CN112746839B - Method and device for determining volume coefficient of crude oil - Google Patents
Method and device for determining volume coefficient of crude oil Download PDFInfo
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- 239000010779 crude oil Substances 0.000 title claims abstract description 333
- 238000000034 method Methods 0.000 title claims abstract description 43
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 110
- 239000003921 oil Substances 0.000 claims abstract description 72
- 238000007872 degassing Methods 0.000 claims abstract description 31
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- 238000005070 sampling Methods 0.000 claims abstract description 10
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Abstract
The invention provides a new method and a device for evaluating the volume coefficient of crude oil, which comprises the following steps: obtaining the density of the dissolved gas, the formation temperature and the density of the de-aerated crude oil corresponding to the formation temperature; generating formation crude oil density corresponding to the formation type according to the formation temperature and the density of the de-aerated crude oil corresponding to the formation temperature; establishing a general model of crude oil volume coefficient according to the stratum crude oil density and the degassing crude oil density; inputting the numerical values of the stratum crude oil density and the degassing crude oil density into a model to obtain the crude oil volume coefficient. The general equation of the crude oil volume coefficient and the simplified crude oil volume coefficient formula are objectively established by adopting parameters such as measured stratum temperature, ground degassing crude oil density, dissolved gas-oil ratio and the like corresponding to the oil deposit burial depth. The determination method not only reduces the cost of exploration, development, sampling and analysis, but also ensures that the calculated crude oil volume coefficient can meet the precision requirement of three-level reserve evaluation, and is a simple and efficient crude oil volume coefficient determination method.
Description
Technical Field
The application belongs to the field of petroleum exploration and development, and particularly relates to an evaluation method of crude oil volume coefficient.
Background
The crude oil volume factor refers to the ratio of the volume of petroleum under formation conditions to the volume of de-aerated crude oil under surface conditions:
in B of oi Representing the volume coefficient of crude oil, and having no dimension; v (V) of Represents the volume of petroleum in units of m under formation conditions 3 ；V o Represents the volume of the crude oil in unit m 3 。
Obtaining crude oil volume coefficients by in-situ sampling analysis is the most accurate and effective method at present, but is difficult to realize for most oil reservoirs or evaluation units; when the evaluation unit does not have an actual crude oil volume coefficient analysis value, the crude oil volume coefficient of the oil reservoir similar to the evaluation unit is generally selected after analog analysis is performed on the parameters related to known oil reservoir geological conditions, crude oil properties and the like, or the crude oil volume coefficient is calculated by using an empirical formula.
The existing empirical formula is to perform regression analysis by using the in-situ measured crude oil volume coefficient and crude oil characteristic parameters, for example, the relationship is established between the original dissolved gas-oil ratio, deltaB (intermediate parameter related to the original dissolved gas-oil ratio) and the like, and the original dissolved gas-oil ratio is a very acquired parameter, so that the crude oil volume coefficient can be accurately obtained as long as the accurate original dissolved gas-oil ratio can be acquired, because the original dissolved gas-oil ratio has very good correlation with the crude oil volume coefficient. The existing empirical formula has good effect on calculating the volume coefficient of crude oil in the corresponding region, but the empirical formula lacks theoretical basis, has application limitation and limited precision.
Disclosure of Invention
The application provides an evaluation method of crude oil volume coefficient, which at least solves the problem that the crude oil volume coefficient is difficult to obtain during evaluation of various oil reservoir resources/reserves in the prior art.
According to one aspect of the present application, there is provided a novel method of evaluating crude oil volume coefficients, comprising:
obtaining the density of the dissolved gas, the formation temperature and the density of the de-aerated crude oil corresponding to the formation temperature;
generating formation crude oil density corresponding to the formation type according to the formation temperature and the density of the de-aerated crude oil corresponding to the formation temperature, wherein the formation type comprises: saturated sandstone reservoir formations and former new kingdom and high pour point oil unsaturated reservoir formations;
establishing a general model of crude oil volume coefficient according to the stratum crude oil density and the degassing crude oil density;
inputting the numerical values of the stratum crude oil density and the degassing crude oil density into a model to obtain the crude oil volume coefficient.
In one embodiment, after obtaining the general equation for the volumetric coefficient of crude oil, the method further comprises:
and carrying out oil exploration and oil reservoir development according to the volume coefficient of crude oil.
In one embodiment, establishing a general model of crude oil volume coefficients based on formation crude oil density, de-aerated crude oil density, comprises:
generating a crude oil volume coefficient by using the formation crude oil density, the de-aerated crude oil density, the formation crude oil mass and the de-aerated crude oil mass;
establishing a stratum crude oil quality model according to the dissolved gas-oil ratio, the quality of the dead crude oil, the dissolved gas density and the density of the dead crude oil;
and establishing a general model of the crude oil volume coefficient according to the crude oil volume coefficient and the stratum crude oil quality model.
In one embodiment, modeling formation crude oil quality based on dissolved gas to oil ratio, quality of the de-aerated crude oil, dissolved gas density, and density of the de-aerated crude oil, comprises:
generating a stratum crude oil quality first model according to the dissolved gas volume, the dissolved gas density and the quality of the degassed crude oil;
generating a dissolved gas volume model according to the dissolved gas-oil ratio and the volume of the de-aerated crude oil;
and establishing a stratum crude oil quality model according to the stratum crude oil quality first model and the dissolved gas volume model.
According to another aspect of the present application, there is also provided a device for determining a volumetric coefficient of crude oil, including:
the sampling unit is used for obtaining the density of the dissolved gas, the formation temperature and the density of the de-aerated crude oil corresponding to the formation temperature;
the formation crude oil density calculation unit is used for generating formation crude oil density corresponding to the formation type according to the formation temperature and the degassing crude oil density corresponding to the formation temperature, and the formation type comprises: saturated sandstone reservoir formations and former new kingdom and high pour point oil unsaturated reservoir formations;
the general model building unit is used for building a general model of crude oil volume coefficient according to the stratum crude oil density and the de-aerated crude oil density;
the crude oil volume coefficient calculation unit is used for inputting the numerical values of the stratum crude oil density and the degassing crude oil density into the model to obtain the crude oil volume coefficient.
In one embodiment, the apparatus further comprises:
the application unit is used for carrying out oil exploration and oil reservoir development according to the crude oil volume coefficient.
In an embodiment, the generic model building unit comprises:
the crude oil volume coefficient generation module is used for generating a crude oil volume coefficient by utilizing the stratum crude oil density, the degassing crude oil density, the stratum crude oil quality and the degassing crude oil quality;
the quality model building module is used for building a stratum crude oil quality model according to the dissolved gas-oil ratio, the quality of the de-aerated crude oil, the dissolved gas density and the density of the de-aerated crude oil;
and the first merging module is used for establishing a general model of the crude oil volume coefficient according to the crude oil volume coefficient and the stratum crude oil quality model.
In one embodiment, the quality model building module includes:
the first model building module is used for generating a stratum crude oil quality first model according to the dissolved gas volume, the dissolved gas density and the quality of the degassed crude oil;
the volume model building module is used for generating a dissolved gas volume model according to the dissolved gas-oil ratio and the volume of the de-aerated crude oil;
and the second merging module is used for establishing a stratum crude oil quality model according to the stratum crude oil quality first model and the dissolved gas volume model.
In order to reduce the high-pressure physical sampling analysis cost of the reserves evaluation block or the objective reality that the high-pressure physical sampling cannot be carried out and reduce the oil reservoir exploration and development investment, the crude oil volume coefficient evaluation method is established through actually measuring the stratum temperature corresponding to the oil reservoir burial depth, the ground degassing crude oil density and other easily-obtained parameters, so that the problem that the crude oil volume coefficient is difficult to obtain during oil reservoir resource/reserves evaluation and oil reservoir engineering design is solved.
Drawings
In order to more clearly illustrate the embodiments of the invention 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 invention, and that 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 determining a volumetric coefficient of crude oil provided by the present application.
FIG. 2 is a flow chart for establishing a general model of crude oil volume coefficients based on formation crude oil density and de-aerated crude oil density as provided herein.
FIG. 3 is a flow chart for modeling the quality of crude oil in a formation provided herein.
Fig. 4 is a block diagram of a device for determining a volumetric coefficient of crude oil according to the present application.
Fig. 5 is a specific implementation of an electronic device in an embodiment of the present application.
Detailed Description
The following description of the embodiments of the present invention will be made clearly and completely with reference to the accompanying drawings, in which it is apparent that the embodiments described are only some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
In the existing oil reservoir exploration and development process, the crude oil volume coefficient is not easy to realize by on-site sampling analysis, so that the crude oil volume coefficient similar to an oil reservoir is usually adopted or an empirical formula is used for calculating the crude oil volume coefficient, however, the crude oil volume coefficient is usually regional by adopting the empirical formula, the empirical formula lacks a theoretical basis, and the problems of poor universality, low accuracy of the obtained crude oil volume coefficient and the like are easily caused. Based on the above problems, the present application solves the problems of high cost of obtaining the crude oil volume coefficient by PVT sampling analysis of the oil reservoir evaluation unit, and low accuracy of obtaining by analogy or empirical formula, and provides a new determination method for the crude oil volume coefficient, as shown in fig. 1, specifically comprising the following steps:
and acquiring the vertical depth (D) of the target layer and the stratum temperature (t) by adopting corresponding testing equipment after the exploratory well, the evaluation well or the development well of the target oil reservoir is drilled.
S101: and obtaining the density of the dissolved gas, the formation temperature and the density of the de-aerated crude oil corresponding to the formation temperature.
And (3) extracting stratum crude oil and natural gas (dissolved gas) in the target oil reservoir according to oil field development equipment and corresponding production modes, wherein the stratum crude oil is formed by mixing the deaerated crude oil and the dissolved gas.
The laboratory sampling equipment is adopted to obtain stratum crude oil samples and natural gas samples meeting the experimental analysis requirements at a wellhead, and then the corresponding experimental analysis equipment is adopted to obtain the density (rho) of the de-aerated crude oil according to the samples o ) And dissolved gas density (ρ) g )。
S102: generating formation crude oil density corresponding to the formation type according to the formation temperature and the density of the de-aerated crude oil corresponding to the formation temperature, wherein the formation type comprises: saturated sandstone reservoir formations and pre-new kingdom and high-pour-point oil unsaturated reservoir formations.
Based on the formation temperature (t) obtained in step S101 and the obtained surface degassed crude oil density (ρ o ) The formation crude oil density (ρ) is calculated using the formulas currently in common use in the art of )：
According to the geological type of the stratum in actual condition, if the stratum is a saturated sandstone oil reservoir, adopting a saturated sandstone oil reservoir stratum crude oil density calculation formula:
ρ of ＝1.7527ρ ot -0.7298，(n＝280,r＝0.9380)
wherein ρ is of Represents the density of crude oil in stratum, g/cm 3 ；
ρ ot Represents the density, g/cm, of the de-aerated crude oil corresponding to the formation temperature t 3 。
The formation crude oil density of the saturated sandstone oil reservoir can be obtained according to the formula;
if the geological type is a pre-new kingdom and a high pour point unsaturated oil reservoir, adopting a stratum crude oil density calculation formula of the pre-new kingdom and the high pour point unsaturated oil reservoir:
ρ of ＝0.7997ρ ot +0.1855，(n＝44,r＝0.90896)
ρ ot ＝ρ o +(13.560-0.191ξ)×10 -3 -(63.900-0.870ξ)×10 -5 t 1.02
ξ＝INT[100(ρ o -0.8001)]
in the formula, INT represents a rounding function;
ζ represents the density modulus of the degassed crude oil;
ρ o represents the density, g/cm, of the ground degassing crude oil 3 。
S103: and establishing a general model of the crude oil volume coefficient according to the stratum crude oil density and the degassing crude oil density.
The definition of the volume coefficient of crude oil is: ratio of petroleum volume under formation conditions to volume of crude oil removed under surface conditions:
in B of oi Representing the volume coefficient of crude oil, and having no dimension;
V of represents the volume of crude oil in stratum, m 3 ；
V o Represents the volume of the degassed crude oil, m 3 。
Thus, from the density of the de-aerated crude, the density of the formation crude, and from the definition of the crude volume factor and the density, mass, volume relation of the material, it is possible to obtain:
wherein m represents the mass of crude oil in the stratum and g;
m o indicating the quality (m) of the degassed crude oil o ≤m)，g。
The general model of the crude oil volume coefficient can be obtained according to the common physical relationship and the physical definition of the crude oil volume coefficient.
S104: inputting the numerical values of the stratum crude oil density and the degassing crude oil density into a model to obtain the crude oil volume coefficient.
After the general model of the crude oil volume coefficient is obtained in the step S103, the actual data obtained in the petroleum exploration is input into the general model, and the crude oil volume coefficient required in the petroleum exploration can be obtained. After the crude oil volume coefficient model is obtained by the method, the model is applied to the actual petroleum exploration field, so that the petroleum exploration precision can be improved, more accurate exploitation can be realized, the exploration cost can be reduced, and more accurate petroleum exploitation technical effects can be obtained.
In the implementation of the invention, after the general equation of the crude oil volume coefficient is obtained, oil exploration and oil reservoir development can be carried out according to the crude oil volume coefficient.
In one embodiment, as shown in FIG. 2, the general model of crude oil volume coefficients is built based on formation crude oil density, de-aerated crude oil density, comprising:
s201: and generating a crude oil volume coefficient by using the stratum crude oil density, the degassing crude oil density, the stratum crude oil quality and the degassing crude oil quality.
From the density of the de-aerated crude oil, the density of the formation crude oil, and from the definition of the crude oil volume coefficient and the density, mass and volume relation of the substance, the following formula can be obtained:
wherein m represents the mass of crude oil in the stratum and g;
m o indicating the quality (m) of the degassed crude oil o ≤m)，g。
S202: and establishing a stratum crude oil quality model according to the dissolved gas-oil ratio, the quality of the dead crude oil, the dissolved gas density and the density of the dead crude oil.
The difference in crude oil mass before and after degassing is equal to the mass (. DELTA.m) of the dehydrated gas (dissolved gas) g )：
m＝m o +Δm g
Δm g ＝V g ρ g
Wherein V is g Represents the volume of gas (dissolved gas) removed from petroleum under ground conditions, m 3 ；
ρ g Represents the density of gas (dissolved gas) evolved from petroleum at ground conditions, g/cm 3 ；
Δm g And g represents the mass of gas (dissolved gas) evolved from petroleum under surface conditions.
Thus, m=m can be obtained from the formula in S202 o +V g ρ g 。
After the stratum crude oil quality model is obtained, stable daily oil production data and stable daily gas production data and corresponding accumulated yield data of the wellhead of the oil well are obtained through corresponding storage and transportation equipment, and the dissolved gas-oil ratio of the oil well production can be obtained according to the data:
the volume of natural gas dissolved by a unit volume of crude oil under ground conditions under stratum conditions is called dissolved gas-oil ratio, and the mathematical expression is:
V o the volume of the crude oil in the stratum is obtained.
Thus, it can be obtained that V g ＝R si V o From this, the relationship of the dissolved gas-oil ratio, the quality of the crude oil, the dissolved gas density, and the density of the crude oil in the removed gas and the quality of the crude oil in the formation can be further obtained, thereby establishing the following model of the quality of the crude oil in the formation:
m＝R si V O ρ g +m o
s203: and establishing a general model of the crude oil volume coefficient according to the crude oil volume coefficient and the stratum crude oil quality model.
And (3) utilizing the crude oil volume coefficient in the step S201 and the stratum crude oil quality model obtained in the step S202 to transform, fuse and combine the two to obtain a crude oil volume coefficient universal model.
In one embodiment, modeling the formation crude oil quality based on the dissolved gas to oil ratio, the quality of the de-aerated crude oil, the dissolved gas density, and the de-aerated crude oil density, as shown in FIG. 3, includes:
s301: and generating a stratum crude oil quality first model according to the dissolved gas volume, the dissolved gas density and the quality of the degassed crude oil.
In one embodiment, a first model of formation crude oil quality is generated based on dissolved gas volume, dissolved gas density, and de-aerated crude oil quality:
the difference in crude oil mass before and after degassing is equal to the mass (. DELTA.m) of the dehydrated gas (dissolved gas) g )：
m＝m o +Δm g
Δm g ＝V g ρ g
V in g Represents the volume of gas (dissolved gas) removed from petroleum under ground conditions, m 3 ；
ρ g Represents the density of gas (dissolved gas) evolved from petroleum at ground conditions, g/cm 3 ；
Δm g And g represents the mass of gas (dissolved gas) evolved from petroleum under surface conditions.
Thus, the first model of formation crude oil quality is: m=m o +V g ρ g 。
S302: and generating a dissolved gas volume model according to the dissolved gas-oil ratio and the volume of the degassed crude oil.
The volume model of the dissolved gas generated according to the dissolved gas-oil ratio and the volume of the crude oil is as follows:
V g ＝R si V o
s303: and establishing a stratum crude oil quality model according to the stratum crude oil quality first model and the dissolved gas volume model.
The formation crude oil quality model and the crude oil volume coefficient expression are combined to obtain:
this is the general model of crude oil volume coefficient.
However, in the actual exploration and development process, the solution gas-oil ratio in the general model of the crude oil volume coefficient is difficult to obtain, and at this time, a general model of the simplified crude oil volume coefficient is generally adopted.
In one embodiment, the crude oil volume coefficient is analyzed according to the actual high-pressure physical properties of the existing 358 wells, and when the evaluation unit cannot obtain the crude oil solution gas-oil ratio, the crude oil volume coefficient can be evaluated by adopting the ground crude oil density and the stratum crude oil density according to the overall knowledge of the area where the evaluation unit is located:
the crude oil volume coefficients calculated by the formulas (a) and (b) are compared with the actual analysis values, the average absolute errors are 0.0328 and 0.0368 respectively, and the average relative errors are 2.57% and 2.20% respectively. Therefore, the formation crude oil volume coefficient calculated by the formula (a) or the formula (b) has high credibility, can meet the precision requirement of crude oil volume coefficient evaluation, and can be used for rapidly evaluating the crude oil volume coefficient of a hydrocarbon reservoir.
In one embodiment, the oil field Chen Gu well is a well known to contain oil: midwifery world; the buried depth of the oil layer is 3732-3783m; the reservoir temperature was 124.3 ℃ (corresponding to depth 3700 m); crude oil density of stratum 0.7318g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the Density of crude oil at 20℃as degassed 0.8379g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the Dissolved air Density 0.0010613g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the Raw dissolved gas-oil ratio 80.27m 3 /m 3 。
Calculating the volume coefficient of Chen Gu well crude oil by adopting a general crude oil volume coefficient model:
calculating Chen Gu well crude oil volume coefficients using a simplified crude oil volume coefficient generic model (a):
chen Gu 6 well actually analyzes crude oil volume coefficient 1.2697, and absolute error calculated by using general equation is 0.0083, relative error is 0.65%; the absolute error calculated with the reduced equation was 0.0186 and the relative error was 1.47%.
Based on the same inventive concept, the embodiments of the present application also provide a device for determining the volume coefficient of crude oil, which can be used to implement the method described in the above embodiments, as described in the following embodiments. Because the principle of solving the problem of the crude oil volume coefficient determining device is similar to that of the crude oil volume coefficient determining, the implementation of the crude oil volume coefficient determining device can refer to the implementation of the crude oil volume coefficient determining method, and the repetition is omitted. As used below, the term "unit" or "module" may be a combination of software and/or hardware that implements the intended function. While the system described in the following embodiments is preferably implemented in software, implementation in hardware, or a combination of software and hardware, is also possible and contemplated.
According to another aspect of the present application, there is also provided a device for determining a volumetric coefficient of crude oil, as shown in fig. 4, including:
the sampling unit 401 is configured to obtain a density of the de-aerated crude oil corresponding to the dissolved gas density, the formation temperature, and the formation temperature;
the formation crude oil density calculating unit 402 is configured to generate a formation crude oil density corresponding to a formation type according to a formation temperature and a degassing crude oil density corresponding to the formation temperature, where the formation type includes: saturated sandstone reservoir formations and former new kingdom and high pour point oil unsaturated reservoir formations;
a general model building unit 403, configured to build a general model of crude oil volume coefficient according to the formation crude oil density and the de-aerated crude oil density;
the crude oil volume coefficient calculating unit 404 is used for inputting the values of the formation crude oil density and the de-aerated crude oil density into the model to obtain the crude oil volume coefficient.
In one embodiment, the apparatus further comprises:
the application unit is used for carrying out oil exploration and oil reservoir development according to the crude oil volume coefficient.
In an embodiment, the generic model building unit 403 includes:
the crude oil volume coefficient generation module is used for generating a crude oil volume coefficient by utilizing the stratum crude oil density, the degassing crude oil density, the stratum crude oil quality and the degassing crude oil quality;
the quality model building module is used for building a stratum crude oil quality model according to the dissolved gas-oil ratio, the quality of the de-aerated crude oil, the dissolved gas density and the density of the de-aerated crude oil;
and the first merging module is used for establishing a general model of the crude oil volume coefficient according to the crude oil volume coefficient and the stratum crude oil quality model.
In one embodiment, the quality model building module includes:
the first model building module is used for generating a stratum crude oil quality first model according to the dissolved gas volume, the dissolved gas density and the quality of the degassed crude oil;
the volume model building module is used for generating a dissolved gas volume model according to the dissolved gas-oil ratio and the volume of the de-aerated crude oil;
and the second merging module is used for establishing a stratum crude oil quality model according to the stratum crude oil quality first model and the dissolved gas volume model.
It will be appreciated by those skilled in the art that embodiments of the present invention may be provided as a method, system, or computer program product. Accordingly, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present invention 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 principles and embodiments of the present invention have been described in detail with reference to specific examples, which are provided to facilitate understanding of the method and core ideas of the present invention; meanwhile, as those skilled in the art will have variations in the specific embodiments and application scope in accordance with the ideas of the present invention, the present description should not be construed as limiting the present invention in view of the above.
The embodiment of the present application further provides a specific implementation manner of an electronic device capable of implementing all the steps in the method in the foregoing embodiment, and referring to fig. 5, the electronic device specifically includes the following:
a processor (processor) 501, a memory 502, a communication interface (Communications Interface) 503, a bus 504, and a nonvolatile memory 505;
wherein, the processor 501, the memory 502 and the communication interface 503 complete the communication with each other through the bus 504;
the processor 501 is configured to invoke the computer program in the memory 502 and the nonvolatile storage 505, where the processor executes the computer program to implement all the steps in the method in the foregoing embodiment, for example, the processor executes the computer program to implement the following steps:
s101: and obtaining the density of the dissolved gas, the formation temperature and the density of the de-aerated crude oil corresponding to the formation temperature.
S102: generating formation crude oil density corresponding to the formation type according to the formation temperature and the density of the de-aerated crude oil corresponding to the formation temperature, wherein the formation type comprises: saturated sandstone reservoir formations and pre-new kingdom and high-pour-point oil unsaturated reservoir formations.
S103: and establishing a general model of the crude oil volume coefficient according to the stratum crude oil density and the degassing crude oil density.
S104: inputting the numerical values of the stratum crude oil density and the degassing crude oil density into a model to obtain the crude oil volume coefficient.
The embodiments of the present application also provide a computer-readable storage medium capable of implementing all the steps of the method in the above embodiments, the computer-readable storage medium having stored thereon a computer program which, when executed by a processor, implements all the steps of the method in the above embodiments, for example, the processor implements the following steps when executing the computer program:
s101: and obtaining the density of the dissolved gas, the formation temperature and the density of the de-aerated crude oil corresponding to the formation temperature.
S102: generating formation crude oil density corresponding to the formation type according to the formation temperature and the density of the de-aerated crude oil corresponding to the formation temperature, wherein the formation type comprises: saturated sandstone reservoir formations and pre-new kingdom and high-pour-point oil unsaturated reservoir formations.
S103: and establishing a general model of the crude oil volume coefficient according to the stratum crude oil density and the degassing crude oil density.
S104: inputting the numerical values of the stratum crude oil density and the degassing crude oil density into a model to obtain the crude oil volume coefficient.
In this specification, each embodiment is described in a progressive manner, and identical and similar parts of each embodiment are all referred to each other, and each embodiment mainly describes differences from other embodiments. In particular, for a hardware+program class embodiment, the description is relatively simple, as it is substantially similar to the method embodiment, as relevant see the partial description of the method embodiment. Although the present description provides method operational steps as described in the examples or flowcharts, more or fewer operational steps may be included based on conventional or non-inventive means. The order of steps recited in the embodiments is merely one way of performing the order of steps and does not represent a unique order of execution. When implemented in an actual device or end product, the instructions may be executed sequentially or in parallel (e.g., in a parallel processor or multi-threaded processing environment, or even in a distributed data processing environment) as illustrated by the embodiments or by the figures. The terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, it is not excluded that additional identical or equivalent elements may be present in a process, method, article, or apparatus that comprises a described element. For convenience of description, the above devices are described as being functionally divided into various modules, respectively. Of course, when implementing the embodiments of the present disclosure, the functions of each module may be implemented in the same or multiple pieces of software and/or hardware, or a module that implements the same function may be implemented by multiple sub-modules or a combination of sub-units, or the like. The above-described apparatus embodiments are merely illustrative, for example, the division of the units is merely a logical function division, and there may be additional divisions when actually implemented, for example, multiple units or components may be combined or integrated into another system, or some features may be omitted or not performed. Alternatively, the coupling or direct coupling or communication connection shown or discussed with each other may be an indirect coupling or communication connection via some interfaces, devices or units, which may be in electrical, mechanical or other form. The present invention is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the invention. 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.
It will be appreciated by those skilled in the art that embodiments of the present description may be provided as a method, system, or computer program product. Accordingly, the present specification embodiments may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present description embodiments may take the form of a computer program product on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) having computer-usable program code embodied therein. In this specification, each embodiment is described in a progressive manner, and identical and similar parts of each embodiment are all referred to each other, and each embodiment mainly describes differences from other embodiments. In particular, for system embodiments, since they are substantially similar to method embodiments, the description is relatively simple, as relevant to see a section of the description of method embodiments. In the description of the present specification, a description referring to terms "one embodiment," "some embodiments," "examples," "specific examples," or "some examples," etc., means that a particular feature, structure, material, or characteristic described in connection with the embodiment or example is included in at least one embodiment or example of the embodiments of the present specification.
In this specification, schematic representations of the above terms are not necessarily directed to the same embodiment or example. Furthermore, the different embodiments or examples described in this specification and the features of the different embodiments or examples may be combined and combined by those skilled in the art without contradiction. The foregoing is merely an example of an embodiment of the present disclosure and is not intended to limit the embodiment of the present disclosure. Various modifications and variations of the illustrative embodiments will be apparent to those skilled in the art. Any modification, equivalent replacement, improvement, or the like, which is within the spirit and principles of the embodiments of the present specification, should be included in the scope of the claims of the embodiments of the present specification.
Claims (6)
1. A method for determining a volumetric coefficient of crude oil, comprising:
obtaining dissolved gas density, formation temperature and density of the de-aerated crude oil corresponding to the formation temperature;
generating a formation crude oil density corresponding to a formation type according to a formation temperature and the de-aerated crude oil density corresponding to the formation temperature, wherein the formation type comprises: saturated sandstone reservoir formations and former new kingdom and high pour point oil unsaturated reservoir formations;
establishing a general model of crude oil volume coefficient according to the stratum crude oil density and the degassing crude oil density;
inputting the values of the stratum crude oil density and the degassing crude oil density into a model to obtain a crude oil volume coefficient;
the method for establishing the general model of the crude oil volume coefficient according to the stratum crude oil density and the degassing crude oil density comprises the following steps:
generating the crude oil volume coefficient by using the formation crude oil density, the de-aerated crude oil density, the formation crude oil mass, and the de-aerated crude oil mass;
establishing a stratum crude oil quality model according to the dissolved gas-oil ratio, the quality of the dead crude oil, the dissolved gas density and the density of the dead crude oil;
establishing a general model of the crude oil volume coefficient according to the crude oil volume coefficient and the stratum crude oil quality model;
the formation crude oil quality model is established according to the dissolved gas-oil ratio, the quality of the dead crude oil, the dissolved gas density and the density of the dead crude oil, and comprises the following steps:
generating a first model of formation crude oil quality from the dissolved gas volume, the dissolved gas density, and the de-aerated crude oil quality;
generating a dissolved gas volume model according to the dissolved gas-oil ratio and the volume of the de-aerated crude oil;
and establishing the stratum crude oil quality model according to the stratum crude oil quality first model and the dissolved gas volume model.
2. The method of determining according to claim 1, wherein after obtaining the crude volume coefficient general equation, the method further comprises:
and carrying out oil exploration and oil reservoir development according to the crude oil volume coefficient.
3. A device for determining a volumetric coefficient of crude oil, comprising:
the sampling unit is used for obtaining the density of the dissolved gas, the formation temperature and the density of the de-aerated crude oil corresponding to the formation temperature;
the formation crude oil density calculation unit is used for generating formation crude oil density corresponding to a formation type according to formation temperature and the de-aerated crude oil density corresponding to the formation temperature, and the formation type comprises: saturated sandstone reservoir formations and former new kingdom and high pour point oil unsaturated reservoir formations;
the general model building unit is used for building a general model of crude oil volume coefficient according to the stratum crude oil density and the degassing crude oil density;
the crude oil volume coefficient calculation unit is used for inputting the numerical values of the stratum crude oil density and the degassing crude oil density into a model to obtain a crude oil volume coefficient;
the general model building unit includes:
the crude oil volume coefficient generation module is used for generating the crude oil volume coefficient by utilizing the stratum crude oil density, the degassing crude oil density, the stratum crude oil mass and the degassing crude oil mass;
the quality model building module is used for building a stratum crude oil quality model according to the dissolved gas-oil ratio, the quality of the de-aerated crude oil, the dissolved gas density and the de-aerated crude oil density;
the first merging module is used for establishing a general model of the crude oil volume coefficient according to the crude oil volume coefficient and the stratum crude oil quality model;
the quality model building module comprises:
the first model building module is used for generating a stratum crude oil quality first model according to the dissolved gas volume, the dissolved gas density and the de-aerated crude oil quality;
the volume model building module is used for generating a dissolved gas volume model according to the dissolved gas-oil ratio and the volume of the de-aerated crude oil;
and the second merging module is used for establishing the stratum crude oil quality model according to the stratum crude oil quality first model and the dissolved gas volume model.
4. A determining apparatus according to claim 3, further comprising:
and the application unit is used for carrying out oil exploration and oil reservoir development according to the crude oil volume coefficient.
5. An electronic 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 determining the volumetric coefficient of crude oil according to any one of claims 1 to 2 when executing the program.
6. A computer-readable storage medium, on which a computer program is stored, characterized in that the computer program, when being executed by a processor, implements the method of determining the volumetric coefficient of crude oil according to any one of claims 1 to 2.
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| CN108691537A (en) * | 2018-04-18 | 2018-10-23 | 中国石油大港油田勘探开发研究院 | A kind of reservoir geology reserve forecasting method |
| CN110067555A (en) * | 2018-01-24 | 2019-07-30 | 中国石油天然气股份有限公司 | Method and device for determining minimum dynamic reserve of carbonate oil well |
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| CN110067555A (en) * | 2018-01-24 | 2019-07-30 | 中国石油天然气股份有限公司 | Method and device for determining minimum dynamic reserve of carbonate oil well |
| CN108691537A (en) * | 2018-04-18 | 2018-10-23 | 中国石油大港油田勘探开发研究院 | A kind of reservoir geology reserve forecasting method |
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