wherein n is the mole number of natural gas under stratum conditions, and the unit is mol; v (V) gf Is the volume of natural gas under formation conditions, m3.
The number of moles of natural gas under formation conditions is equal to the sum of the number of moles of natural gas under ground standard conditions and the number of moles of gas of the condensate prior to precipitation:
wherein m is g Is the quality of natural gas under the ground standard conditionThe unit is g; n is n sc The unit is mol of natural gas under the ground standard condition; Δm c The unit is g of the mass of condensate oil precipitated under the ground standard condition; delta n is the number of moles of gas state of condensate prior to precipitation in moles.
The difference between the natural gas mass under the stratum condition and the natural gas mass under the ground standard condition is equal to the mass of condensate oil precipitated under the ground standard condition:
Δm c ＝m gf -m g (8)
wherein m is gf Is the mass of natural gas under the formation condition, and the unit is g.
The mass calculation formula of the natural gas under the stratum condition is as follows:
m gf ＝V gf ρ gf (9)
wherein ρ is gf Is the natural gas density under the formation condition, namely the formation natural gas density, and the unit is g/cm 3 。
The natural gas molar mass and condensate molar mass are calculated as follows:
wherein M is i For the i (i=1, 2,3, …, N) th natural gas component molar mass in g/mol; m is M k The molar mass of the condensate oil component of the kth (k=1, 2,3, …, N') is expressed in g/mol; n is the number of the components of the natural gas; n' is the number of condensate component types; x is x i The unit is f for the mole fraction of the i (i=1, 2,3, …, N) th natural gas component; x is x k Is the mole fraction of the kth (k=1, 2,3, …, N') condensate component, in f.
The formation natural gas density is obtained by the simultaneous equations (6), (7), (8) and (9):
in the formula (12), the relationship between the ratio of the natural gas mass under the ground standard condition to the natural gas mass under the stratum condition and the ground natural gas density, the condensate density and the condensate content is as follows:
and (3) combining the formula (12) and the formula (13) to obtain the stratum natural gas density calculation formula (5).
Based on the above embodiments, the present application proposes the following embodiment to describe a detailed flow of a method for determining a natural gas density of a condensate gas reservoir stratum, and fig. 3 is a detailed flow chart of a method for determining a natural gas density of a condensate gas reservoir stratum according to an embodiment of the present application, including:
step 301, acquiring the formation temperature and formation pressure of a target condensate gas reservoir;
step 302, obtaining the condensate content of the target condensate reservoir according to the accumulated production of condensate and natural gas of a gas well produced in the target condensate reservoir within a set period of time;
step 303, analyzing a condensate sample and a natural gas sample of a wellhead of a production gas well in a target condensate reservoir to obtain condensate density and condensate components of the target condensate reservoir and natural gas components under ground standard conditions;
step 304, obtaining the natural gas density and the natural gas molar mass under the ground standard condition according to the natural gas component under the ground standard condition;
step 305, obtaining condensate molar mass of the target condensate reservoir according to condensate density and condensate component of the target condensate reservoir;
step 306, determining a gas deviation coefficient according to the stratum temperature, stratum pressure and natural gas composition of the target condensate reservoir under the ground standard condition by combining with a setting-Katz chart;
step 307, obtaining the stratum natural gas density of the target condensate gas reservoir according to the stratum temperature, stratum pressure, condensate content, condensate density and condensate composition of the target condensate gas reservoir and the natural gas composition under the ground standard condition.
Of course, it is to be understood that other variations of the above detailed procedures are also possible, and all related variations should fall within the protection scope of the present application.
A specific example is given below to illustrate a specific application of the condensate reservoir formation natural gas density determination method.
The method is characterized in that a Xinglong platform oil field Magu down-the-hole mountain Magu 1 well of a target condensate gas reservoir is used as a production gas well, and the well has condensate gas high-pressure physical property analysis data. The gas-bearing layer of the Magu 1 well is of the Taigu world; the burial depth of the gas layer is 3884.83-4081.02m; the formation temperature was 399.15K (126 ℃); the formation pressure is 43.8MPa; the density of the ground condensate is 0.7816g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the The condensate oil content is 353cm 3 /m 3 The method comprises the steps of carrying out a first treatment on the surface of the A natural gas volume coefficient 0.003597 (natural gas volume conversion coefficient 278.0); actual analysis of formation Natural gas Density 0.267276g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the The analysis of the components of the ground natural gas and the components of the condensate oil are shown in the table 1 in detail.
TABLE 1 Natural gas Components and condensate Components
The natural gas density of the stratum of the Magu 1 well is calculated by adopting a formula (5):
actual analysis of stratum natural gas density of Malu 1 well is 0.267276g/cm 3 And (5) calculating the formation natural gas density to be 0 by using the formula (5).278607g/cm 3 Absolute error of 0.01133g/cm 3 The relative error is 4.24%, and the calculation accuracy is 95.76%; the natural gas density of the stratum is 0.216407g/cm calculated by the conventional method 3 Absolute error of 0.050869g/cm 3 The relative error was 19.03% and the calculation accuracy was only 80.97%.
Therefore, the method and the device for calculating the natural gas density of the condensate gas reservoir stratum have the advantages of high accuracy, low cost, simplicity and convenience in calculation, strong practicability and wide popularization and application values.
In summary, in the method provided by the embodiment of the present application, the formation temperature and the formation pressure of the target condensate gas reservoir are obtained; obtaining the condensate oil content of the target condensate gas reservoir according to the accumulated production of condensate oil and natural gas of a gas well produced in the target condensate gas reservoir within a set period of time; analyzing a condensate oil sample and a natural gas sample of a wellhead of a production gas well in a target condensate gas reservoir to obtain condensate oil density and condensate oil components of the target condensate gas reservoir and natural gas components under ground standard conditions; and obtaining the formation natural gas density according to the formation temperature, formation pressure, condensate content, condensate density and condensate composition of the target condensate reservoir and the natural gas composition under the ground standard condition. In the process, the stratum temperature, stratum pressure, condensate content, condensate density, condensate composition and other easily-obtained parameters of the natural gas composition under the ground standard condition are adopted for the target condensate gas reservoir, so that the stratum natural gas density can be directly obtained; compared with the method for calculating the formation natural gas density by analogy or conventional gas reservoirs, the accuracy of the formation natural gas density determined by the embodiment of the application is high. In addition, the method for calculating the natural gas density of the condensate gas reservoir stratum by adopting the embodiment of the application has the advantages of high precision, simple and convenient calculation, strong practicability and wide popularization and application values.
The embodiment of the application also provides a device for determining the natural gas density of the condensate gas reservoir stratum, the principle of which is similar to that of the condensate gas reservoir stratum, and the method is not repeated here.
FIG. 4 is a schematic view of a natural gas density determining apparatus for a condensate gas reservoir formation according to an embodiment of the present application, as shown in FIG. 4, the apparatus comprising:
a first module 401 for acquiring a formation temperature and a formation pressure of a target condensate reservoir;
a second module 402, configured to obtain a condensate content of the target condensate reservoir according to a cumulative production of condensate and natural gas from a production gas well in the target condensate reservoir for a set period of time;
a third module 403, configured to analyze a condensate sample and a natural gas sample at a wellhead of a production gas well in a target condensate reservoir, to obtain a condensate density and a condensate component of the target condensate reservoir, and a natural gas component under ground standard conditions;
a fourth module 404 is configured to obtain a formation natural gas density based on the formation temperature, formation pressure, condensate content, condensate density, and condensate composition of the target condensate reservoir, and the natural gas composition under ground standard conditions.
In an embodiment, the apparatus further comprises a fifth module 405 for: according to the natural gas composition under the ground standard condition, the natural gas density and the natural gas molar mass under the ground standard condition are obtained;
a sixth module 406 for: obtaining condensate molar mass of the target condensate gas reservoir according to condensate density and condensate components of the target condensate gas reservoir;
a seventh module 407 for: determining a gas deviation coefficient according to the stratum temperature, stratum pressure and natural gas composition of the target condensate gas reservoir under the ground standard condition;
the fourth module 404 is specifically configured to: and obtaining the stratum natural gas density of the target condensate gas reservoir according to the stratum temperature, stratum pressure, condensate content, condensate density and condensate composition of the target condensate gas reservoir and the natural gas composition under the ground standard condition.
In one embodiment, the seventh module 407 is specifically configured to:
and determining a gas deviation coefficient according to the formation temperature, the formation pressure of the target condensate gas reservoir and the natural gas composition under the ground standard condition by combining with a standard-Katz chart.
In summary, in the device provided by the embodiment of the application, the formation temperature and the formation pressure of the target condensate gas reservoir are obtained; obtaining the condensate oil content of the target condensate gas reservoir according to the accumulated production of condensate oil and natural gas of a gas well produced in the target condensate gas reservoir within a set period of time; analyzing a condensate oil sample and a natural gas sample of a wellhead of a production gas well in a target condensate gas reservoir to obtain condensate oil density and condensate oil components of the target condensate gas reservoir and natural gas components under ground standard conditions; and obtaining the formation natural gas density according to the formation temperature, formation pressure, condensate content, condensate density and condensate composition of the target condensate reservoir and the natural gas composition under the ground standard condition. In the process, the stratum temperature, stratum pressure, condensate content, condensate density, condensate composition and other easily-obtained parameters of the natural gas composition under the ground standard condition are adopted for the target condensate gas reservoir, so that the stratum natural gas density can be directly obtained; compared with the method for calculating the formation natural gas density by analogy or conventional gas reservoirs, the accuracy of the formation natural gas density determined by the embodiment of the application is high. In addition, the method for calculating the natural gas density of the condensate gas reservoir stratum by adopting the embodiment of the application has the advantages of high precision, simple and convenient calculation, strong practicability and wide popularization and application values.
An embodiment of the present application further provides a computer device, and fig. 5 is a schematic diagram of the computer device in the embodiment of the present application, where the computer device can implement all the steps in the method for determining a natural gas density of a condensate gas reservoir stratum in the foregoing embodiment, and the electronic device specifically includes the following contents:
a processor (processor) 501, a memory (memory) 502, a communication interface (Communications Interface) 503, and a bus 504;
wherein the processor 501, the memory 502, and the communication interface 503 perform communication with each other through the bus 504; the communication interface 503 is configured to implement information transmission between related devices such as a server device, a detection device, and a user device;
the processor 501 is configured to invoke a computer program in the memory 502, where execution of the computer program by the processor implements all the steps in the condensate gas reservoir formation natural gas density determination method in the above embodiment.
An embodiment of the present application also provides a computer readable storage medium, which can implement all the steps in the method for determining the natural gas density of the condensate gas reservoir stratum in the above embodiment, and the computer readable storage medium stores a computer program, where the computer program is executed by a processor, to implement all the steps in the method for determining the natural gas density of the condensate gas reservoir stratum in the above embodiment.
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 (14)
1. A method of determining the natural gas density of a condensate gas reservoir formation, comprising:
acquiring the stratum temperature and stratum pressure of a target condensate gas reservoir;
obtaining the condensate oil content of the target condensate gas reservoir according to the accumulated production of condensate oil and natural gas of a gas well produced in the target condensate gas reservoir within a set period of time;
analyzing a condensate oil sample and a natural gas sample of a wellhead of a production gas well in a target condensate gas reservoir to obtain condensate oil density and condensate oil components of the target condensate gas reservoir and natural gas components under ground standard conditions;
obtaining the stratum natural gas density of the target condensate gas reservoir according to the stratum temperature, stratum pressure, condensate content, condensate density and condensate composition of the target condensate gas reservoir and the natural gas composition under the ground standard condition;
before obtaining the formation natural gas density of the target condensate reservoir, further comprising:
according to the natural gas composition under the ground standard condition, the natural gas density and the natural gas molar mass under the ground standard condition are obtained;
obtaining condensate molar mass of the target condensate gas reservoir according to condensate density and condensate components of the target condensate gas reservoir;
determining a gas deviation coefficient according to the stratum temperature, stratum pressure and natural gas composition of the target condensate gas reservoir under the ground standard condition;
obtaining a formation natural gas density according to a formation temperature, a formation pressure, a condensate content, a condensate density and a condensate composition of the target condensate reservoir and a natural gas composition under ground standard conditions, comprising:
and obtaining the natural gas density of the stratum according to the stratum temperature, stratum pressure, condensate content, condensate density, natural gas density and natural gas molar mass under the ground standard conditions, condensate molar mass and gas deviation coefficient of the target condensate reservoir.
2. The method for determining the natural gas density of a condensate reservoir formation of claim 1, wherein determining the gas deviation factor based on the formation temperature, formation pressure, and natural gas composition of the target condensate reservoir at ground standard conditions comprises:
and determining a gas deviation coefficient according to the formation temperature, the formation pressure of the target condensate gas reservoir and the natural gas composition under the ground standard condition by combining with a standard-Katz chart.
3. The method for determining the natural gas density of the condensate gas reservoir stratum according to claim 1, wherein the condensate gas content of the target condensate gas reservoir is obtained according to the accumulated production of condensate gas and natural gas of a production gas well in the target gas reservoir within a set period of time by adopting the following formula;
wherein sigma is condensate oil content, and the unit is cm 3 /m 3 ；N c For cumulative production of condensate in cm for a set period of time 3 ；G g For the cumulative production of natural gas over a set period of time, the unit is m 3 ；V c Is the volume of condensate oil precipitated from natural gas under the standard ground condition, and the unit is cm 3 。
4. The method for determining the natural gas density of a condensate gas reservoir formation according to claim 1, wherein the natural gas density and the natural gas molar mass under the ground standard condition are obtained from the natural gas composition under the ground standard condition using the following formula:
wherein M is g The unit is g/mol of the natural gas molar mass under the ground standard condition; m is M i Is i (i=1, 2,3, ··, N) the molar mass of the natural gas component, the unit is g/mol; n is the number of the components of the natural gas; v (V) sc Is 1mol of natural gas in the volume of standard state, V sc ＝2.2413996×10 4 cm 3 /mol；x i The unit is f, which is the mole fraction of the ith natural gas component; ρ g Is the natural gas density under the standard ground condition, and has the unit of g/cm 3 。
5. The method for determining the natural gas density of a condensate gas reservoir stratum according to claim 1, wherein the condensate gas molar mass of the target condensate gas reservoir is obtained according to the condensate gas density and condensate gas composition of the target condensate gas reservoir by adopting the following formula:
wherein M is c The unit is g/mol for condensate oil mol mass; m is M k Is k (k=1, 2,3, ··, N') the molar mass of the condensate oil component is expressed in g/mol; is the condensate component category number; x is x k The mole fraction of the kth condensate component is given in f.
6. The method for determining the natural gas density of the condensate gas reservoir stratum according to claim 1, wherein the stratum natural gas density is obtained according to the stratum temperature, stratum pressure, condensate gas content, condensate gas density, natural gas density and natural gas molar mass under ground standard conditions, condensate gas molar mass and gas deviation coefficient of the target condensate gas reservoir by adopting the following formula:
wherein ρ is gf Is the density of the stratum natural gas, and the unit is g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the p is the formation pressure in MPa; z is a gas deviation coefficient, and is dimensionless; t stratum temperature, the unit is K; m is M g The unit is g/mol of the natural gas molar mass under the ground standard condition; ρ g Is the natural gas density under the standard ground condition, and has the unit of g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the Sigma is the condensate content in cm 3 /m 3 The method comprises the steps of carrying out a first treatment on the surface of the R is the molar gas constant, r= 8.314472432J/(mol·k); ρ c Is condensate density in g/cm 3 ；M c The unit is g/mol for condensate molar mass.
7. A condensate gas reservoir formation natural gas density determination apparatus, comprising:
a first module for acquiring formation temperature and formation pressure of a target condensate reservoir;
the second module is used for obtaining the condensate oil content of the target condensate gas reservoir according to the accumulated production of the condensate oil and the natural gas of the gas well produced in the target condensate gas reservoir within a set period of time;
the third module is used for analyzing a condensate sample and a natural gas sample at the wellhead of the production gas well in the target condensate gas reservoir to obtain condensate density and condensate components of the target condensate gas reservoir and natural gas components under ground standard conditions;
a fourth module for obtaining a formation natural gas density according to the formation temperature, formation pressure, condensate content, condensate density and condensate composition of the target condensate reservoir, and a natural gas composition under ground standard conditions;
further comprising a fifth module for: according to the natural gas composition under the ground standard condition, the natural gas density and the natural gas molar mass under the ground standard condition are obtained;
a sixth module for: obtaining condensate molar mass of the target condensate gas reservoir according to condensate density and condensate components of the target condensate gas reservoir;
a seventh module for: determining a gas deviation coefficient according to the stratum temperature, stratum pressure and natural gas composition of the target condensate gas reservoir under the ground standard condition;
the fourth module is specifically configured to: and obtaining the natural gas density of the stratum according to the stratum temperature, stratum pressure, condensate content, condensate density, natural gas density and natural gas molar mass under the ground standard conditions, condensate molar mass and gas deviation coefficient of the target condensate reservoir.
8. The condensate gas reservoir formation natural gas density determination apparatus of claim 7, wherein the seventh module is specifically configured to:
and determining a gas deviation coefficient according to the formation temperature, the formation pressure of the target condensate gas reservoir and the natural gas composition under the ground standard condition by combining with a standard-Katz chart.
9. The condensate gas reservoir formation natural gas density determination apparatus of claim 7, wherein the second module is specifically configured to:
the condensate oil content of the target condensate gas reservoir is obtained according to the accumulated production of condensate oil and natural gas of a gas well produced in the target gas reservoir within a set period of time by adopting the following formula;
wherein sigma is condensate oil content, and the unit is cm 3 /m 3 ；N c For cumulative production of condensate in cm for a set period of time 3 ；G g For the cumulative production of natural gas over a set period of time, the unit is m 3 ；V c Is the volume of condensate oil precipitated from natural gas under the standard ground condition, and the unit is cm 3 。
10. The condensate gas reservoir formation natural gas density determination apparatus of claim 7, wherein the fifth module is specifically configured to:
the natural gas density and the natural gas molar mass under the ground standard condition are obtained according to the natural gas composition under the ground standard condition by adopting the following formula:
wherein M is g The unit is g/mol of the natural gas molar mass under the ground standard condition; m is M i Is i (i=1, 2,3, ··, N) the molar mass of the natural gas component, the unit is g/mol; n is the number of the components of the natural gas; v (V) sc Is 1mol of natural gas in the volume of standard state, V sc ＝2.2413996×10 4 cm 3 /mol；x i The unit is f, which is the mole fraction of the ith natural gas component; ρ g Is the natural gas density under the standard ground condition, and has the unit of g/cm 3 。
11. The condensate gas reservoir formation natural gas density determination apparatus of claim 9, wherein the sixth module is specifically configured to:
the condensate molar mass of the target condensate reservoir is obtained according to the condensate density and condensate components of the target condensate reservoir by adopting the following formula:
wherein M is c The unit is g/mol for condensate oil mol mass; m is M k Is k (k=1, 2,3, ··, N') the molar mass of the condensate oil component is expressed in g/mol; is the condensate component category number; x is x k The mole fraction of the kth condensate component is given in f.
12. The condensate gas reservoir formation natural gas density determination apparatus of claim 9, wherein the fourth module is specifically configured to:
the formation natural gas density of the target condensate gas reservoir is obtained according to the formation temperature, formation pressure, condensate content, condensate density and condensate composition of the target condensate gas reservoir and the natural gas composition under the ground standard condition by adopting the following formula:
wherein ρ is gf Is the density of the stratum natural gas, and the unit is g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the p is the formation pressure in MPa; z is a gas deviation coefficient, and is dimensionless; t stratum temperature, the unit is K; m is M g The unit is g/mol of the natural gas molar mass under the ground standard condition; ρ g Is the natural gas density under the ground standard condition,the unit is g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the Sigma is the condensate content in cm 3 /m 3 The method comprises the steps of carrying out a first treatment on the surface of the R is the molar gas constant, r= 8.314472432J/(mol·k); ρ c Is condensate density in g/cm 3 ；M c The unit is g/mol for condensate molar mass.
13. 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 any of claims 1 to 6 when executing the computer program.
14. A computer readable storage medium, characterized in that the computer readable storage medium stores a computer program for executing the method of any one of claims 1 to 6.
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| CN1971273A (en) * | 2006-12-12 | 2007-05-30 | 中国石油天然气股份有限公司 | Testing method of constant volume exhaustion of fluid in condensate gas reservoir |
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