• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
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  • 优先权
    • 专利摘要:
    The present invention discloses a method for determining a main controlling factor of a high steam injection pressure and optimizing a treatment means, including the following steps. A, analyzing influencing factors of reservoir conditions on a steam pressure in a steam stimulation process of a 5 heavy oil reservoir, and summarizing the influencing factors into two main controlling factors which affect a change of a fluid viscosity and reservoir permeability; B, analyzing a seepage force offluid crude oil in a target oil reservoir, and determining core influence parameters that hinder steam injection; C, analyzing a change ofa fluid resistance under different parameter conditions according to the core influence parameters in step B; D, using a gray correlation method in a mathematical method 10 to analyze a contribution proportion of the influencing factors in step A, and determining the main controlling factors; E, determining the influencing factors according to the main controlling factors, and optimizing the treatment means. The present invention overcomes the conventional tedious analytical method, and can quickly determine the main controlling factor ofthe high pressure in the steam injection process and optimize the treatment technology. 15
    公开号:NL2024626A
    申请号:NL2024626
    申请日:2020-01-09
    公开日:2020-04-23
    发明作者:Shi Leiting；Zhu Shijie；Ye Zhongbin；Zhu Shanshan；Luo Pingya；Shu Zheng；Wang Xiao
    申请人:Univ Southwest Petroleum；
    IPC主号:
    专利说明:

    METHOD FOR DETERMINING A MAIN CONTROLLING FACTOR OF A HIGH STEAM INJECTION PRESSURE AND OPTIMIZING A TREATMENT MEANS
    TECHNICAL FIELD
    The present disclosure relates to the technical field of petroleum exploitation, and more particularly to a method for determining a main controlling factor of a high steam injection pressure and optimizing a treatment means.
    BACKGROUND
    Due to a high viscosity of crude oil in the heavy oil reservoir, the conventional production and exploitation methods are difficult to be effectively applied, and thus the thermal recovery technology is often used. However, there are some difficulties in the thermal recovery process, which affect the application of the thermal recovery technology, and the primary issue is the high injection pressure of steam. Since the high steam injection pressure will affect the steam injection speed, reduce the dryness of the bottom hole, and even fracturing the formation, resulting in steam channeling and affecting the normal production of multiple wells. Therefore, it is necessary to reduce and control the steam injection pressure.
    The research on the influencing factors of the steam injection pressure of the steam stimulation, the influencing factors of the steam injection capacity, and the improved steam injection pressure technology found that there are many factors that affect the high steam injection pressure, e.g. formation energy, formation shale content, crude oil emulsification, reservoir properties, field operation quality, bottom hole pollution, and formation sand production, etc. In view of these problems, the influencing factors are generally analyzed in sequence based on an actual occurrence in a mine. The most commonly used means is to consider the changes brought from a variety of factors on the basis of a detailed modeling, and analyze the proportion of the influence factors in sequence. This method needs a lot of time and a good research basis of the geological characteristics to analyze and obtain the proportion of the influencing factors, which is likely to delay the production, exploitation, and an effective solution of the best time, resulting in a certain loss to the production.
    Therefore, it is necessary to seek a method for quickly determining the main controlling factor of the high pressure in the steam stimulation process of the heavy oil reservoir, thereby guiding the follow-up construction measures.
    SUMMARY
    In view of the above-mentioned problems, the present disclosure provides a method for determining a main controlling factor of a high steam injection pressure and optimizing a treatment means. The objective of the present disclosure is to find the main controlling factor of the high steam injection pressure step by step from various factors that affect the high steam injection pressure during the steam stimulation process by the changing reservoir conditions, i.e. the core influence parameters, thereby quickly determining the corresponding construction measures to be applied in the petroleum exploitation field operation.
    The present disclosure adopts the following technical solution:
    A method for determining the main controlling factor of the high steam injection pressure and optimizing the treatment means, includes the following steps:
    A, analyzing influencing factors of reservoir conditions on a steam pressure in a steam stimulation process of a heavy oil reservoir, summarizing the influencing factors into two main controlling factors which affect a change of a fluid viscosity and reservoir permeability according to a seepage characteristics principle of crude oil in the reservoir.
    B, analyzing a seepage force of fluid crude oil in a target oil reservoir, establishing a force balance before steam injection, analyzing a force characteristic in a steam injection process, and determining core influence parameters that hinder the steam injection.
    C, analyzing a change of a fluid resistance under different parameter conditions according to the core influence parameters in step B.
    D, using a gray correlation method in a mathematical method to analyze a contribution proportion of the influencing factors in step A, determining the main controlling factors of an influence of a reservoir condition on the injection pressure, and thus determining the main controlling factors which influence the high steam injection pressure;
    E, combining the various influencing factors in step A with the target oil reservoir according to the main controlling factors determined in step D, comparing and analyzing in sequence to determine the influencing factors, and optimizing the treatment means based on this.
    Preferably, in step A, the influencing factors of the reservoir conditions on the steam pressure in the steam stimulation process of the heavy oil reservoir include: formation energy, formation shale content, crude oil emulsification, reservoir properties, field operation quality, bottom hole pollution, formation sand production, crude oil heavy component residues, and crude oil degassing. The formation shale content, the reservoir properties, the field operation quality, the bottom hole pollution, and the formation sand production belong to the influencing factors of the reservoir permeability. The crude oil emulsification, the crude oil heavy component residues, and the crude oil degassing belong to the influencing factors of the crude oil viscosity. The formation energy is an objective existence and is affected by a combined effect of other parameters.
    Preferably, in step C, the factor affecting the change of the fluid resistance in the reservoir is the crude oil fluidity, and the permeability and the crude oil viscosity are the main factors affecting the crude oil fluidity. Namely, the permeability and the crude oil viscosity are the main factors affecting the change of the fluid resistance in the reservoir, thereby determining that the combined effect of the permeability and the crude oil viscosity is a core influencing parameter which hinders the steam injection in the reservoir.
    Preferably, the determined influencing factors are categorized to optimize an effective treatment technological means: (1) the determined main controlling factor is the crude oil viscosity, i.e. further analyzing three situations affecting the change of the crude oil viscosity: a change of heavy components, crude oil degassing, and emulsification and thickening; optimizing a viscosity reduction method according to the emulsification and thickening of the crude oil viscosity; (2) the determined main controlling factor is the reservoir permeability, i.e. further analyzing a change of the reservoir physical characteristics, the field operation quality, the formation sand production and other factors; and then determining the field operation application means that improves the reservoir permeability.
    The advantages of the present disclosure are as follows.
    The present invention discloses a method for determining the main controlling factor of the high steam injection pressure and optimizing the treatment means, which overcomes the conventional tedious analytical method, and quickly determines the main controlling factor of the high steam injection pressure in the steam injection process through a combination of an indoor basic data analysis and an actual field operation, thereby providing a direction for the next solution.
    BRIEF DESCRIPTION OF THE DRAWINGS
    In order to clearly describe the technical solution of the embodiment of the present disclosure, the drawings of the embodiment are briefly introduced hereinafter. Obviously, the drawings described hereinafter only refer to a part of the embodiments of the present disclosure rather than limiting the present disclosure.
    FIG. 1 is a schematic diagram showing a stress analysis in a steam injection process of the present disclosure;
    FIG. 2 a schematic diagram showing a contribution analysis of influencing factors of the injection pressure of the present disclosure;
    FIG. 3 is a schematic diagram showing an apparent viscosity of crude oil measured by the present disclosure;
    FIG. 4 is a schematic diagram showing a viscosity change of the emulsified crude oil of the present disclosure; and
    FIG. 5 is a schematic diagram showing a viscosity reducing effect of the preferred viscosity reducers in view of the emulsified crude oil.
    DETAILED DESCRIPTION OF THE EMBODIMENTS
    In order to make the objective, technical solution and advantages of the embodiments of the present disclosure clearer, the technical solution of the embodiments of the present disclosure will be expressly and completely described hereinafter with reference to the drawings of the embodiments of the present disclosure. Obviously, the described embodiments are part of the embodiments of the present invention rather than all the embodiments. Based on the described embodiments of the present disclosure, all other embodiments obtained by those having ordinary skills in the art without creative efforts would fall within the scope of protection of the present disclosure.
    Unless otherwise defined, the technical or scientific terminologies used in the present disclosure shall be an ordinary meaning understood by those having ordinary skills in the field to which the present disclosure belongs. The terminologies include or comprise used in the present disclosure means that the element or object appearing before this terminology contains the element or object listed after this terminology and other equivalents thereof without excluding other elements or objects. The terminologies top, bottom, left, right, and the like are used only to represent a relative position relationship, when the absolute position of the described object changes, the relative position relationship may change accordingly.
    The present invention will be further illustrated hereinafter with reference to the drawings and the embodiments.
    The method for determining the main controlling factor of the high steam injection pressure and optimizing the treatment means includes the following steps.
    A: The influencing factors of reservoir conditions on the steam pressure in the steam stimulation process of the heavy oil reservoir are analyzed, the influencing factors are summarized into the two main controlling factors which affect the fluid viscosity and the reservoir permeability according to the seepage characteristics principle of the crude oil in the reservoir.
    The influencing factors of the reservoir conditions on the steam pressure in the steam stimulation process of the heavy oil reservoir include: formation energy, formation shale content, crude oil emulsification, reservoir properties, field operation quality, bottom hole pollution, formation sand production, crude oil heavy component residues, and crude oil degassing, and other factors. The formation shale content, the reservoir properties, the field operation quality, the bottom hole pollution, and the formation sand production belong to the influencing factors affecting the change of the reservoir permeability. The principle thereof is as follows. The reservoir shale content is high, the high pressure in the process of steam injection is likely to lead to collapse, blocking the effective flow channel of the fluid, or easily triggering the speed sensitivity” phenomenon. The reservoir properties refer to the clay mineral content in the reservoir, cement type and other conditions, the higher the clay mineral content, the more likely to reduce the salt sensitivity, the acid sensitivity and other phenomena of the reservoir permeability. The field operation quality refers to an improper field operation, which leads to the occurrence of the two situations mentioned above; (1) high pressure injection causes a severe migration of the formation pore particles and a severe speed sensitivity phenomenon; (2) improper fluid causes salt sensitivity; bottom hole pollution refers to an improper well completion method, which leads to a decrease of permeability in the near-wellbore area; the formation sand means that a rock turns into free rock particles, which is easy to block the pore channel in the production process, resulting in a decrease of permeability.
    The crude oil emulsification, the crude oil heavy component residues, and the crude oil degassing belong to the influencing factors affecting the change of the crude oil viscosity. The formation energy is an objective existence and is affected by a combined effect of other parameters. The influencing factors of the crude oil viscosity, including three aspects as follows: (1) the more the crude oil component and the heavy component, the higher the crude oil viscosity; (2) emulsification and thickening forms a water-in-oil aqueous emulsion; (3) when the crude oil is degassed, the saturated gas of crude oil decreases its viscosity, and the degassing increases its viscosity.
    B: The seepage force of fluid crude oil in the target reservoir is analyzed, and the force balance is established before the steam injection. Then, the force characteristic during the steam injection is analyzed, and the core influence parameters that hinder the steam injection in the reservoir are determined.
    According to the principle of crude oil seepage in reservoir engineering, the force balance of the formation before the steam injection means that the driving force of the formation overcomes the seepage resistance of the formation crude oil, and the result thereof is equal to the bottom hole flow pressure (shown in FIG. 1). The calculation formula is as follows:
    (1)
    The bottom hole flow pressure formed by the formation driving force, the formation oil seepage resistance, and the flow resistance needs to be overcome in the steam injection process, and the calculation formula thereof is as follows:
    F-Fe-f-f„=Q
    Combining the formulas (1) and (2), the following formula is obtained:
    F-2(f+fJ = Q
    According to the formula (3), the injection pressure F must overcome two times the flow resistance and the bottom hole flow pressure (without considering the bottom hole flow pressure loss). In the formula, Fe-formation driving force, MPa; f-formation oil seepage resistance, MPa; fw-bottom hole flow pressure, MPa; F-steam injection pressure, MPa; Q-injection displacement, m3/d.
    C: According to the core influence parameter in step B, the mathematical formula used for characterizing the parameter is that the injection pressure in step B only needs to overcome a sum of two times the crude oil flow resistance and the bottom hole flow pressure, wherein the bottom hole flow pressure is objective data which can be measured. The flow capacity of crude oil in the porous medium is usually represented by fluidity (a ratio of permeability value K to crude oil viscosity μ). The flow resistance is generally obtained by the steady state method, the unsteady state method, the capillary equilibrium method, and the bubble method to form the flow resistance formula shown in formula (4), and the formula (4) is used to analyze the flow resistance under different data conditions.
    AP /ι·ί; — = αχ
    AL (4)
    In the formula: AP/AL-starting pressure gradient, MPa/m; K-permeability, mD; μ-crude oil viscosity, mPa-s; wherein a and b are constants obtained by experimental measures, i.e. the values of a and b are obtained by the one-dimensional formula of Darcy's law 0= — A — after the value of m D£ the starting pressure gradient and the regression equation are obtained. According to the formula (4), the factors that affect the change of the fluid resistance in the reservoir are the crude oil fluidity. The permeability and the crude oil viscosity are the main factors that affect the crude oil fluidity. Namely, the permeability and the crude oil viscosity are the main factors that affect the change of the fluid resistance in the reservoir, thereby determining that the combined effect of the permeability and the crude oil viscosity is the core influence parameter that hinders the steam injection in the reservoir.
    D: the gray correlation method in the mathematical method is used to analyze the contribution proportion of the influencing factors in step A, the main controlling factors of the influence of the reservoir conditions on the injection pressure are determined, thereby the main controlling factors affecting the high steam injection pressure are determined. The calculating data in step C (the crude oil viscosity, the permeability, the starting pressure gradient, and relevant parameters are shown in Table 1), and the flow resistance formula (5) of a target area is determined by an indoor unsteady state method (wherein a=0.1237, b=-1.106):
    (5)
    Table 1 parameters of crude oil viscosity, permeability, and starting pressure gradient
    ΔΡ LK 1106 — = 0.1237 X (-)
    AL uj
    Viscosity, mPa-sPermeability, pm2 Starting pressure gradient, MPa/m10002500.5720004000.7330005500.8140007000.8550008500.88600010000.90700011500.91800013000.92900014500.931000016000.941100017500.941200019000.951300020500.951400022000.961500023500.961600025000.961700026500.971800028000.971900029500.972000031000.972100032500.97
    2200034000.982300035500.982400037000.982500038500.982500025020.152400040011.46230005507.68220007005.60210008504.292000010003.401900011502.751800013002.261700014501.881600016001.581500017501.331400019001.131300020500.951200022000.811100023500.681000025000.57900026500.48800028000.40700029500.32600031000.26500032500.20400034000.15300035500.10200037000.06100038500.03
    The gray correlation method is used to analyze the data in Table 1 (as shown in FIG. 2) by using software MATLAB, and the computed results thereof are shown in Table 2:
    Table 2 contribution analysis of the injection pressure
    TypeFormula 5Viscosity, mPa-sPermeability, 1 χ10'3μΓη2
    correlation coefficient0.01340.0068contribution66.34%33.66%
    According to Table 2, the contribution of the change of the crude oil viscosity is approximately 2 times of the reservoir permeability. Therefore, the change of crude oil viscosity is the main controlling factor affecting the steam injection pressure in terms of the target heavy oil reservoir.
    E, the various influencing factors in step A are combined with the target oil reservoir according to the main controlling factors determined in step D, which are compared and analyzed in sequence to determine the influencing factors, and the treatment means is selected based on this. The determined influencing factors are categorized to optimize the effective treatment technological means: (1) the determined main controlling factor is the crude oil viscosity, i.e. the influencing factors affecting the change of the crude oil viscosity are further analyzed, including the following three situations: a change of heavy components, crude oil degassing, and emulsification and thickening; optimizing a viscosity reduction method according to the influencing factors affecting the change of the crude oil viscosity; (2) the determined main controlling factor is the reservoir permeability, i.e. the change of the reservoir physical characteristics, the field operation quality, the formation sand production and other factors are further analyzed; and then the field operation application means that improves the reservoir permeability is determined.
    In view of the crude oil viscosity found as the main controlling factor, the method for determining the influencing factors affecting the crude oil viscosity is further determined, which are all obtained through experimental research, and the influences of different conditions on the crude oil viscosity are analyzed by experimental means with different purposes. The method for analyzing and testing the crude oil viscosity is as follows.
    1. The experimental principle and the steps for determining the components in crude oil are as follows.
    (1) Asphaltenes separation principle: Asphaltenes are insoluble in n-heptane and are soluble in benzene.
    (2) Methods and steps: The crude oil sample m (1-3 g) is taken and dissolved in 80 mL nheptane, and is heated to reflux in the flask (flat bottom or triangular flask) for 30 min (the soluble components are completely dissolved), which is put aside for 1 h, and then is filtered by a filter paper at the normal pressure. The precipitation (asphaltenes) is wrapped in the filter paper and is placed in an extractor, and is extracted by the n-heptane filtrate for 4-5 h until colorless. The extraction solution (deasphalted oil, n-heptane is used as a solvent) is reserved. After that, the precipitation (asphaltenes are wrapped in the filter paper) is extracted by benzene (70 mL) to colorless. A part of benzene in the extraction solution is evaporated and recycled, and the remaining extraction solution is dried and weighed Gi.
    Wj = X 100% (6)
    The solution containing n-pentane after asphaltenes are separated is evaporated by a rotary evaporator to evaporate pentane. Since the boiling point of n-pentane is only 36°C, thus, under an appropriate temperature setting, it can ensure that n-pentane is evaporated without losing the heavy oil sample, and finally a certain amount of deasphalted oil is obtained. Different proportions of the heavy component content are prepared by the separated asphaltenes, the apparent viscosity of crude oil is measured under the temperature of 50°, and the crude oil viscosity with different heavy component contents is analyzed and compared. The test results thereof are shown in FIG. 3 (measured according to the People's Republic of China Oil and Gas Industry Standard SY/T75502000).
    2. crude oil emulsification
    Different proportions of the oil and water mixture (oil: water = 9:1,8:2, 7:3, 6:4, 5:5, 4:6, 3:7, 2:8, 1:9), the viscosity is measured by the viscometer, and the test results are shown in FIG. 4.
    3. Crude oil degassing (1) Degassed crude oil - the crude oil is heated to a specified temperature, and the rheological curve is measured at 10 s’1;
    (2) Formation crude oil - 30 mL crude oil is added in a closed container, after the temperature is increased to the formation temperature, a certain proportion of natural gas is added, and is pressurized to the formation pressure. The rotor rotates at a constant speed so that the natural gas is fully integrated into the crude oil, and then a measurement is performed (the test method is in accordance with the Oil and Gas Industry Standard of the People's Republic of China, Analysis Method of Fluid Properties of Oil and Gas Reservoirs (SY/T 5542-2009)).
    According to the experimental steps, the obtained experimental results are shown in Table 3.
    Table 3 Viscosity-temperature relationship under different crude oil conditions
    temperature (°C)Degassed crude (mPa s)Formation oil (mPas)5262788808801360.764420100681.192918120271.14203115056.363720032.054953005.55176
    Through the analysis of several factors that affect the crude oil viscosity, a further analysis of the crude oil output in the target reservoir indicates that the emulsification of crude oil is serious, and the viscosity of the emulsified crude oil increases greatly, as shown in FIG. 4. In view of the high injection pressure situation caused by the emulsification and thickening of crude oil, the viscosity reducer which can improve the emulsification condition of crude oil is optimized, e.g. reversed phase demulsifier or water-soluble viscosity reducer. FIG. 5 shows the viscosity reducing effect of several kinds of watersoluble viscosity reducers under the condition of 40% water content. It can be seen that the water soluble viscosity reducer can effectively reduce the viscosity change caused by crude oil emulsification.
    The above description is only the preferred embodiments ofthe present invention, which are not intended to limit the present invention in any form. The preferred embodiments are disclosed by the present invention, while these embodiments are not intended to limit the present disclosure. Any person familiar with the present profession can make some changes or modify the technical content to equivalent embodiments by using the disclosed technical content without departing from the scope of the technical solution ofthe present disclosure. However, any content that does not depart from the technical solution ofthe present invention, any simple modifications, equivalent changes, and improvements made to the above-mentioned embodiments based on the technical essence ofthe present invention would fall within the scope ofthe technical solution ofthe present invention.
    权利要求:
    Claims (4)
    [1]
    CONCLUSIONS
    A method for determining an important determinant of high steam injection pressure and optimizing a treating agent, characterized in that it comprises the following steps:
    A, Analyzing reservoir condition influencing factors on a steam pressure in a steam stimulation process of a heavy oil reservoir, the influencing factors are summarized in two main determinants influencing a change of fluid viscosity and reservoir permeability according to a crude characteristics principle of crude oil in the reservoir ;
    B, analyzing a penetration force of liquid crude oil into a target oil reservoir, determining a force balance before steam injection, analyzing a force characteristic in a steam injection process and determining core influence parameters that impede steam injection;
    C, analyzing a change of a fluid resistance under different parameter conditions according to the core influence parameters in step B;
    D, using a Gray correlation method in a mathematical method to analyze a contribution share of the influencing factors in step A, determining the main determinants of an influence of the reservoir conditions on the injection pressure, and determining the main determinants which affect the high steam injection pressure; and
    E, combining the different influencing factors in step A with the target oil reservoir according to the main determining factors determined in step D, comparing and analyzing in order to determine the influencing factors, and optimizing the treating agent based on this.
    [2]
    Method for determining the main determining factor of the high steam injection pressure and optimizing the treating agent according to claim 1, characterized in that in step A the influencing factors of the reservoir conditions on the steam pressure in the steam stimulation process of the heavy reservoir oil includes: formation energy, formation shale content, crude oil emulsification, reservoir properties, quality of field operation, bottom hole pollution, formation sand production, heavy component crude oil residues and crude oil degassing; wherein the content of the formation shale, the properties of the reservoir, the quality of the field action, the bottom hole contamination and the production of formation sand are among influencing factors of the permeability of the reservoir; the emulsification of the crude oil, heavy component residues of the crude oil and degassing of the crude oil are among influencing factors of the viscosity of the oil; and the formation energy is an objective entity and is influenced by a combined effect of other parameters.
    [3]
    Method for determining the main determining factor of the high steam injection pressure and optimizing the treating agent according to claim 1, characterized in that in step C a factor influencing the change of the fluid resistance in the reservoir, the fluidity of crude oil and the permeability and viscosity of the crude oil are important factors affecting the fluidity of the crude oil, namely the permeability and viscosity of the crude oil are the main factors influencing the change in fluid resistance in the reservoir, causing it is determined that a combined effect of the permeability and the viscosity of crude oil is a nuclear influencing parameter that hinders the steam injection into the reservoir.
    [4]
    Method for determining the main determining factor of the high steam injection pressure and optimizing the treatment agent according to claim 1, characterized in that the determined influencing factors are categorized to optimize an effective technological treatment: (1) the determined main the determining factor is the viscosity of crude oil, ie the further analysis of three situations that influence the change in the viscosity of crude oil: a change in heavy components, the degassing of crude oil and emulsification and thickening; optimizing a viscosity reduction method according to the above various modes influencing the change in crude oil viscosity; (2) the determined key determining factor is the permeability of the reservoir, i.e., further analyzing a change in physical properties of the reservoir, the quality of the field action, the production of formation sand and other factors; and then determining a field processing application that improves the permeability of the reservoir.
    类似技术:
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    同族专利:
    公开号 | 公开日
    CN109826602A|2019-05-31|
    CN109826602B|2019-10-22|
    NL2024626B1|2020-08-14|
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    法律状态:
    优先权:
    申请号 | 申请日 | 专利标题
    CN201910065928.0A|CN109826602B|2019-01-24|2019-01-24|The high Dominated Factors judgement of steam injection pressure and governing measure preferred method|
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