CN112270138A - Complex oil field group flow guarantee and capacity release determination method - Google Patents
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Abstract
The invention relates to a method for ensuring the flow of a complex oilfield group and determining the release of productivity, which comprises the following steps: combining large oil fields with different physical properties to obtain a complex oil field group; determining an adjustment turn-off logic of the complex oilfield group; determining the minimum flow of settled sand of the submarine pipeline; determining the dynamic water hammer pressure of the submarine pipeline; determining the ultimate pressure-bearing capacity of the submarine pipeline in service; and determining the flow guarantee and capacity release of the complex oilfield group according to the adjustment and shutoff logic, the dynamic water hammer pressure, the minimum sand setting flow of the submarine pipeline and the limit bearing capacity. By determining the flow guarantee and the capacity release of the complex oil field group, the invention can realize the good situation of 'development with new and old belt, rolling development and development depending on' of the oil field group, fully release the capacity of the old oil field, reduce the operation and maintenance cost and effectively solve the contradiction between the capacity release requirement and the bottleneck of the safe production of the in-service facility.
Description
Technical Field
The invention relates to the technical field of offshore oilfield groups, in particular to a method for guaranteeing the flow and determining the capacity release of a complex oilfield group.
Background
With the continuous production and rolling development of offshore oil and gas fields, part of marginal oil and gas field development has better economic benefit only by depending on the existing oil and gas facilities and submarine pipelines; meanwhile, due to the consideration of safety and environmental protection, the production can be integrally adjusted according to the service life and the condition of the production facility. Because the related facilities have different production time, partial facility equipment has different attenuation degrees due to longer service time, and various conditions of the original design are different, in order to implement the supported development, the system adaptability, the processing capacity, the conveying capacity of a submarine pipeline and the like of the related facilities become prominent bottlenecks and technical difficulties for the flow guarantee and the production energy release of the oilfield group.
Disclosure of Invention
The technical problem to be solved by the present invention is to provide a method for guaranteeing mobility and determining capacity release of a complex oilfield group, aiming at the above-mentioned defects in the prior art.
The technical scheme adopted by the invention for solving the technical problems is as follows: a method for flow guarantee and capacity release determination of a complex oilfield group is constructed, and comprises the following steps:
combining large oil fields with different physical properties to obtain a complex oil field group;
determining adjusted turn-off logic for the complex oilfield cluster;
determining the minimum flow of settled sand of the submarine pipeline;
determining the dynamic water hammer pressure of the submarine pipeline;
determining the ultimate pressure-bearing capacity of the submarine pipeline in service;
and determining the flow guarantee and the capacity release of the complex oilfield group according to the adjusting and turning-off logic, the dynamic water hammer pressure, the minimum flow of the settled sand of the submarine pipeline and the limit pressure-bearing capacity.
Preferably, the merging of large oil fields with different physical properties to obtain a complex oil field group comprises:
carrying out oil, gas and water balance calculation according to the physical property parameters and the yield of each block of each oil field; the parameters include: crude oil physical property, crude oil components, crude oil yield, natural gas physical property, natural gas components, natural gas yield, water physical property and water yield;
calculating actual load data and power load data of each process processing system according to the processing scale of the process processing system of each block of each oil field;
and organically combining the actual load data and the power load data based on the calculation result of the oil, gas and water balance to obtain the complex oilfield group.
Preferably, the determining the adjusted turn-off logic for the complex oilfield cluster comprises:
determining an adjusted shutdown logic for the complex oilfield fleet based on the type of platforms that have been coupled through the subsea pipeline and the shutdown level.
Preferably, the logic for determining adjusted shutdown of the complex oilfield formation based on the type of platform that has been coupled through the subsea pipeline and the shutdown level comprises:
determining the weight of each oil field according to the type and the shutdown level of the platform connected through the submarine pipeline and by combining the productivity of each oil field;
based on the weights, adjusted turn-off logic for the complex oilfield cluster is determined.
Preferably, the types of the platform include: the system comprises a central processing platform, a drilling and production platform, a wellhead platform and a pressurizing platform;
the shutdown level comprises: abandon platform and turn off, gas and fire turn off, production turn off, unit turn off.
Preferably, the acquiring the dynamic water hammer pressure of the submarine pipeline comprises:
and determining the dynamic water hammer pressure of the submarine pipeline according to the physical property of the submarine pipeline conveying fluid, the parameters of the emergency shut-off valve and the comprehensive factors of the operation conditions.
Preferably, the acquiring the dynamic water hammer pressure of the subsea pipeline according to the physical properties of the fluid transported by the subsea pipeline, the parameters of the emergency shutdown valve, and the comprehensive factors of the operating conditions comprises:
according to the physical property of the fluid conveyed by the submarine pipeline, the parameters of an emergency shut-off valve and the comprehensive factors of the operation conditions;
selecting fluid parameters of the submarine pipeline at the maximum output;
and calculating the dynamic water hammer pressure of the submarine pipeline according to the fluid parameters of the submarine pipeline at the maximum output.
Preferably, the determining the minimum flow rate of the sand setting of the subsea pipeline comprises:
and determining the minimum flow of the settled sand of the submarine pipeline according to the fluid physical property, sand content and sand particle size distribution of the fluid conveyed by the submarine pipeline.
Preferably, the fluid properties of the subsea pipeline transport fluid include: hydrodynamic viscosity, solid particle diameter, solid particle to liquid density difference, and liquid density;
the determining the minimum flow rate of the subsea pipeline sand setting according to the fluid properties of the subsea pipeline transport fluid comprises:
calculating the minimum flow rate of the settled sand of the submarine pipeline according to the hydrodynamic viscosity, the diameter of the solid particles, the density difference between the solid particles and the liquid and the density of the liquid and by combining a calculation formula of the minimum flow rate of the settled sand of the submarine pipeline;
and determining the minimum flow of the settled sand of the submarine pipeline according to the minimum flow rate of the settled sand of the submarine pipeline.
Preferably, the acquiring of the ultimate bearing capacity of the active submarine pipeline comprises:
obtaining an internal pressure analysis formula of an active submarine pipeline;
and calculating the ultimate pressure-bearing capacity of the active submarine pipeline according to the internal pressure analysis formula.
The method for guaranteeing the flow of the complex oilfield group and determining the release of the capacity has the following beneficial effects: the method comprises the following steps: combining large oil fields with different physical properties to obtain a complex oil field group; determining an adjustment turn-off logic of the complex oilfield group; determining the minimum flow of settled sand of the submarine pipeline; determining the dynamic water hammer pressure of the submarine pipeline; determining the ultimate pressure-bearing capacity of the submarine pipeline in service; and determining the flow and capacity release of the complex oilfield group according to the adjustment and shutoff logic, the dynamic water hammer pressure, the minimum sand setting flow of the submarine pipeline and the limit bearing capacity. According to the invention, by determining the flow and capacity release of the complex oil field group, the good situation of 'development in new and old ways, rolling development and development depending on' of the oil field group can be realized, the capacity of the old oil field is fully released, the operation and maintenance cost is reduced, and the contradiction between the capacity release requirement and the bottleneck of safe production of in-service facilities is effectively solved.
Drawings
The invention will be further described with reference to the accompanying drawings and examples, in which:
fig. 1 is a schematic flow chart of a method for ensuring mobility and determining capacity release of a complex oilfield group according to an embodiment of the present invention;
FIG. 2 is a schematic diagram comparing water hammer pressures for a subsea pipeline;
fig. 3 is a schematic diagram of a consolidated complex field group.
Detailed Description
For a more clear understanding of the technical features, objects and effects of the present invention, embodiments of the present invention will now be described in detail with reference to the accompanying drawings.
Referring to fig. 1, fig. 1 is a schematic flow chart of an alternative embodiment of the embodiments of the present invention.
As shown in fig. 1, the method for determining flow assurance and capacity release of a complex oilfield group includes:
and S101, combining large oil fields with different physical properties to obtain a complex oil field group.
Wherein, merge the large-scale oil field of different rerum natures, obtain complicated oil field crowd and include: carrying out oil, gas and water balance calculation according to the physical property parameters and the yield of each block of each oil field; the physical property parameters comprise: crude oil physical property, crude oil components, crude oil yield, natural gas physical property, natural gas components, natural gas yield, water physical property, water components and water yield; calculating the capacity data and the power load data of each process processing system according to the processing scale of the process processing system of each block of each oil field; and organically combining the oil, gas and water balance calculation results, actual load data and power load data to obtain a complex oil field group.
Specifically, because the differences in the composition of crude oil physical properties, natural gas and the like of each block in different oil fields are large, the processing scale of a process processing system and the type of processing facilities are different, and the like, in the embodiment of the invention, regional oil, gas and water balance calculation, main equipment actual load capacity calculation, power load calculation and the like can be sequentially carried out by combining the different crude oil physical properties, natural gas components, the yields of oil, gas and water of each block and the like, and further the combination of the oil fields is completed to obtain a complex oil field group.
Different oil fields are combined according to the conditions to obtain the complex oil field group, and then comprehensive comparison and selection are performed on the complex oil field group, so that development of old facilities driven by new facilities can be realized, and continuous and stable production of platforms with large yield is guaranteed to the greatest extent. The consolidated complex field group is shown in fig. 3, wherein fig. 3 is only an example and does not have any limiting effect on the present invention. As shown in fig. 3, the capacity of the existing facility can be fully utilized by the combination, and the work load and the work cost can be reduced.
And S102, determining the adjusting and turning-off logic of the complex oilfield group.
Wherein determining the adjusted turn-off logic for the complex oilfield group comprises: the adjusted shutdown logic for a complex oilfield formation is determined based on the type and shutdown level of the platform that has been coupled through the subsea pipeline.
In some embodiments, determining adjusted shutdown logic for a complex oilfield formation based on the type of platforms that have been coupled through the subsea pipeline and the shutdown level comprises: determining the specific gravity of each oil field according to the type and the shutdown level of the platform connected through the submarine pipeline and by combining the capacity of each oil field to the total output of the complex oil field group; based on the specific gravity, an adjusted shutdown logic for the complex oilfield cluster is determined.
In some embodiments, the types of platforms include, but are not limited to: the system comprises a central processing platform, a drilling and production platform, a wellhead platform and a pressurizing platform.
In some embodiments, shutdown levels include, but are not limited to: abandon platform and turn off, gas and fire turn off, production turn off, unit turn off.
Specifically, the weight of each oil field is determined by determining the contribution of the platform for connecting the submarine pipelines to the total output of the complex oil field group according to different types and different shutdown levels of the platform and the productivity of each oil field (determining the weight of each oil field is equivalent to determining the weight of the platform for exploiting the oil field). After the weight is determined, under the condition that normal production of related facilities (such as a platform and a submarine pipeline) is met, adjusting and turning-off logics of mining process conditions (such as pressure, flow and the like) are further determined, so that corresponding process condition adjustment and turning-off of different levels (such as unit turning-off, production turning-off, fire gas turning-off, platform abandoning and the like) are carried out according to the determined adjusting and turning-off logics, comprehensive judgment on yield loss influence of the whole oil field group can be realized, and cost reduction, yield increase and efficiency increase of the oil field are realized.
And S103, determining the lowest flow of the settled sand of the submarine pipeline.
Wherein, confirm submarine pipeline sand setting minimum flow includes: and determining the lowest flow of settled sand of the submarine pipeline according to the fluid physical property, sand content and sand particle size distribution of the submarine pipeline conveying fluid. In some embodiments, the fluid properties of the subsea pipeline transport fluid include: hydrodynamic viscosity, solid particle diameter, solid particle to liquid density difference, and liquid density.
Further, determining the minimum flow rate of the sand setting of the subsea pipeline according to the fluid properties of the fluid transported by the subsea pipeline comprises:
calculating the minimum flow rate of the settled sand of the submarine pipeline according to the hydrodynamic viscosity, the diameter of the solid particles, the density difference between the solid particles and the liquid and the density of the liquid and by combining a calculation formula of the minimum flow rate of the settled sand of the submarine pipeline; and determining the minimum flow of the settled sand of the submarine pipeline according to the minimum flow rate of the settled sand of the submarine pipeline.
The calculation formula of the minimum flow rate of the settled sand of the submarine pipeline is as follows:
in the formula, VmRepresenting the minimum flow velocity of settled sand of the submarine pipeline, m/s; v is hydrodynamic viscosity, m2S; d is the solid particle diameter, m; delta rho is the density difference between solid particles and liquid, kg/m3；ρfIs liquid density, kg/m3。
Wherein, table 1 shows the lowest flow rates for particles of different particle sizes:
further, after determining the minimum flow rate, the minimum flow rate (i.e., minimum output) of the subsea pipeline is determined based on the minimum flow rate. Namely, the lowest flow of the submarine pipeline can be calculated according to the determined lowest flow velocity and by combining the pipe diameter and the sectional area of the submarine pipeline. By determining the minimum output, the loss of output energy and the processing load of downstream facilities can be reduced, and cost reduction and efficiency improvement are realized.
And step S104, determining the dynamic water hammer pressure of the submarine pipeline.
Wherein determining the subsea pipeline dynamic water hammer pressure comprises: and acquiring the dynamic water hammer pressure of the submarine pipeline according to the physical property of the submarine pipeline conveying fluid, the parameters of the emergency shut-off valve, the operating conditions and other comprehensive factors.
In some embodiments, obtaining the dynamic water hammer pressure of the subsea pipeline according to the physical properties of the fluid transported by the subsea pipeline, the parameters of the emergency shutdown valve, and the operating conditions includes: according to the physical property of the fluid conveyed by the submarine pipeline, the parameters of an emergency shut-off valve, the operating conditions and other comprehensive factors; selecting fluid parameters of the submarine pipeline at the maximum output; and calculating the dynamic water hammer pressure of the submarine pipeline according to the fluid parameters of the submarine pipeline at the maximum output. The comprehensive factors include, but are not limited to, water hammer pressurization factors, water hammer transient response factors, SDV valve closing duration and other factors.
Specifically, the dynamic water hammer pressure of the submarine pipeline is obtained by comprehensively analyzing and calculating various factors such as the physical property of the fluid conveyed by the submarine pipeline, emergency shut-off factors, water hammer pressurization, water hammer transient response, the valve closing time of an SDV (shut-off valve) and the like. Furthermore, the obtained dynamic water hammer pressure of the submarine pipeline is applied to the maximum pressure check of the submarine pipeline in service, so that the conveying pressure of the submarine pipeline can be improved, the maximum conveying capacity of the submarine pipeline is released, and the technical guarantee is provided for capacity release. The properties of the fluid transported by the subsea pipeline include, but are not limited to: flow, flow rate, fluid density, hydrodynamic viscosity, temperature, inlet pressure.
For example, in some embodiments, when the outlet valve of the subsea pipeline is suddenly closed or the output pump is suddenly stopped, the flow rate of the fluid in the subsea pipeline changes sharply, and the pressure fluctuates greatly, and the existing conventional method is to calculate the water hammer pressure of the subsea pipeline according to a static water hammer pressure formula, and the water hammer pressurization calculated in this way is large. According to the embodiment of the invention, the dynamic water hammer pressure is calculated by selecting the factors such as the flow, the flow speed, the fluid density, the temperature, the inlet pressure, the SDV valve closing time length and the like of the submarine pipeline at the maximum output. By comparison, it can be seen that the dynamic water hammer pressure calculated by using the method of the present invention is closer to the actual field.
Specifically, as shown in fig. 2, line a1 is a graph of the dynamic water hammer pressure calculated by the present invention, and line a2 is the static water hammer pressure calculated by the conventional method. As shown in fig. 2, the peak of the a1 line (shown as 1 in fig. 2) is smaller than the peak of a2 (shown as 2 in fig. 2). The comparison shows that the dynamic water hammer pressure is adopted to determine the water hammer pressure generated when the submarine pipeline is shut down suddenly, the maximum allowable working pressure of the pipeline is improved compared with the conventional static water hammer pressure, and the maximum output can be increased by about 26%. Reference may be made specifically to the data comparison in the following table:
| year of year | X year (ten thousand tons/year) | X +1 year (ten thousand tons/year) |
| Original design for conveying oil mass | 304.22 | 294.38 |
| Optimized oil delivery | 386.9 | 327.83 |
| Increase of yield | 82.68 | 33.45 |
Table 2: delivery of oil
And S105, determining the limit pressure-bearing capacity of the active submarine pipeline.
Wherein, confirm that the extreme pressure-bearing capacity of active submarine pipeline includes: obtaining an internal pressure analysis formula of an active submarine pipeline; and calculating the ultimate pressure-bearing capacity of the submarine pipeline in service according to the internal pressure analysis formula.
Specifically, the internal pressure analysis formula of the submarine pipeline in service is as follows:
in the formula, peExternal pressure; t is the pipe wall thickness; gamma raym1.15 for a material resistance coefficient; gamma raySCA security level coefficient; p is a radical ofb(t) bearing resistance, which is related to material properties; p is a radical ofliFor extreme bearing capacity, it may be: p is a radical ofli＝pd·γinc+ρcont·g·h；pdDesigning the pressure; gamma rayinc1.1 as the ratio of the accidental pressure to the design pressure; rhocontIs the density of the liquid in the pipe; g is the acceleration of gravity; h is the depth of water.
Wherein,
while
Wherein D is the outer diameter; f. ofyYield strength to account for temperature reduction; f. ofuTo take into account the temperature-reduced tensile strength.
Specifically, the invention reversely calculates the limit pressure which can be borne by the submarine pipeline through the formula under the condition that the two sides of the formula are equal. Calculating the limit pressure, and performing a series of checks on accessories such as a combination effect, a flange, an anchoring piece and the like of the submarine pipeline by using the limit pressure, wherein if the limit pressure meets the requirements, the limit pressure is the limit strength of the submarine pipeline; if the requirement is not met, reducing the limit pressure by proper step (the size of the step is determined by practical application, the invention is not particularly limited), and then performing a series of checks on accessories such as a combination action, a flange, an anchor and the like on the submarine pipeline. By repeating the steps, the ultimate strength of the feasible submarine pipeline is finally determined, so that the design of the submarine pipeline is effectively released, and the conveying capacity of the submarine pipeline is released to the maximum extent on the premise that the strength allows. Comparing the extreme strength check result of the submarine pipelines combined by a complex oilfield group with the conventional check result, wherein the comparison is as follows:
and S106, determining the flow guarantee and the capacity release of the complex oilfield group according to the adjustment and shutdown logic, the dynamic water hammer pressure, the minimum sand setting flow of the submarine pipeline and the limit pressure-bearing capacity.
By determining the flow guarantee and the capacity release of the complex oil field group, a proper scheme, such as an optimal scheme, can be obtained according to the flow and the capacity release of the complex oil field group, so that the flow of the complex oil and gas field pipeline can be guaranteed based on the obtained scheme, and meanwhile, the oil field group can be developed in a rolling way as a new oil field and an old oil field, the capacity of the old oil field can be fully released, the operation and maintenance cost can be reduced, and the contradiction between the capacity release requirement and the bottleneck of the in-service facility safety production can be solved according to the good situation of development.
The above embodiments are merely illustrative of the technical ideas and features of the present invention, and are intended to enable those skilled in the art to understand the contents of the present invention and implement the present invention, and not to limit the scope of the present invention. All equivalent changes and modifications made within the scope of the claims of the present invention should be covered by the claims of the present invention.
Claims (10)
1. A method for flow assurance and capacity release determination of a complex oilfield group is characterized by comprising the following steps:
combining large oil fields with different physical properties to obtain a complex oil field group;
determining adjusted turn-off logic for the complex oilfield cluster;
determining the minimum flow of settled sand of the submarine pipeline;
determining the dynamic water hammer pressure of the submarine pipeline; determining the ultimate pressure-bearing capacity of the submarine pipeline in service;
and determining the flow guarantee and the capacity release of the complex oilfield group according to the adjusting and turning-off logic, the dynamic water hammer pressure, the minimum flow of the settled sand of the submarine pipeline and the limit pressure-bearing capacity.
2. The method for determining flow assurance and capacity release of a complex oilfield cluster according to claim 1, wherein the combining of the large oilfield with different physical properties to obtain the complex oilfield cluster comprises:
carrying out oil, gas and water balance calculation according to the physical property parameters and the yield of each block of each oil field; the physical property parameters comprise: crude oil physical property, crude oil components, crude oil yield, natural gas physical property, natural gas components, natural gas yield, water composition and water yield;
calculating actual load data and power load data of each process processing system according to the scale of the production process processing system of each block of each oil field;
and organically combining the actual load data and the power load data based on the calculation result of the oil, gas and water balance to obtain the complex oilfield group.
3. The complex oilfield cluster flow assurance and capacity release determination method of claim 1, wherein the determining the adjusted shutdown logic of the complex oilfield cluster comprises:
determining an adjusted shutdown logic for the complex oilfield fleet based on the type of platforms that have been coupled through the subsea pipeline and the shutdown level.
4. The complex oilfield cluster flow assurance and capacity release determination method of claim 3, wherein the determining the adjusted shutdown logic for the complex oilfield cluster based on the type of platform that has been coupled by the subsea pipeline and the shutdown level comprises:
determining the weight of each oil field according to the type and the shutdown level of the platform connected through the submarine pipeline and by combining the productivity of each oil field;
based on the weights, adjusted turn-off logic for the complex oilfield cluster is determined.
5. The complex oilfield group flow assurance and capacity release determination method of claim 3, wherein the platform is of a type comprising: the system comprises a central processing platform, a drilling and production platform, a wellhead platform and a pressurizing platform;
the shutdown level comprises: abandon platform and turn off, gas and fire turn off, production turn off, unit turn off.
6. The complex oilfield group flow assurance and capacity release determination method of claim 1, wherein the determining the subsea pipeline dynamic water hammer pressure comprises:
and determining the dynamic water hammer pressure of the submarine pipeline according to the physical property of the submarine pipeline conveying fluid, the parameters of the emergency shut-off valve and the comprehensive factors of the operation conditions.
7. The complex oilfield group flow assurance and capacity release determination method of claim 6, wherein determining the subsea pipeline dynamic water hammer pressure based on the subsea pipeline transport fluid properties, emergency shutdown valve parameters, and operating condition combination factors comprises:
according to the physical property of the fluid conveyed by the submarine pipeline, the parameters of an emergency shut-off valve and the comprehensive factors of the operation conditions;
selecting fluid parameters of the submarine pipeline at the maximum output;
and calculating the dynamic water hammer pressure of the submarine pipeline according to the fluid parameters of the submarine pipeline at the maximum output.
8. The complex oilfield group flow assurance and capacity release determination method of claim 1, wherein determining the minimum flow rate of subsea pipeline sand deposition comprises:
and determining the minimum flow of the settled sand of the submarine pipeline according to the fluid physical property, sand content and sand particle size distribution of the fluid conveyed by the submarine pipeline.
9. The complex oilfield group flow assurance and productivity release determination method of claim 8, wherein the fluid properties of the subsea pipeline transport fluid comprise: hydrodynamic viscosity, solid particle diameter, solid particle to liquid density difference, and liquid density;
the determining the minimum flow rate of the subsea pipeline sand setting according to the fluid properties of the subsea pipeline transport fluid comprises:
calculating the minimum flow rate of the settled sand of the submarine pipeline according to the hydrodynamic viscosity, the diameter of the solid particles, the density difference between the solid particles and the liquid and the density of the liquid and by combining a calculation formula of the minimum flow rate of the settled sand of the submarine pipeline;
and determining the minimum flow of the settled sand of the submarine pipeline according to the minimum flow rate of the settled sand of the submarine pipeline.
10. The complex oilfield group flow assurance and capacity release determination method of claim 1, wherein the obtaining the ultimate bearing capacity of the active subsea pipeline comprises:
obtaining an internal pressure analysis formula of an active submarine pipeline;
and calculating the ultimate pressure-bearing capacity of the active submarine pipeline according to the internal pressure analysis formula.
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| CN202010912192.9A CN112270138B (en) | 2020-09-02 | 2020-09-02 | Complex oilfield group flow guarantee and productivity release determination method |
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Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102747991A (en) * | 2011-04-22 | 2012-10-24 | 长江大学 | Method for determining single-layer output of commingled producing well |
| CN105631754A (en) * | 2015-12-29 | 2016-06-01 | 中国石油天然气股份有限公司 | Method and device for determining production profile data of offshore oil field |
| WO2018213083A1 (en) * | 2017-05-15 | 2018-11-22 | University Of Houston System | Advanced technique for screening enhanced oil recovery and improved oil recovery methodologies for a petroleum reservoir |
| CN110284872A (en) * | 2019-06-10 | 2019-09-27 | 中国石油大学(北京) | The virtual flow rate calculation method and system of the underwater acquisition system of offshore gas field group |
| CN110390439A (en) * | 2019-07-29 | 2019-10-29 | 山东圣哲石油装备有限公司 | Oil field Early-warning Model system based on big data rough set theory |
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Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102747991A (en) * | 2011-04-22 | 2012-10-24 | 长江大学 | Method for determining single-layer output of commingled producing well |
| CN105631754A (en) * | 2015-12-29 | 2016-06-01 | 中国石油天然气股份有限公司 | Method and device for determining production profile data of offshore oil field |
| WO2018213083A1 (en) * | 2017-05-15 | 2018-11-22 | University Of Houston System | Advanced technique for screening enhanced oil recovery and improved oil recovery methodologies for a petroleum reservoir |
| CN110284872A (en) * | 2019-06-10 | 2019-09-27 | 中国石油大学(北京) | The virtual flow rate calculation method and system of the underwater acquisition system of offshore gas field group |
| CN110390439A (en) * | 2019-07-29 | 2019-10-29 | 山东圣哲石油装备有限公司 | Oil field Early-warning Model system based on big data rough set theory |
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