CN117684935A - Shale oil reservoir carbon dioxide huff and puff gas injection amount determining method and device - Google Patents
Shale oil reservoir carbon dioxide huff and puff gas injection amount determining method and device Download PDFInfo
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- 238000002347 injection Methods 0.000 title claims abstract description 270
- 239000007924 injection Substances 0.000 title claims abstract description 270
- 239000003079 shale oil Substances 0.000 title claims abstract description 191
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 title claims abstract description 162
- 229910002092 carbon dioxide Inorganic materials 0.000 title claims abstract description 81
- 239000001569 carbon dioxide Substances 0.000 title claims abstract description 81
- 238000000034 method Methods 0.000 title claims abstract description 52
- 238000009792 diffusion process Methods 0.000 claims abstract description 41
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims abstract description 20
- 229910052799 carbon Inorganic materials 0.000 claims abstract description 20
- 239000010779 crude oil Substances 0.000 claims description 38
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 29
- 230000006835 compression Effects 0.000 claims description 24
- 238000007906 compression Methods 0.000 claims description 24
- 238000004519 manufacturing process Methods 0.000 claims description 24
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
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- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/164—Injecting CO2 or carbonated water
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- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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Abstract
The invention discloses a method and a device for determining carbon dioxide throughput and gas injection of a shale oil reservoir. Wherein the method comprises the following steps: acquiring the gas injection speed of injecting carbon dioxide gas into the shale oil reservoir and the gas concentration of the carbon dioxide gas in the shale oil reservoir, wherein the gas concentration dynamically changes along with the diffusion depth; determining a target fracture area of a shale oil reservoir in the shale oil reservoir, wherein the target fracture area dynamically changes along with accumulated open time; determining a first gas injection amount corresponding to the shale oil reservoir based on the gas injection speed and the target fracture area; determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area; and obtaining the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount. The method solves the technical problems of large calculated amount, long time consumption, large crack characterization difficulty and inaccurate evaluation existing in the related art because the shale dioxide huff-puff carbon gas injection quantity design mainly depends on a conventional oil reservoir numerical simulation method.
Description
Technical Field
The invention relates to the technical field of shale oil reservoir development, in particular to a method and a device for determining carbon dioxide huff and puff gas injection quantity of a shale oil reservoir.
Background
Shale oil is widely used as an unconventional oil and gas resource, and due to low permeability of a reservoir, water injection is difficult to establish an effective displacement pressure system under an economic limit well pattern, and the development of shale oil benefits is generally realized by adopting a horizontal well and volume fracturing mode at present. Molecular diffusion is an important mechanism for shale oil to improve recovery efficiency in the carbon dioxide huff and puff process. How to consider molecular diffusion to carry out optimal design to shale oil carbon dioxide throughput gas injection becomes a key ring influencing shale oil gas injection throughput effect and benefit, wherein the design throughput gas injection is too small, the throughput oil increasing effect is poor, the design gas injection is too large, invalid circulation of gas injection is caused, and throughput benefit is influenced.
In the prior art, shale oil throughput parameter optimization design is carried out by utilizing oil reservoir numerical simulation software to carry out optimization design on gas injection quantity through geological modeling and oil reservoir numerical simulation according to a conventional oil reservoir method, and mainly, prediction of the gas injection quantity is realized by adjusting oil gas permeation in the gas injection process, so that the implementation mode is single. Meanwhile, because the difficulty of establishing a fracture model by using the oil reservoir numerical simulation effect is high, the accuracy of representing the fracture by the fracture model under the unconventional oil reservoir volume fracturing scale is poor, and meanwhile, the defects of more needed basic data, long time consumption, more influence factors and the like are overcome.
In view of the above problems, no effective solution has been proposed at present.
Disclosure of Invention
The embodiment of the invention provides a method and a device for determining the carbon dioxide throughput and gas injection amount of a shale oil reservoir, which are used for at least solving the technical problems of large calculated amount, long time consumption, large difficulty in crack characterization and inaccurate evaluation because the design of the carbon dioxide throughput and gas injection amount of the shale oil reservoir in the related technology mainly depends on a conventional oil reservoir numerical simulation method.
According to one aspect of the embodiment of the invention, a method for determining the carbon injection amount of the carbon dioxide huff-puff of a shale oil reservoir is provided, which comprises the following steps: acquiring a gas injection speed of injecting carbon dioxide gas into a shale oil reservoir and a gas concentration of the carbon dioxide gas in the shale oil reservoir, wherein the gas injection speed is the gas injection speed corresponding to a unit fracture area of the shale oil reservoir, the gas concentration is the gas concentration corresponding to the unit fracture area of the shale oil reservoir, and the gas concentration dynamically changes along with the diffusion depth of the carbon dioxide gas in the cracks of the shale oil reservoir; determining a target fracture area of the shale oil reservoir, wherein the target fracture area dynamically changes along with the accumulated open time of the shale oil reservoir; determining a first gas injection amount corresponding to the shale oil reservoir based on the gas injection speed and the target fracture area; determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area, wherein the first gas injection amount is a ground conversion gas injection amount corresponding to a gas injection stage, and the second gas injection amount is a ground conversion gas injection amount corresponding to a gas diffusion stage; and obtaining the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount.
Optionally, determining the target fracture area of the shale oil reservoir includes: obtaining production history data of the shale oil reservoir, wherein the production history data at least comprises: crude oil yield, water content, formation pressure and bottom hole flowing pressure corresponding to the shale oil reservoir; the target fracture area is determined based on the production history data.
Optionally, the determining the target fracture area based on the production history data includes: obtaining a plurality of crack areas at different historical moments based on the production historical data; selecting a crack area corresponding to the water content within a first preset range from the plurality of crack areas; and calculating an average value of the crack areas corresponding to the water content in a first preset range, and taking the average value as the target crack area.
Optionally, the obtaining a plurality of crack areas at different historical moments based on the production history data includes: acquiring reservoir physical parameters, crude oil high-pressure physical parameters and accumulated well opening time corresponding to the shale oil reservoir, wherein the reservoir physical parameters at least comprise: crude oil saturation pressure, crude oil compression coefficient, formation volume coefficient and formation crude oil viscosity, wherein the reservoir physical parameters at least comprise: matrix-over-pressure permeability, matrix-over-pressure porosity, irreducible water saturation; based on the production history data, the reservoir physical property parameters, the crude oil high-pressure physical property parameters and the accumulated well opening time, a plurality of crack areas at different historical moments are obtained in the following mode:
Wherein A is f1 Represents crack area, q at different historic moments o Representing the above crude oil yield, B o Representing the formation volume coefficient, P i Representing the formation pressure, P wf Represents the bottom hole flow pressure, mu o Representing the viscosity of the crude oil in the stratum, t k Represents the cumulative open time, K represents the matrix overburden permeability, phi represents the matrix overburden porosity, C t Representing an integrated compression factor, wherein the integrated compression factor is determined based on the crude oil compression factor and the irreducible water saturation.
Optionally, the determining, based on the gas injection speed and the target fracture area, a first gas injection amount corresponding to the shale oil reservoir includes: based on the gas injection speed and the target fracture area, determining a first gas injection amount corresponding to the shale oil reservoir in the following manner:
wherein q g Representing the gas injection speed, A f And (3) expressing the target crack area, wherein t represents the gas injection duration.
Alternatively, the above gas injection speed q is obtained by g ：
Wherein Q is p Represents the first air injection amount, P inj Represents the bottom hole pressure of gas injection, P i Represents formation pressure, B g Represents the gas volume coefficient, K represents the matrix overpressure permeability, phi represents the matrix overpressure porosity, C t Represents the integrated compression coefficient, mu g Indicating the viscosity of the gas.
Optionally, the determining, based on the gas concentration and the target fracture area, a second gas injection amount corresponding to the shale oil reservoir includes: and determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area by the following method:
wherein C (x) represents the gas concentration, d represents the furthest distance of the gas diffusion after the completion of the shale reservoir soaking, B g Represents the gas volume coefficient, Q C The second air injection amount is indicated.
Alternatively, the above gas concentration is obtained by:
wherein D represents a gas diffusion coefficient, x represents the diffusion depth, t represents a soak time,representing the complementary error function.
Optionally, the obtaining the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount includes: and summing the first gas injection amount and the second gas injection amount to obtain the target gas injection amount.
According to another aspect of the embodiment of the invention, there is also provided a device for determining the carbon injection amount of the carbon dioxide huff-puff of a shale oil reservoir, comprising: the device comprises a first acquisition module, a second acquisition module and a third acquisition module, wherein the first acquisition module is used for acquiring the gas injection speed of injecting carbon dioxide gas into a shale oil reservoir and the gas concentration of the carbon dioxide gas in the shale oil reservoir, wherein the gas injection speed is the gas injection speed corresponding to the unit fracture area of the shale oil reservoir, the gas concentration is the gas concentration corresponding to the unit fracture area of the shale oil reservoir, and the gas concentration dynamically changes along with the diffusion depth of the carbon dioxide gas in the fracture of the shale oil reservoir; the first determining module is used for determining a target fracture area of the shale oil deposit, wherein the target fracture area dynamically changes along with the accumulated open time of the shale oil deposit; the second determining module is used for determining a first gas injection amount corresponding to the shale oil reservoir based on the gas injection speed and the target fracture area; determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area, wherein the first gas injection amount is a ground conversion gas injection amount corresponding to a gas injection stage, and the second gas injection amount is a ground conversion gas injection amount corresponding to a gas diffusion stage; and the second acquisition module is used for obtaining the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount.
According to another aspect of the embodiment of the invention, there is further provided a non-volatile storage medium, where a plurality of instructions are stored, the instructions being adapted to be loaded and executed by a processor to any one of the shale reservoir carbon dioxide throughput carbon injection amount determining methods described above.
According to another aspect of the embodiment of the present invention, there is further provided an electronic device, including one or more processors and a memory, where the memory is configured to store one or more programs, and when the one or more programs are executed by the one or more processors, the one or more processors implement any one of the methods for determining a carbon injection amount for a shale oil reservoir through-put dioxide.
In the embodiment of the invention, the gas injection speed of injecting carbon dioxide gas into the shale oil deposit and the gas concentration of the carbon dioxide gas in the shale oil deposit are obtained, wherein the gas injection speed is the gas injection speed corresponding to the unit fracture area of the shale oil deposit, the gas concentration is the gas concentration corresponding to the unit fracture area of the shale oil deposit, and the gas concentration dynamically changes along with the diffusion depth of the carbon dioxide gas in the fracture of the shale oil deposit; determining a target fracture area of the shale oil reservoir, wherein the target fracture area dynamically changes along with the accumulated open time of the shale oil reservoir; determining a first gas injection amount corresponding to the shale oil reservoir based on the gas injection speed and the target fracture area; determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area, wherein the first gas injection amount is a ground conversion gas injection amount corresponding to a gas injection stage, and the second gas injection amount is a ground conversion gas injection amount corresponding to a gas diffusion stage; based on the first gas injection amount and the second gas injection amount, the target gas injection amount of the shale oil reservoir is obtained, and the aim of determining the carbon injection amount of the carbon dioxide throughput of the shale oil reservoir by comprehensively considering the factors of carbon dioxide gas diffusion and crack area dynamic change is achieved, so that the technical effects of improving the prediction efficiency and the prediction accuracy of the carbon dioxide throughput gas injection amount in the shale oil reservoir are achieved, and the technical problems that the calculated amount is large, the time consumption is long, the crack characterization difficulty is large and the evaluation is inaccurate because the design of the carbon dioxide throughput gas injection amount of the shale in the related technology mainly depends on a conventional oil reservoir numerical simulation method are solved.
Drawings
The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this application, illustrate embodiments of the invention and together with the description serve to explain the invention and do not constitute a limitation on the invention. In the drawings:
FIG. 1 is a flow chart of a shale reservoir carbon dioxide huff and puff gas injection amount determination method according to an embodiment of the present invention;
FIG. 2 is a schematic structural view of a shale oil reservoir carbon dioxide huff-puff gas injection amount determining device according to an embodiment of the present invention;
fig. 3 is a schematic diagram of an electronic device according to an embodiment of the invention.
Detailed Description
In order that those skilled in the art will better understand the present invention, a technical solution in the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings in which it is apparent that the described embodiments are only some embodiments of the present invention, not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the present invention without making any inventive effort, shall fall within the scope of the present invention.
It should be noted that the terms "first," "second," and the like in the description and the claims of the present invention and the above figures are used for distinguishing between similar objects and not necessarily for describing a particular sequential or chronological order. It is to be understood that the data so used may be interchanged where appropriate such that the embodiments of the invention described herein may be implemented in sequences other than those illustrated or otherwise described herein. Furthermore, the terms "comprises," "comprising," and "having," and any variations thereof, are intended to cover a non-exclusive inclusion, such that a process, method, system, article, or apparatus that comprises a list of steps or elements is not necessarily limited to those steps or elements expressly listed but may include other steps or elements not expressly listed or inherent to such process, method, article, or apparatus.
In accordance with an embodiment of the present invention, a method embodiment for determining carbon injection capacity for a shale reservoir is provided, it being noted that the steps illustrated in the flowchart of the figures may be performed in a computer system, such as a set of computer executable instructions, and, although a logical sequence is illustrated in the flowchart, in some cases, the steps illustrated or described may be performed in a different order than that illustrated herein.
FIG. 1 is a flow chart of a method for determining the carbon injection amount of the carbon dioxide huff-puff of a shale oil reservoir according to an embodiment of the invention, as shown in FIG. 1, the method comprises the following steps:
step S102, acquiring the gas injection speed of injecting carbon dioxide gas into a shale oil reservoir and the gas concentration of the carbon dioxide gas in the shale oil reservoir;
step S104, determining a target fracture area of the shale oil reservoir, wherein the target fracture area dynamically changes along with the accumulated open time of the shale oil reservoir;
step S106, determining a first gas injection amount corresponding to the shale oil reservoir based on the gas injection speed and the target fracture area; determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area, wherein the first gas injection amount is a ground conversion gas injection amount corresponding to a gas injection stage, and the second gas injection amount is a ground conversion gas injection amount corresponding to a gas diffusion stage;
And step S108, obtaining the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount.
Through the steps, the aim of determining the carbon dioxide injection quantity of the shale oil reservoir by comprehensively considering the carbon dioxide gas diffusion and the fracture area dynamic change factors can be achieved, so that the technical effects of improving the prediction efficiency and the prediction accuracy of the carbon dioxide injection quantity in the shale oil reservoir are achieved, and the technical problems that the calculation quantity is large, the time consumption is long, the fracture characterization difficulty is large and the assessment is inaccurate due to the fact that the shale carbon dioxide injection quantity design in the related technology mainly depends on a conventional oil reservoir numerical simulation method are solved.
Optionally, the gas injection rate is a gas injection rate corresponding to a unit fracture area of the shale oil reservoir, the gas concentration is a gas concentration corresponding to a unit fracture area of the shale oil reservoir, and the gas concentration dynamically changes along with a diffusion depth of the carbon dioxide gas in the shale oil reservoir. That is, the gas concentration is a gas concentration in consideration of molecular diffusion, and the further the distance from the fracture surface of the shale reservoir is, the smaller the concentration of carbon dioxide gas is.
Optionally, the gas injection stage is a stage of injecting carbon dioxide gas into the shale oil reservoir. The gas diffusion stage is a stage of injecting carbon dioxide gas into the shale oil reservoir, then performing well soaking treatment on the shale oil reservoir, and diffusing the gas in the well soaking process.
In the related technology, the gas injection quantity is optimally designed by using the oil reservoir numerical simulation software through geologic modeling and oil reservoir numerical simulation, and the prediction of the throughput effect is realized by mainly adjusting the oil gas permeation in the gas injection process, so that the contribution of the molecular diffusion action mechanism of the unconventional oil reservoir caused by the pore scale effect to the improvement of the recovery ratio is not considered. Meanwhile, the accuracy of the oil reservoir numerical simulation prediction method mainly depends on the accuracy of a fracture model, but the characterization difficulty of the fracture is high and the accuracy is poor under the unconventional oil reservoir volume fracturing scale. According to the method for determining the carbon dioxide injection quantity of the shale oil deposit huff-puff carbon, when the carbon dioxide injection quantity of the shale oil deposit huff-puff carbon is determined, the gas concentration of carbon dioxide gas is determined according to the gas diffusion principle, the dynamic fracture area is obtained according to the accumulated open time of the shale oil deposit, and the obtained carbon dioxide injection quantity of the shale oil deposit huff-puff carbon is higher and is closer to reality, and is better in accuracy.
In an alternative embodiment, the determining the target fracture area of the shale reservoir includes:
obtaining production history data of the shale oil reservoir, wherein the production history data at least comprises: crude oil yield, water content, formation pressure and bottom hole flowing pressure corresponding to the shale oil reservoir;
the target fracture area is determined based on the production history data.
Optionally, when determining the target fracture area, the factors such as crude oil yield, water content, formation pressure, bottom hole flow pressure and the like corresponding to the shale oil reservoir and the dynamic change conditions of the factors along with time are considered, so that the obtained fracture area (namely the target fracture area) of the shale oil reservoir is more fit with reality, the calculation requirement of the shale oil reservoir carbon dioxide huff and puff gas injection amount is better met, and the accuracy of the obtained shale oil reservoir carbon dioxide huff and puff gas injection amount is higher.
In an alternative embodiment, the determining the target fracture area based on the production history data includes:
obtaining a plurality of crack areas at different historical moments based on the production historical data;
selecting a crack area corresponding to the water content within a first preset range from the plurality of crack areas;
And calculating an average value of the crack areas corresponding to the water content in a first preset range, and taking the average value as the target crack area.
Optionally, according to the production history data of the shale oil reservoir, collecting the crude oil yield, the water content, the formation pressure and the bottom hole flowing pressure at different historic moments, and the reservoir physical parameters, the crude oil high-pressure physical parameters and the accumulated well opening time corresponding to the shale oil reservoir. Determining a plurality of crack areas at different historical moments based on the crude oil yield, the water content, the formation pressure, the bottom hole flowing pressure, reservoir physical parameters corresponding to the shale oil reservoir, crude oil high-pressure physical parameters and accumulated well opening time; and calculating an average value of the plurality of crack areas meeting the water content requirement as the target crack area when the water content is in a first preset range (for example, 15%) and the plurality of crack areas are corresponding to the first preset range (for example, less than 15%).
Optionally, the water content is determined according to a water content change curve acquired in situ from the shale oil reservoir. For example, the first preset range of the change of the water content is selected according to the change curve of the water content to be less than 15% of the water content. In addition, since the flow fracture area (i.e., the target fracture area) changes with time, it is mainly affected by the production pressure difference, the shale reservoir yield, the reservoir physical properties, the fluid physical properties, and the like, and when the flow fracture area is taken, it is recommended to select a calculated value when the water content is reduced to 15% or less after completion of flowback of the fracturing fluid.
In an alternative embodiment, the obtaining a plurality of crack areas at different historical moments based on the production history data includes:
acquiring reservoir physical parameters, crude oil high-pressure physical parameters and accumulated well opening time corresponding to the shale oil reservoir, wherein the reservoir physical parameters at least comprise: crude oil saturation pressure, crude oil compression coefficient, formation volume coefficient and formation crude oil viscosity, wherein the reservoir physical parameters at least comprise: matrix-over-pressure permeability, matrix-over-pressure porosity, irreducible water saturation;
based on the production history data, the reservoir physical property parameters, the crude oil high-pressure physical property parameters and the accumulated well opening time, a plurality of crack areas at different historical moments are obtained in the following mode:
wherein A is f1 Represents the crack area at different historical moments, the unit is m 2 ；q o Representing the above crude oil yield in m 3 /d (cubic meters/day); b (B) o Representing the stratum volume coefficient in the form of decimal; p (P) i The formation pressure is expressed in MPa (megapascals); p (P) wf Representing the bottom hole flow pressure in MPa; mu (mu) o Representing the viscosity of the crude oil in the stratum, wherein the unit is Cp (centipoise); t is t k The accumulated open time is expressed in d (days); k represents the above matrix overpressure permeability in mD (millidarcy); phi represents the covering porosity of the matrix, and the unit is; c (C) t Represents the integrated compression coefficient in mD (millidarcy); wherein said integrated compressibility is determined based on said crude oil compressibility and said irreducible water saturation, and said crude oil yield may be daily crude oil yield.
Alternatively, the above-mentioned integrated compression coefficient C is obtained by t ：
Wherein C is o The compression coefficient of crude oil is expressed, and the unit is 1/MPa; c (C) w The compression coefficient of formation water is expressed, and the unit is 1/MPa; c (C) f The compression coefficient of a rock pore system is expressed, and the unit is 1/MPa; s is S wi Representing the water saturation of the substrate bindingAnd degrees, which may be in decimal form.
Optionally, real-time monitoring of various parameters is required in the actual exploitation process of the shale oil reservoir, and corresponding test reports are generated. Most of the parameter distances involved in the embodiments of the present invention can be obtained from the generated test report. For example, the above-mentioned crude oil high-pressure physical properties, such as crude oil saturation pressure (p) b ) Volume coefficient (B) o ) Compression factor of crude oil (C) o ) Viscosity (mu) o ) Isoparametric, wherein the volume coefficient and the compression coefficient are affected by formation pressure; the reservoir physical parameters described above, such as, for example, the overburden porosity (phi) and permeability (K), the irreducible water saturation (S) under reservoir matrix reservoir conditions, may be obtained, but are not limited to, by pre-collected in-shale reservoir core test analysis reports wc )。
Optionally, collecting shale reservoir pressure measurement data before shale reservoir production to obtain shale reservoir original stratum pressure (p i )。
Alternatively, the shale reservoir may be tested for its corresponding rock pore compression factor according to, but not limited to, the rock pore volume compression factor determination method standard. The compression coefficient test is carried out on the shale oil core according to the SY/T5815-2016 rock pore volume compression coefficient determination method of petroleum carbon dioxide industry standard to obtain the rock pore compression coefficient (C) f )。
In an alternative embodiment, the determining the first gas injection amount corresponding to the shale oil reservoir based on the gas injection speed and the target fracture area includes:
based on the gas injection speed and the target fracture area, determining a first gas injection amount corresponding to the shale oil reservoir in the following manner:
wherein q g The unit of the gas injection speed is m 3 /d (vertical nm/min); a is that f Expressing the target crack area in m 3 (cubic meters); t represents the gas injection time length, and the unit is d (days); wherein the gas injection speed q g Is obtained by the following steps:
wherein Q is p The first air injection amount is expressed as m 3 (cubic meters); p (P) inj Represents the bottom hole pressure of gas injection, and the unit is MPa; p (P) i Represents the formation pressure in MPa; b (B) g Representing the gas volume coefficient in decimal form; k represents the matrix overpressure permeability in mD (millidarcy); phi represents the matrix-coated porosity in units of; c (C) t Represents the integrated compression coefficient in mD (millidarcy); mu (mu) g The gas viscosity is expressed in Cp (centipoise).
In an alternative embodiment, the determining the second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area includes:
and determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area by the following method:
wherein C (x) represents the concentration of the gas in units of; d represents the furthest distance of the gas diffusion after the end of the shale oil reservoir well soaking, and the unit is m (meters); b (B) g Representing the gas volume coefficient in decimal form; q (Q) C The second air injection amount is expressed as m 3 (cubic meters); wherein, the gas concentration is obtained by the following method:
optionally, D represents a gas diffusion coefficient in m 2 S (square meters/second); x represents the diffusion depth in m (meters); t represents the time of well logging in d (days); Representing the complementary error function.
In an alternative embodiment, the obtaining the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount includes: and summing the first gas injection amount and the second gas injection amount to obtain the target gas injection amount.
Optionally, based on the first air injection quantity Q p And the second air injection quantity Q C The target gas injection amount is calculated by the following formula
The embodiment also provides a device for determining the carbon injection amount of the shale oil reservoir during the oxidation, which is used for realizing the embodiment and the preferred embodiment, and is not described in detail. As used below, the terms "module," "apparatus" may be a combination of software and/or hardware that implements a predetermined function. While the means described in the following embodiments are preferably implemented in software, implementation in hardware, or a combination of software and hardware, is also possible and contemplated.
According to an embodiment of the present invention, there is further provided an embodiment of a device for implementing the method for determining a carbon injection amount of a shale oil deposit carbon dioxide huff, and fig. 2 is a schematic structural diagram of a device for determining a carbon injection amount of a shale oil deposit carbon dioxide huff according to an embodiment of the present invention, as shown in fig. 2, where the device for determining a carbon injection amount of a shale oil deposit carbon dioxide huff includes: a first acquisition module 200, a first determination module 204, a second determination module 206, a second acquisition module 208, wherein:
The first obtaining module 200 is configured to obtain a gas injection rate of injecting carbon dioxide gas into the shale oil reservoir, and a gas concentration of the carbon dioxide gas in the shale oil reservoir, where the gas injection rate is a gas injection rate corresponding to a unit fracture area of the shale oil reservoir, the gas concentration is a gas concentration corresponding to a unit fracture area of the shale oil reservoir, and the gas concentration dynamically changes according to a diffusion depth of the carbon dioxide gas in a fracture of the shale oil reservoir;
the first determining module 204 is connected to the first obtaining module 200, and is configured to determine a target fracture area of the shale oil reservoir, where the target fracture area dynamically changes along with an accumulated open time of the shale oil reservoir;
the second determining module 206, coupled to the first determining module 204, is configured to determine a first gas injection amount corresponding to the shale reservoir based on the gas injection rate and the target fracture area; determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area, wherein the first gas injection amount is a ground conversion gas injection amount corresponding to a gas injection stage, and the second gas injection amount is a ground conversion gas injection amount corresponding to a gas diffusion stage;
The second obtaining module 208 is connected to the second determining module 206, and is configured to obtain the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount.
In the embodiment of the present invention, the first obtaining module 200 is configured to obtain a gas injection speed of injecting carbon dioxide gas into a shale oil reservoir and a gas concentration of the carbon dioxide gas in the shale oil reservoir, where the gas injection speed is a gas injection speed corresponding to a unit fracture area of the shale oil reservoir, the gas concentration is a gas concentration corresponding to a unit fracture area of the shale oil reservoir, and the gas concentration dynamically changes along with a diffusion depth of the carbon dioxide gas in a fracture of the shale oil reservoir; the first determining module 204 is configured to determine a target fracture area of the shale oil reservoir, where the target fracture area dynamically changes with a cumulative open time of the shale oil reservoir; the second determining module 206 is configured to determine a first gas injection amount corresponding to the shale oil reservoir based on the gas injection speed and the target fracture area; determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area, wherein the first gas injection amount is a ground conversion gas injection amount corresponding to a gas injection stage, and the second gas injection amount is a ground conversion gas injection amount corresponding to a gas diffusion stage; the second obtaining module 208 is configured to obtain the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount, thereby achieving the purpose of determining the carbon injection amount of the carbon dioxide in the shale oil reservoir by comprehensively considering the factors of carbon dioxide diffusion and dynamic change of the fracture area, and further achieving the technical effects of improving the prediction efficiency and the prediction accuracy of the carbon injection amount of the carbon dioxide in the shale oil reservoir, and further solving the technical problems of large calculated amount, long time consumption, large fracture characterization difficulty and inaccurate evaluation because the design of the carbon injection amount of the carbon dioxide in the shale oil reservoir mainly depends on a conventional oil reservoir numerical simulation method.
It should be noted that each of the above modules may be implemented by software or hardware, for example, in the latter case, it may be implemented by: the above modules may be located in the same processor; alternatively, the various modules described above may be located in different processors in any combination.
It should be noted that, the first obtaining module 200, the first determining module 204, the second determining module 206, and the second obtaining module 208 correspond to steps S102 to S108 in the embodiment, and the modules are the same as the examples and the application scenarios implemented by the corresponding steps, but are not limited to the disclosure of the foregoing embodiments. It should be noted that the above modules may be run in a computer terminal as part of the apparatus.
It should be noted that, the optional or preferred implementation manner of this embodiment may be referred to the related description in the embodiment, and will not be repeated herein.
The shale oil reservoir carbon dioxide throughput determination device may further include a processor and a memory, where the first obtaining module 200, the first determining module 204, the second determining module 206, the second obtaining module 208 and the like are all stored as program modules in the memory, and the processor executes the program modules stored in the memory to implement corresponding functions.
The processor comprises a kernel, the kernel accesses the memory to call the corresponding program module, and the kernel can be provided with one or more than one. The memory may include volatile memory, random Access Memory (RAM), and/or nonvolatile memory, such as Read Only Memory (ROM) or flash memory (flash RAM), among other forms in computer readable media, the memory including at least one memory chip.
According to an embodiment of the present application, there is also provided an embodiment of a nonvolatile storage medium. Optionally, in this embodiment, the nonvolatile storage medium includes a stored program, where when the program runs, the device where the nonvolatile storage medium is controlled to execute any one of the methods for determining the carbon injection amount of the oxidation throughput of the shale oil reservoir.
Alternatively, in this embodiment, the above-mentioned nonvolatile storage medium may be located in any one of the computer terminals in the computer terminal group in the computer network or in any one of the mobile terminals in the mobile terminal group, and the above-mentioned nonvolatile storage medium includes a stored program.
Optionally, the program controls the device in which the nonvolatile storage medium is located to perform the following functions when running: acquiring a gas injection speed of injecting carbon dioxide gas into a shale oil reservoir and a gas concentration of the carbon dioxide gas in the shale oil reservoir, wherein the gas injection speed is the gas injection speed corresponding to a unit fracture area of the shale oil reservoir, the gas concentration is the gas concentration corresponding to the unit fracture area of the shale oil reservoir, and the gas concentration dynamically changes along with the diffusion depth of the carbon dioxide gas in the cracks of the shale oil reservoir; determining a target fracture area of the shale oil reservoir, wherein the target fracture area dynamically changes along with the accumulated open time of the shale oil reservoir; determining a first gas injection amount corresponding to the shale oil reservoir based on the gas injection speed and the target fracture area; determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area, wherein the first gas injection amount is a ground conversion gas injection amount corresponding to a gas injection stage, and the second gas injection amount is a ground conversion gas injection amount corresponding to a gas diffusion stage; and obtaining the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount.
According to an embodiment of the present application, there is also provided an embodiment of a processor. Optionally, in this embodiment, the processor is configured to run a program, where the program executes any one of the methods for determining a carbon dioxide injection amount of a shale oil reservoir during running the program.
According to an embodiment of the present application, there is also provided an embodiment of a computer program product, which when executed on a data processing apparatus, is adapted to carry out a program for initializing the shale reservoir carbon dioxide throughput gas injection amount determination method steps of any of the above.
Optionally, the computer program product mentioned above, when executed on a data processing device, is adapted to perform a program initialized with the method steps of: acquiring a gas injection speed of injecting carbon dioxide gas into a shale oil reservoir and a gas concentration of the carbon dioxide gas in the shale oil reservoir, wherein the gas injection speed is the gas injection speed corresponding to a unit fracture area of the shale oil reservoir, the gas concentration is the gas concentration corresponding to the unit fracture area of the shale oil reservoir, and the gas concentration dynamically changes along with the diffusion depth of the carbon dioxide gas in the cracks of the shale oil reservoir; determining a target fracture area of the shale oil reservoir, wherein the target fracture area dynamically changes along with the accumulated open time of the shale oil reservoir; determining a first gas injection amount corresponding to the shale oil reservoir based on the gas injection speed and the target fracture area; determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area, wherein the first gas injection amount is a ground conversion gas injection amount corresponding to a gas injection stage, and the second gas injection amount is a ground conversion gas injection amount corresponding to a gas diffusion stage; and obtaining the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount.
As shown in fig. 3, an embodiment of the present invention provides an electronic device, where the electronic device 10 includes a processor, a memory, and a program stored on the memory and executable on the processor, and the processor implements the following steps when executing the program: acquiring a gas injection speed of injecting carbon dioxide gas into a shale oil reservoir and a gas concentration of the carbon dioxide gas in the shale oil reservoir, wherein the gas injection speed is the gas injection speed corresponding to a unit fracture area of the shale oil reservoir, the gas concentration is the gas concentration corresponding to the unit fracture area of the shale oil reservoir, and the gas concentration dynamically changes along with the diffusion depth of the carbon dioxide gas in the cracks of the shale oil reservoir; determining a target fracture area of the shale oil reservoir, wherein the target fracture area dynamically changes along with the accumulated open time of the shale oil reservoir; determining a first gas injection amount corresponding to the shale oil reservoir based on the gas injection speed and the target fracture area; determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area, wherein the first gas injection amount is a ground conversion gas injection amount corresponding to a gas injection stage, and the second gas injection amount is a ground conversion gas injection amount corresponding to a gas diffusion stage; and obtaining the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount.
The foregoing embodiment numbers of the present invention are merely for the purpose of description, and do not represent the advantages or disadvantages of the embodiments.
In the foregoing embodiments of the present invention, the descriptions of the embodiments are emphasized, and for a portion of this disclosure that is not described in detail in this embodiment, reference is made to the related descriptions of other embodiments.
In the several embodiments provided in the present application, it should be understood that the disclosed technology content may be implemented in other manners. The above-described embodiments of the apparatus are merely exemplary, and the division of the modules may be a logic function division, and there may be another division manner when actually implemented, for example, a plurality of modules or components may be combined or may be 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 respect to each other may be through some interface, module or indirect coupling or communication connection of modules, electrical or otherwise.
The modules described above as separate components may or may not be physically separate, and components shown as modules may or may not be physical modules, i.e., may be located in one place, or may be distributed over a plurality of modules. Some or all of the modules may be selected according to actual needs to achieve the purpose of the solution of this embodiment.
In addition, each functional module in each embodiment of the present invention may be integrated into one processing module, or each module may exist alone physically, or two or more modules may be integrated into one module. The integrated modules may be implemented in hardware or in software functional modules.
The integrated modules described above, if implemented in the form of software functional modules and sold or used as a stand-alone product, may be stored in a computer readable non-volatile storage medium. Based on such understanding, the technical solution of the present invention may be embodied essentially or in part or all of the technical solution or in part in the form of a software product stored in a non-volatile storage medium, including several instructions to cause a computer device (which may be a personal computer, a server, or a network device, etc.) to perform all or part of the steps of the methods of the embodiments of the present invention. And the aforementioned nonvolatile storage medium includes: a U-disk, a Read-Only Memory (ROM), a random access Memory (RAM, random Access Memory), a removable hard disk, a magnetic disk, or an optical disk, or other various media capable of storing program codes.
The foregoing is merely a preferred embodiment of the present invention and it should be noted that modifications and adaptations to those skilled in the art may be made without departing from the principles of the present invention, which are intended to be comprehended within the scope of the present invention.
Claims (10)
1. A shale oil reservoir carbon dioxide huff and puff gas injection amount determining method is characterized by comprising the following steps:
acquiring the gas injection speed of injecting carbon dioxide gas into a shale oil reservoir and the gas concentration of the carbon dioxide gas in the shale oil reservoir, wherein the gas injection speed is the gas injection speed corresponding to the unit fracture area of the shale oil reservoir, the gas concentration is the gas concentration corresponding to the unit fracture area of the shale oil reservoir, and the gas concentration dynamically changes along with the diffusion depth of the carbon dioxide gas in the cracks of the shale oil reservoir;
determining a target fracture area of the shale oil reservoir, wherein the target fracture area dynamically changes with accumulated open time of the shale oil reservoir;
determining a first gas injection amount corresponding to the shale oil reservoir based on the gas injection speed and the target fracture area; determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area, wherein the first gas injection amount is a ground converted gas injection amount corresponding to a gas injection stage, and the second gas injection amount is a ground converted gas injection amount corresponding to a gas diffusion stage;
And obtaining the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount.
2. The method of claim 1, wherein the determining the target fracture area of the shale reservoir comprises:
obtaining production history data of the shale oil reservoir, wherein the production history data at least comprises: the shale oil reservoir corresponds to crude oil yield, water content, formation pressure and bottom hole flowing pressure;
the target fracture area is determined based on the production history data.
3. The method of claim 2, wherein the determining the target fracture area based on the production history data comprises:
based on the production history data, obtaining a plurality of crack areas at different historical moments;
selecting a crack area corresponding to the water content in a first preset range from the plurality of crack areas;
and calculating an average value of the crack areas corresponding to the water content in a first preset range, and taking the average value as the target crack area.
4. The method of claim 3, wherein deriving a plurality of crack areas at different historical moments based on the production history data comprises:
Acquiring reservoir physical parameters, crude oil high-pressure physical parameters and accumulated well opening time corresponding to the shale oil reservoir, wherein the reservoir physical parameters at least comprise: crude oil saturation pressure, crude oil compression coefficient, formation volume coefficient and formation crude oil viscosity, wherein the reservoir physical parameters at least comprise: matrix-over-pressure permeability, matrix-over-pressure porosity, irreducible water saturation;
based on the production history data, the reservoir physical property parameters, the crude oil high-pressure physical property parameters and the accumulated well opening time, a plurality of crack areas at different historical moments are obtained in the following mode:
wherein A is f1 Represents crack area, q at different historic moments o Representing the crude oil yield, B o Representing the formation volume coefficient, P i Representing the formation pressure, P wf Represents the bottom hole flow pressure, mu o Representing the viscosity of the crude oil of the stratum, t k Representing the tirednessCounting the open time, K represents the matrix overburden permeability, phi represents the matrix overburden porosity, C t Representing an integrated compression factor, wherein the integrated compression factor is determined based on the crude oil compression factor and the irreducible water saturation.
5. The method of claim 1, wherein the determining a corresponding first gas injection amount for the shale reservoir based on the gas injection rate and the target fracture area comprises:
Based on the gas injection speed and the target fracture area, determining a first gas injection amount corresponding to the shale oil reservoir in the following manner:
wherein q g Representing the gas injection speed, A f Expressing the target crack area, wherein t represents the gas injection time length; wherein the gas injection speed q g Is obtained by the following steps:
wherein Q is p Representing the first air injection amount, P inj Represents the bottom hole pressure of gas injection, P i Represents formation pressure, B g Represents the gas volume coefficient, K represents the matrix overpressure permeability, phi represents the matrix overpressure porosity, C t Represents the integrated compression coefficient, mu g Indicating the viscosity of the gas.
6. The method of claim 1, wherein the determining a corresponding second gas injection amount for the shale reservoir based on the gas concentration and the target fracture area comprises:
and determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area by the following method:
wherein C (x) represents the gas concentration, d represents the furthest distance of gas diffusion after the shale oil reservoir is closed off, B g Represents the gas volume coefficient, Q C Representing the second gas injection amount; wherein the gas concentration is obtained by:
Wherein D represents a gas diffusion coefficient, x represents the diffusion depth, t represents a soak time,representing the complementary error function.
7. The method of any one of claims 1 to 6, wherein the deriving the target gas injection rate for the shale reservoir based on the first gas injection rate and the second gas injection rate comprises:
and summing the first gas injection amount and the second gas injection amount to obtain the target gas injection amount.
8. The utility model provides a shale oil reservoir carbon dioxide huff and puff gas injection amount determining device which characterized in that includes:
the device comprises a first acquisition module, a second acquisition module and a third acquisition module, wherein the first acquisition module is used for acquiring the gas injection speed of carbon dioxide gas injected into a shale oil reservoir and the gas concentration of the carbon dioxide gas in the shale oil reservoir, wherein the gas injection speed is the gas injection speed corresponding to the unit fracture area of the shale oil reservoir, the gas concentration is the gas concentration corresponding to the unit fracture area of the shale oil reservoir, and the gas concentration is dynamically changed along with the diffusion depth of the carbon dioxide gas in the fracture of the shale oil reservoir;
the first determining module is used for determining a target fracture area of the shale oil reservoir, wherein the target fracture area dynamically changes along with the accumulated open time of the shale oil reservoir;
The second determining module is used for determining a first gas injection amount corresponding to the shale oil reservoir based on the gas injection speed and the target fracture area; determining a second gas injection amount corresponding to the shale oil reservoir based on the gas concentration and the target fracture area, wherein the first gas injection amount is a ground converted gas injection amount corresponding to a gas injection stage, and the second gas injection amount is a ground converted gas injection amount corresponding to a gas diffusion stage;
and the second acquisition module is used for obtaining the target gas injection amount of the shale oil reservoir based on the first gas injection amount and the second gas injection amount.
9. A non-volatile storage medium having stored thereon a plurality of instructions adapted to be loaded by a processor and to perform the shale reservoir carbon dioxide throughput gas injection amount determination method of any of claims 1 to 7.
10. An electronic device comprising one or more processors and a memory for storing one or more programs, wherein the one or more programs, when executed by the one or more processors, cause the one or more processors to implement the shale reservoir carbon dioxide throughput carbon injection determination method of any of claims 1-7.
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