CN112270138B - Complex oilfield group flow guarantee and productivity release determination method - Google Patents
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Abstract
The invention relates to a method for determining flow guarantee and capacity release of a complex oilfield group, 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 sand setting flow of the submarine pipeline; determining the dynamic water hammer pressure of the submarine pipeline; determining the ultimate bearing capacity of the active submarine pipeline; and determining the flow guarantee and the capacity release of the complex oil field group according to the adjustment shut-off logic, the dynamic water hammer pressure, the minimum sand setting flow of the submarine pipeline and the limit bearing capacity. The invention can realize the good situation of 'new and old, rolling development and depending on development' of the oil field group by determining the flow guarantee and capacity release of the complex 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 safety production bottleneck of in-service facilities.
Description
Technical Field
The invention relates to the technical field of offshore oilfield groups, in particular to a method for guaranteeing flow and determining capacity release of a complex oilfield group.
Background
Along with continuous production and rolling development of offshore oil and gas fields, part of marginal oil and gas field development needs to rely on existing oil and gas facilities and submarine pipelines to have better economic benefit; meanwhile, due to the consideration of safety and environmental protection, the integrated adjustment of production can be performed according to the service life and the condition of the production facility. Because the production time of related facilities is different, different levels of attenuation appear in partial facility equipment due to longer efficiency of the time of application, various conditions of original design are different, and in order to implement depending development, the system adaptability, the processing capacity, the conveying capacity of submarine pipelines and the like of related facilities all become outstanding bottlenecks and technical difficulties of production flow guarantee and capacity release of oil field groups.
Disclosure of Invention
The invention aims to solve the technical problem of providing a method for ensuring the flow of a complex oil field group and determining the release of productivity aiming at the defects in the prior art.
The technical scheme adopted for solving the technical problems is as follows: a method for determining flow assurance and productivity release of a complex oilfield group is constructed, and the method comprises the following steps:
combining large oil fields with different physical properties to obtain a complex oil field group;
determining an adjustment shut-off logic for the complex oilfield group;
determining the minimum sand setting flow of the submarine pipeline;
determining the dynamic water hammer pressure of the submarine pipeline;
determining the ultimate bearing capacity of the active submarine pipeline;
and determining the flow guarantee and the capacity release of the complex oil field group according to the adjustment shut-off logic, the dynamic water hammer pressure, the minimum sand setting flow of the submarine pipeline and the limit bearing capacity.
Preferably, the merging the large oil fields with different physical properties to obtain the complex oil field group comprises:
calculating oil, gas and water balance according to physical parameters and yield of each block of each oil field; the parameters include: crude oil physical properties, crude oil components, crude oil yield, natural gas physical properties, natural gas components, natural gas yield, water physical properties, and water yield;
according to the processing scale of the process processing system of each block of each oil field, calculating the actual load data and the electric load data of each process processing system;
and organically combining the actual load data and the electric load data based on the calculation result of the oil, gas and water balance to obtain the complex oilfield group.
Preferably, the determining the adjustment shut-off logic for the complex oilfield group comprises:
an adjusted shut-off logic for the complex oilfield group is determined based on the type of platform and the shut-off hierarchy that has been joined by the subsea pipeline.
Preferably, said determining the adjusted shut-off logic for the complex oilfield group based on the type of platform and shut-off level that has been coupled by the subsea pipeline comprises:
determining the weight of each oil field according to the type and the turn-off level of the platform connected through the submarine pipeline and the productivity of each oil field;
based on the weights, an adjusted shut-off logic for the complex oilfield group is determined.
Preferably, the types of the platform include: the system comprises a central processing platform, a drilling platform, a wellhead platform and a pressurizing platform;
the shutdown level includes: discarding platform turn-off, fire turn-off, production turn-off, unit turn-off.
Preferably, the obtaining the submarine pipeline dynamic water hammer pressure comprises:
and determining the dynamic water hammer pressure of the submarine pipeline according to the physical properties of the fluid conveyed by the submarine pipeline, the emergency shut-off valve parameters and the comprehensive factors of the operation working conditions.
Preferably, the obtaining the dynamic water hammer pressure of the submarine pipeline according to the physical property of the fluid transported by the submarine pipeline, the emergency shut-off valve parameter and the comprehensive factors of the operation condition comprises:
according to physical properties of the fluid conveyed by the submarine pipeline, emergency shut-off valve parameters and comprehensive factors of operation conditions;
selecting fluid parameters of the submarine pipeline at the maximum delivery;
and calculating the dynamic water hammer pressure of the submarine pipeline according to the fluid parameters of the submarine pipeline at the maximum delivery.
Preferably, the determining the minimum sand setting flow rate of the subsea pipeline comprises:
and determining the minimum sand setting flow of the submarine pipeline according to the physical properties, the sand content and the sand grain diameter distribution of the fluid conveyed by the submarine pipeline.
Preferably, the fluid properties of the subsea pipeline transfer fluid include: hydrodynamic viscosity, solid particle diameter, solid particle to liquid density difference, and liquid density;
the determining the minimum sand setting flow rate of the submarine pipeline according to the fluid physical property of the submarine pipeline conveying fluid comprises the following steps:
calculating the minimum sand setting flow rate of the submarine pipeline according to the hydrodynamic viscosity, the solid particle diameter, the solid particle-liquid density difference and the liquid density and by combining the calculation of the minimum sand setting flow rate of the submarine pipeline;
and determining the minimum sand setting flow rate of the submarine pipeline according to the minimum sand setting flow rate of the submarine pipeline.
Preferably, the acquiring the ultimate bearing capacity of the active subsea pipeline comprises:
acquiring the internal pressure analysis type of the active submarine pipeline;
and calculating the ultimate bearing capacity of the active submarine pipeline according to the internal pressure analysis formula.
The complex oilfield group flow guarantee and productivity release determination method has the following beneficial effects: comprising 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 sand setting flow of the submarine pipeline; determining the dynamic water hammer pressure of the submarine pipeline; determining the ultimate bearing capacity of the active submarine pipeline; and determining the flow and capacity release of the complex oil field group according to the adjustment shut-off logic, the dynamic water hammer pressure, the minimum sand setting flow of the submarine pipeline and the limit bearing capacity. The invention can realize the good situation of 'new and old, rolling development and depending on development' of the oil field group by determining the flow and capacity release of the complex 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 safety production bottleneck of in-service facilities.
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 determining flow assurance and capacity release of a complex oilfield group provided by an embodiment of the invention;
FIG. 2 is a schematic diagram showing the water hammer pressure contrast of a subsea pipeline;
FIG. 3 is a schematic diagram of a consolidated complex oilfield group.
Detailed Description
For a clearer understanding of technical features, objects and effects of the present invention, a detailed description of embodiments of the present invention will be made with reference to the accompanying drawings.
Referring to fig. 1, fig. 1 is a schematic flow chart of an alternative embodiment of each embodiment provided in the present invention.
As shown in fig. 1, the method for determining the flow assurance and the capacity release of the complex oilfield group comprises the following steps:
and step S101, merging large oil fields with different physical properties to obtain a complex oil field group.
Wherein, merge the large-scale oil field of different physical properties, obtain complicated oil field crowd including: calculating oil, gas and water balance according to physical parameters and yield of each block of each oil field; the physical parameters include: crude oil physical properties, crude oil components, crude oil yield, natural gas physical properties, natural gas components, natural gas yield, water physical properties, water components, and water yield; according to the processing scale of the process processing system of each block of each oil field, calculating the capacity data and the power load data of each process processing system; and organically combining the actual load data and the electric load data based on the oil, gas and water balance calculation result to obtain the complex oil field group.
Specifically, because the physical properties of crude oil, the composition difference of natural gas and the like of each block in different oil fields are large, the processing scale of a process processing system and the types of processing facilities are different, and the like, in the embodiment of the invention, the calculation of regional oil, gas and water balance, the calculation of main equipment actual load capacity, the calculation of electric load and the like can be sequentially carried out by combining different physical properties of crude oil, natural gas components, the yields of oil, gas and water of each block and the like, and further the combination of each oil field is completed, so that a complex oil field group is obtained.
Different oil fields are combined according to the conditions to obtain the complex oil field group, and comprehensive comparison and selection are further carried out on the basis of the complex oil field group, so that old facilities can be driven by new facilities to develop, and continuous and stable production of a platform with large yield can be ensured as much as possible. The consolidated complex field population is shown in fig. 3, where fig. 3 is merely exemplary and does not limit the present invention. As shown in fig. 3, by combining, the capacity of existing facilities can be fully utilized, and the amount of engineering and engineering cost can be reduced.
And step S102, determining an adjustment turn-off logic of the complex oilfield group.
Wherein determining the adjusted shut-off logic for the complex oilfield group comprises: the adjusted shut-off logic for the complex oilfield group is determined based on the type of platform and the shut-off hierarchy that has been coupled by the subsea pipeline.
In some embodiments, determining the adjusted shut-off logic for the complex oilfield group based on the type of platform and the shut-off level that has been coupled by the subsea pipeline comprises: determining the specific gravity of each oil field according to the type and the turn-off level of a platform connected through a submarine pipeline and combining the capacity of each oil field to the total yield of the complex oil field group; based on the specific gravity, an adjusted shut-off logic for the complex oilfield group is determined.
In some embodiments, the types of platforms include, but are not limited to: the system comprises a central processing platform, a drilling platform, a wellhead platform and a pressurizing platform.
In some embodiments, the shutdown level includes, but is not limited to: discarding platform turn-off, fire turn-off, production turn-off, unit turn-off.
Specifically, the weight of each oil field is determined by the contribution of each oil field to the total yield of the complex oil field group according to the productivity of each oil field by connecting the submarine pipeline with the platform according to different types and different shut-off levels (the weight of each oil field is determined, namely, the weight of the platform for exploiting the oil field is determined). After the weight is determined, under the condition that the normal production of related facilities (such as a platform and a submarine pipeline) is met, the adjustment shutdown logic of the exploitation process conditions (such as pressure, flow and the like) is further determined, so that corresponding process condition adjustment and different-level shutdown (such as unit shutdown, production shutdown, fire shutdown, platform rejection shutdown and the like) are performed according to the determined adjustment shutdown logic, thereby realizing comprehensive judgment on the influence of yield loss of a whole oil field group, and realizing cost reduction, yield increase and synergy of the oil field.
And step S103, determining the minimum sand setting flow of the submarine pipeline.
Wherein, determining the minimum sand setting flow rate of the submarine pipeline comprises: and determining the minimum sand setting flow of the submarine pipeline according to the physical properties of the fluid, the sand content and the sand diameter distribution of the fluid conveyed by the submarine pipeline. 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 a minimum subsea pipeline sand setting flow rate based on fluid properties of the subsea pipeline transport fluid comprises:
calculating the minimum sand setting flow rate of the submarine pipeline according to the hydrodynamic viscosity, the solid particle diameter, the solid particle-liquid density difference and the liquid density and by combining the calculation of the minimum sand setting flow rate of the submarine pipeline; and determining the minimum sand setting flow rate of the submarine pipeline according to the minimum sand setting flow rate of the submarine pipeline.
The calculation formula of the minimum sand setting flow rate of the submarine pipeline is as follows:
wherein V is m Representing the minimum sand setting flow rate of the submarine pipeline, and m/s; v is hydrodynamic viscosity, m 2 S; d is the diameter of solid particles, m; deltaρ is the density difference between solid particles and liquid, kg/m 3 ；ρ f Is of liquid density, kg/m 3 。
Wherein table 1 shows the lowest flow rates corresponding to particles of different sizes:
further, after determining the minimum flow rate, the minimum flow rate (i.e., the minimum throughput) of the subsea pipeline is determined from the minimum flow rate. Namely, according to the determined minimum flow rate, the minimum flow rate of the submarine pipeline can be calculated by combining the pipe diameter and the sectional area of the submarine pipeline. By determining the minimum output, the output energy loss and the downstream facility processing load can be reduced, and the 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 obtaining the dynamic water hammer pressure of the submarine pipeline according to the physical properties of the fluid conveyed by the submarine pipeline, the emergency shut-off valve parameters, the operation conditions and other comprehensive factors.
In some embodiments, obtaining the subsea pipeline dynamic water hammer pressure based on the physical properties of the subsea pipeline transport fluid, the emergency shutdown valve parameters, and the operating conditions, and other integrated factors, comprises: according to the physical properties of the fluid conveyed by the submarine pipeline, the emergency shut-off valve parameters, the operation conditions and other comprehensive factors; selecting fluid parameters of the submarine pipeline at the maximum delivery; and calculating the dynamic water hammer pressure of the submarine pipeline according to the fluid parameters of the submarine pipeline at the maximum delivery. Among these, the integrated factors include, but are not limited to, water hammer boost factors, water hammer transient response factors, SDV valve closing duration, and the like.
Specifically, the dynamic water hammer pressure of the submarine pipeline is obtained by comprehensively analyzing and calculating various factors such as physical properties of fluid conveyed by the submarine pipeline, emergency shutdown factors, water hammer pressurization, water hammer transient response, SDV (shut down valve) closing time and the like. Further, by means of the obtained dynamic water hammer pressure of the submarine pipeline, the dynamic water hammer pressure is applied to maximum pressure check of the submarine pipeline in service, conveying pressure of the submarine pipeline can be improved, and the maximum conveying capacity of the submarine pipeline is released, so that technical guarantee is provided for capacity release. Among the physical properties of subsea pipeline transport fluids include, but are not limited to: flow, flow rate, fluid density, hydrodynamic viscosity, temperature, inlet pressure.
For example, in some embodiments, when the subsea pipeline outlet valve is suddenly closed or the external pump is suddenly shut down, the fluid flow rate in the subsea pipeline changes dramatically, thereby causing the pressure to fluctuate significantly, and the conventional method in the prior art is to calculate the subsea pipeline's water hammer pressure according to a static water hammer pressure formula, which results in a larger calculated water hammer boost. According to the embodiment of the invention, the dynamic water hammer pressure is calculated by selecting the factors such as the flow rate, the flow velocity, the fluid density, the temperature, the inlet pressure, the SDV valve closing time length and the like of the submarine pipeline when the maximum delivery amount is selected. By comparison, the dynamic water hammer pressure calculated by adopting the mode of the invention is more approximate to the actual on-site.
Specifically, as shown in fig. 2, a line A1 is a graph of dynamic water hammer pressure calculated by the present invention, and A2 is a static water hammer pressure calculated by the existing method. As shown in fig. 2, the peak value of the A1 line (shown as 1 in fig. 2) is smaller than the peak value of A2 (shown as 2 in fig. 2). As can be seen from comparison, the dynamic water hammer pressure is adopted to determine the water hammer pressure generated when the submarine pipeline is suddenly shut down, and compared with the conventional static water hammer pressure, the maximum allowable working pressure of the pipeline is improved, and the transmission capacity can be increased by about 26% at maximum. Reference is made in particular 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 of oil delivery | 304.22 | 294.38 |
| Optimized oil delivery | 386.9 | 327.83 |
| Increase in yield | 82.68 | 33.45 |
Table 2: delivery oil quantity
And step 105, determining the limit bearing capacity of the active submarine pipeline.
Wherein determining the ultimate bearing capacity of the active subsea pipeline comprises: acquiring the internal pressure analysis type of the active submarine pipeline; and calculating the limit bearing capacity of the submarine pipeline in service according to the internal pressure analysis.
Specifically, the internal pressure analysis formula of the active subsea pipeline is as follows:
wherein p is e External pressure; t=pipe wall thickness; gamma ray m Material resistance coefficient, 1.15; gamma ray SC Security class coefficient; p is p b (t) =bearing resistance, related to material properties; p is p li As extreme bearing capacity, it may be: p is p li ＝p d ·γ inc +ρ cont ·g·h；p d Design pressure; gamma ray inc =ratio of accidental pressure to design pressure, 1.1; ρ cont Is the density of the liquid in the pipe; g is gravity acceleration; h is the water depth.
Wherein,,but->
Wherein D is the outer diameter; f (f) y Yield strength for consideration of temperature compromise; f (f) u To take into account the tensile strength of the temperature decrease.
Specifically, the invention calculates the limit pressure born by the submarine pipeline reversely through the formula under the condition that the two sides of the formula are equal. Calculating the limiting pressure, carrying out a series of checks on accessories such as a submarine pipeline, a flange, an anchor and the like according to the limiting pressure, and if the requirement is met, obtaining the limiting pressure as the limiting strength of the submarine pipeline; if the requirement is not met, reducing the limiting pressure by a proper step (the step size is determined by practical application, the invention is not limited in detail), and then carrying out a series of checks on the auxiliary parts such as the submarine pipeline, the flange, the anchoring piece and the like again. And repeating the steps, and finally determining the ultimate strength of the feasible submarine pipeline, so that the design of the submarine pipeline is effectively released, and the conveying capacity of the submarine pipeline is released to the greatest extent on the premise of allowing the strength. Comparing the ultimate strength check result of the submarine pipeline which is related to the combination of 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 shut-off logic, the dynamic water hammer pressure, the minimum sand setting flow of the submarine pipeline and the extreme bearing capacity.
By determining the flow guarantee and the capacity release of the complex oil field group, a proper scheme, such as a preferable scheme, can be obtained according to the determined flow and 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, meanwhile, the good situation that the oil field group is 'newly worn and rolled for development and depends on development' 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 safety production bottleneck of in-service facilities is solved.
The above embodiments are provided to illustrate the technical concept and features of the present invention and are intended to enable those skilled in the art to understand the content of the present invention and implement the same according to the content of the present invention, and not to limit the scope of the present invention. All equivalent changes and modifications made with the scope of the claims should be covered by the claims.
Claims (3)
1. The method for determining the flow guarantee and the productivity release of the complex oilfield group is characterized by comprising the following steps of:
combining large oil fields with different physical properties to obtain a complex oil field group;
according to the type and the turn-off level of a platform which is connected through a submarine pipeline, the weight of each oil field is determined by combining the productivity of each oil field, and the adjustment turn-off logic of the complex oil field group is determined based on the weight of each oil field;
determining the minimum sand setting flow rate of the submarine pipeline by combining the calculation of the minimum sand setting flow rate of the submarine pipeline according to the hydrodynamic viscosity, the solid particle diameter, the solid particle and liquid density difference, the physical properties of the liquid density, the sand content and the sand particle size distribution of the fluid in the submarine pipeline conveying fluid;
according to physical properties of fluid conveyed by the submarine pipeline, emergency shut-off valve parameters and comprehensive factors of operation conditions, selecting the fluid parameters of the submarine pipeline at the maximum conveying amount, and calculating to determine the dynamic water hammer pressure of the submarine pipeline;
acquiring an internal pressure analysis formula of the active subsea pipeline, and calculating according to the internal pressure analysis formula to determine the ultimate bearing capacity of the active subsea pipeline;
and determining the flow guarantee and the capacity release of the complex oil field group according to the adjustment shut-off logic, the dynamic water hammer pressure, the minimum sand setting flow of the submarine pipeline and the limit bearing capacity.
2. The method for determining flow assurance and capacity release of a complex oilfield group of claim 1, wherein the merging the large oilfield groups of different physical properties to obtain the complex oilfield group comprises:
calculating oil, gas and water balance according to physical parameters and yield of each block of each oil field; the physical parameters include: crude oil physical properties, crude oil components, crude oil yield, natural gas physical properties, natural gas components, natural gas yield, water composition, and water yield;
calculating actual load data and electric load data of each process treatment system according to the scale of the production process treatment system of each block of each oil field;
and organically combining the actual load data and the electric load data based on the calculation result of the oil, gas and water balance to obtain the complex oilfield group.
3. The complex oilfield group flow assurance and capacity release determination method of claim 1, wherein the type of platform comprises: the system comprises a central processing platform, a drilling platform, a wellhead platform and a pressurizing platform;
the shutdown level includes: discarding platform turn-off, fire turn-off, production turn-off, unit turn-off.
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| 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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