CN114034729B - Ultra-high temperature-based underground sand consolidation strengthening evaluation method - Google Patents

Ultra-high temperature-based underground sand consolidation strengthening evaluation method Download PDF

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CN114034729B
CN114034729B CN202210019795.5A CN202210019795A CN114034729B CN 114034729 B CN114034729 B CN 114034729B CN 202210019795 A CN202210019795 A CN 202210019795A CN 114034729 B CN114034729 B CN 114034729B
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谭晓华
王一航
李晓平
李溢龙
陈昌浩
奎明清
唐艺月
张研
李�杰
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Abstract

The invention belongs to the field of oil and gas field development, and particularly relates to an underground sand consolidation strengthening evaluation method based on ultrahigh temperature; the invention aims to: silicon carbide powder and clay are mixed into the core of the sandstone reservoir after being heated at the ultrahigh temperature of 1500 ℃ to change the mineral components of the core, so that the modified artificial consolidated core is artificially reformed into a honeycomb structure under the ultrahigh temperature condition, and the original sand consolidation capability of the sandstone reservoir is enhanced; the technical scheme includes that an X-ray diffraction experiment and an electron microscope scanning experiment are carried out on sandstone reservoir cores before and after severe deformation, porosity, gas permeability and sand production rate are evaluated, various parameters influencing the sand consolidation capability of the reservoir are comprehensively considered, and finally, the underground sand consolidation strengthening evaluation system coefficient is calculated. Compared with the prior art, the invention has the following advantages: (1) the evaluation coefficient is visual, and the evaluation system is convenient and effective; (2) the evaluation system gives consideration to multiple factors influencing sand production, so that the evaluation result is more reliable; (3) the evaluation method is easy to popularize.

Description

Ultra-high temperature-based underground sand consolidation strengthening evaluation method
Technical Field
The invention belongs to the field of oil and gas field development, and particularly relates to an underground sand consolidation strengthening evaluation method based on ultrahigh temperature.
Background
At present, both foreign exploitation practical experience and domestic exploration show that the key factor limiting effective development of an oil well is the sand production problem of the oil well, and the main reason of sand production of the oil well is formation cementation looseness and single-layer outburst when sand prevention liquid enters a formation due to poor formation permeability. At present, the sand control process of an oil well is mature, and various chemical, mechanical and composite sand control technologies are widely applied to actual work production. However, most of the existing sand control processes are used for sand consolidation in a mode of finally forming an artificial well wall, the cost required by the process is too high in the whole oil field production and development process, and the traditional sand control process technology needs to run through the whole development process, so that the oil and gas layer is inevitably polluted. The invention relates to a method for modifying a reservoir by mixing non-metallic carbide powder into the reservoir under a high-temperature and high-pressure environment and then injecting inorganic salt ore adhesive and clay, wherein the structure of the reservoir and the mineralization degree of the reservoir are changed, so that the reservoir structure is manually modified into a honeycomb shape, the modified reservoir is similar to the structure of foamed ceramic, sand fixation of an oil well is facilitated, and the method is different from the traditional sand fixation.
The preparation process of the foamed ceramic is researched in the preparation and performance of the SiC foamed ceramic/Fe-based bicontinuous phase composite material, and the result shows that the surface of the foamed ceramic can be oxidized at the high temperature of 1250 ℃ to generate a barrier layer, and the generated SiO2Inhibiting the generation of brittle compounds, and improving the interface between organism and reinforcement. The relation between drying, powder making, dry pressing, sintering and sintering performances in preparation is researched in silicon carbide foam ceramic slurry components and sintering performances, and the research result shows that the open porosity and the sintering temperature are in negative correlation change; the sintering strength is mainly contributed by the generation of mullite and the wrapping of silicon carbide particles, the refractoriness of samples with different components reaches about 1730 ℃, XRD whole-rock clay analysis shows that the mullite phase is obviously increased after sintering, and the sintering performance is in positive correlation with the generation of the mullite phase. Innovation is carried out on resin sand consolidation in Liaohe oil field L-block fine silt oil reservoir sand consolidation technical experimental research, the net-shaped molecular structure of the resin enables contact points between sand and gravel and between the sand and a well wall to be mutually cemented, a strong polar group in a resin molecule has a strong affinity effect with a polar group of the sand, and on the basis, liquid resin and a curing agent are injected into a sand producing stratum, so that the reaction degree between the sand and the resin can be well enhanced. The research in the sandstone reservoir sensitivity mechanism research in Wangzhuangyining sea area finds that: the stratum burial depth is in positive correlation with diagenesis intensity, and the clay minerals of the sandstone reservoir are mutually converted under the conditions that: the halloysite is converted into kaolinite, the montmorillonite is converted into illite, and the sandstone reservoirs at different layers have different physical property characteristics, sensitivity characteristics and sand production degrees due to different combination relations of clay mineral types and clay minerals. In the research and application of silicate sand consolidation agent, a small amount of organic silicon is added into the sand consolidation agent to modify the adhesive, so that the adhesive gradually forms a substance which is formed by Si-O bonds and contains a three-dimensional network structure with a plurality of hydroxyl groups, and the modified chemical sand consolidation agent can well control oilAnd (4) sand production of the well. In the feasibility test research and application of the offshore oil field sand heating and consolidating process, a circulating hot fluid sand consolidating process is adopted, a reservoir section is heated to 70 ℃, and under the condition of only considering an original shaft temperature field, the artificial well wall coating temperature and the sand and stone bonding strength are in positive correlation, namely the sand consolidating effect is better when the temperature is higher.
The preparation method of the foamed ceramic and the composition and the property thereof are determined, and by using the preparation method, after the porosity, the gas logging permeability, the sand production coefficient and the sand production rate of the core under the conditions of high temperature and high pressure are calculated, the changes of the structure, the sand production degree, the porosity, the permeability and the sand production rate of the artificially consolidated core after the non-metallic carbide powder, the inorganic salt ore binder and the clay are injected into the reservoir under the conditions of high temperature and high pressure are analyzed, and the sand consolidation capability and the permeability and circulation capability to water and gas of the artificially consolidated core are analyzed, so that the improvement of the existing sand consolidation process and the innovative strengthened sand consolidation method in the production process of oil well development are realized.
Disclosure of Invention
The invention aims to: the original sand consolidation capability of the sandstone reservoir is enhanced, and the problem that the permeability of the reservoir and the earth surface is adversely affected after cementation in the conventional oil well sand control process is solved; the problem that the sand control technology can only be adopted in the early mining stage is solved; the problem of traditional sand control technique when the consolidated sand reduces the oil field productivity is solved. According to the invention, by using the process technology of firing the foamed ceramic at high temperature and according to the property that each hole of the foamed ceramic is mutually separated by continuous ceramic matrixes, the advantage of strong porous high-permeability stability after the foamed ceramic is prepared is simulated, and an underground reservoir stratum is tried to be transformed into a porous material with the same high-temperature characteristic. The firing principle of the foamed ceramic is applied to the modification of the properties and the structure of the sandstone reservoir, so that a stable barrier is formed inside the sandstone reservoir to improve the oil layer strength, and sand is not forcibly solidified by a method of artificially molding an external permeability barrier; therefore, the porosity and the permeability of the sandstone reservoir are correspondingly improved, the quick sensitivity and the pore permeability of the reservoir are optimized, the stratum sand rack is effectively protected from being damaged, and the effect of strengthening the sand consolidation capability of the reservoir is finally achieved on the premise of not reducing the productivity.
In order to achieve the aim, the invention provides an ultrahigh temperature-based downhole sand consolidation strengthening evaluation method, which comprises the following steps of:
s100, obtaining sandstone reservoir cores at the same layer, and heating the sandstone reservoir cores at the ultrahigh temperature of 1500 ℃ by using a box-type resistance furnace;
s200, measuring the porosity phi of the sandstone reservoir core heated at the ultrahigh temperature of 1500 DEG C0Permeability with gasg1；
S300, performing a damage experiment on the sandstone reservoir rock core heated at the ultrahigh temperature of 1500 ℃ to obtain a sand production coefficient A1；
Figure GDA0003524772290000021
In the formula, A is the sand production coefficient of the rock core and has no dimensional quantity; sigmarThe unit is the core failure stress in the experiment and is MPa; sigmavThe unit is the near-well reservoir vertical stress in the experiment and is MPa; 0.86 is a correction coefficient and has no dimensional quantity;
s400, performing an X-ray diffraction experiment and an electron microscope scanning experiment on the sandstone reservoir core heated at the ultrahigh temperature of 1500 ℃, and analyzing the mineral components and the pore structure of the rock sample; grinding the sandstone reservoir rock core, mixing silicon carbide powder with the volume content of 25% of the rock sample into the ground sandstone reservoir rock core, and injecting mullite-rich clay; finally, the cross-linking agent mixture and the denatured sandstone reservoir core are cemented and remolded into a honeycomb-shaped artificial consolidated core at high temperature and high pressure;
s500, heating the honeycomb artificial consolidated core at the ultrahigh temperature of 1500 ℃ by using a box-type resistance furnace;
s600, measuring the porosity phi of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 DEG C1Calculating the porosity evaluation coefficient phi of the rock core before and after remodeling at the ultra-high temperature of 1500 ℃, and evaluating the porosity of the rock core, wherein the relation of the porosity evaluation coefficient phi is as follows;
Figure GDA0003524772290000031
in the formula phi1The porosity of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 ℃ is calculated in unit; phi0The unit of the porosity of the sandstone reservoir core is the porosity of the sandstone reservoir core heated at the ultrahigh temperature of 1500 ℃; phi is the porosity evaluation coefficient of the rock core before and after remodeling at the ultrahigh temperature of 1500 ℃, and has no dimensional quantity;
s700, measuring gas logging permeability K of honeycomb artificial consolidated core heated at ultra-high temperature of 1500 DEG Cg2Calculating a gas logging permeability evaluation coefficient J of the rock core before and after the remodeling at the ultra-high temperature of 1500 ℃, and carrying out gas logging permeability evaluation on the rock core, wherein the gas logging permeability evaluation coefficient J has the following relational expression;
Figure GDA0003524772290000032
in the formula, Kg1Gas logging permeability of a sandstone reservoir core heated at the ultrahigh temperature of 1500 ℃, wherein the unit is mD; kg2Gas logging permeability of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 ℃, wherein the unit is mD; j is the gas logging permeability evaluation coefficient of the rock core before and after the remodeling at the ultrahigh temperature of 1500 ℃, and has no dimensional quantity;
s800, performing a destruction experiment on the honeycomb artificial consolidated core heated at the ultrahigh temperature of 1500 ℃ to obtain a sand production coefficient A2(ii) a Performing core sand production rate evaluation, and calculating a core sand production rate evaluation coefficient Z before and after remodeling at the ultrahigh temperature of 1500 ℃;
Z＝-0.5(A2-A1)
in the formula, Z is the sand production rate evaluation coefficient of the rock core before and after the remodeling at the ultrahigh temperature of 1500 ℃, and is free of dimensional quantity; a. the1The sand production coefficient of the sandstone reservoir core after being heated at the ultrahigh temperature of 1500 ℃ is dimensionless; a. the2The sand production coefficient of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 ℃ is dimensionless;
s900, carrying out an X-ray diffraction experiment and an electron microscope scanning experiment on the honeycomb artificial consolidated core heated at the ultrahigh temperature of 1500 ℃, analyzing mineral components and a pore structure of the honeycomb artificial consolidated core heated at the ultrahigh temperature of 1500 ℃, and comparing to obtain that the sand consolidation capability of the reservoir can be improved by artificially enriching mullite in the reservoir; based on that the mineral components and the pore structure of the manually consolidated core are changed after the core is remolded, substituting the changed mineral components and the pore structure into the porosity evaluation coefficient, the gas logging permeability evaluation coefficient and the sand production evaluation coefficient of the core before and after the core is remolded at the ultrahigh temperature of 1500 ℃, performing underground sand consolidation strengthening evaluation, and calculating an underground sand consolidation strengthening evaluation system coefficient G;
G＝0.3φ+0.2J+Z
in the formula, G is the coefficient of the underground sand consolidation strengthening evaluation system and has no dimensional quantity; phi is the porosity evaluation coefficient of the rock core before and after remodeling at the ultrahigh temperature of 1500 ℃, and has no dimensional quantity; j is the gas logging permeability evaluation coefficient of the rock core before and after the remodeling at the ultrahigh temperature of 1500 ℃, and has no dimensional quantity; z is the sand production rate evaluation coefficient of the rock core before and after the remodeling at the ultrahigh temperature of 1500 ℃, and is free of dimensional quantity;
when G is more than-1 and less than 0, the strengthening effect of the sand-fixing ability of the reservoir stratum after remodeling is poor; when G is 0, the sand fixing capacity of the reservoir after remodeling is not strengthened; when G is more than 0 and less than or equal to 0.5, the sand fixing capacity of the reservoir after remolding is slightly strengthened; when G is more than 0.5 and less than or equal to 1, the sand fixing capacity of the reservoir stratum after remodeling is obviously enhanced; when G is more than 1, the sand fixing capacity of the reservoir after remodeling is remarkably strengthened.
Further, the underground sand consolidation strengthening evaluation method based on the ultrahigh temperature is characterized by comprising the following steps: the evaluation of the core porosity is specifically that when phi is less than 0, the reservoir pore characteristics are more compact after being remolded; when phi is 0, the pore characteristics of the reservoir after remodeling are not changed; when phi is more than 0 and less than or equal to 0.2, the pore characteristics of the reservoir are slightly improved after being remolded; when phi is more than 0.2 and less than 0.4, the improvement effect is good after the pore characteristics of the reservoir stratum are remodeled; when phi is more than or equal to 0.4, the improved effect after the pore characteristics of the reservoir stratum are remolded is excellent; the core gas logging permeability evaluation specifically comprises that when J is less than 0, the water-gas flow capacity of a reservoir layer is poor; when J is 0, the water-gas flow capacity of the reservoir is not changed; when J is more than 0 and less than or equal to 1, the water and gas flow capacity of the reservoir is slightly enhanced; when J is more than 1 and less than 2, the water and gas flow capacity of the reservoir is enhanced; when J is more than or equal to 2, the water-gas flow capacity of the reservoir is greatly enhanced; the sand production rate evaluation specifically comprises the following steps that when Z is more than-0.1 and less than 0, free sand grains in a reservoir are slightly increased after remodeling; when Z is 0, the amount of reservoir free sand after remodeling is unchanged; when Z is more than 0 and less than or equal to 0.1, the free sand grains of the reservoir are slightly reduced after the remodeling; when Z is more than 0.1 and less than or equal to 0.2, the free sand grains of the reservoir are obviously reduced after the remolding; when Z > 0.2, the remodeled reservoir had no free sand.
Further, the underground sand consolidation strengthening evaluation method based on the ultrahigh temperature is characterized by comprising the following steps: the cross-linking agent mixture is specifically a mixture of 36% of phenolic resin, 17% of polyimide resin, 21% of cementing agent, 14% of curing agent and 12% of coupling agent.
Compared with the prior art, the invention has the following beneficial effects: (1) the evaluation coefficient is visual, and the evaluation system is convenient and effective; (2) the evaluation system gives consideration to multiple factors influencing sand production, so that the evaluation result is more reliable; (3) the evaluation method is easy to popularize.
Drawings
In the drawings:
FIG. 1 is a technical scheme of the method.
Figure 2 is an X-ray diffraction pattern of sandstone reservoir core S11 after heating at ultra-high temperature of 1500 ℃.
Figure 3 is an X-ray diffraction pattern of sandstone reservoir core S12 after heating at ultra-high temperature of 1500 ℃.
Figure 4 is an electron microscope scan of sandstone reservoir core S11 after heating at 1500 deg.c at ultra-high temperature.
Figure 5 is an electron microscope scan of sandstone reservoir core S12 after heating at 1500 deg.c at ultra-high temperature.
FIG. 6 is an X-ray diffraction pattern of a honeycomb shaped artificially consolidated core S11 after heating at a super high temperature of 1500 ℃.
FIG. 7 is an X-ray diffraction pattern of a honeycomb shaped artificially consolidated core S12 after heating at a super high temperature of 1500 ℃.
FIG. 8 is an electron microscope scan of a honeycomb shaped artificially consolidated core S11 after heating at a super high temperature of 1500 ℃.
FIG. 9 is an electron microscope scan of a honeycomb shaped artificially consolidated core S12 after heating at a super high temperature of 1500 ℃.
Detailed Description
The present invention will be further described with reference to the following embodiments and drawings.
The invention provides an ultra-high temperature-based underground consolidated sand reinforcement evaluation method, and FIG. 1 is a technical route diagram of the method, and the method comprises the following steps:
firstly, obtaining sandstone reservoir rock cores S11 and S12 with the same layer, heating the sandstone reservoir rock cores to 1500 ℃ at ultrahigh temperature through a box-type resistance furnace, and measuring the porosity phi of the sandstone reservoir rock cores0And its gas permeability K at that timeg1；
TABLE 1
Core number Porosity phi0(％) Gas permeability Kg1(mD)
S11 10.25 0.0469
S12 12.37 0.1191
Secondly, cutting two sandstone reservoir cores heated at the ultrahigh temperature of 1500 ℃, respectively taking half of the sandstone reservoir cores to perform a core failure experiment, measuring failure stress when the cores are failed and near-well reservoir vertical stress at the moment, and calculating a sand production coefficient A of the sandstone reservoir cores heated at the ultrahigh temperature of 1500 DEG C1；
Figure GDA0003524772290000061
In the formula, A1The sand production coefficient of the sandstone reservoir core after being heated at the ultrahigh temperature of 1500 ℃ is dimensionless; sigmar1The unit is the core failure stress in the experiment and is MPa; sigmav1The unit is the near-well reservoir vertical stress in the experiment and is MPa; 0.86 is a correction coefficient and has no dimensional quantity;
TABLE 2
Core number Failure stress sigmar1(MPa) Vertical stress sigmav1(MPa) Coefficient of sand production A1
S11 120.41 133.34 1.28
S12 113.21 117.54 1.20
Thirdly, performing an X-ray diffraction experiment and an electron microscope scanning experiment on the sandstone reservoir core heated at the ultrahigh temperature of 1500 ℃ to obtain an X-ray diffraction pattern of the sandstone reservoir core at the moment, such as the images in the figures 2 and 3, and performing X-ray diffraction total rock quantitative analysis on the sandstone reservoir core; obtaining an electron microscope scanning image of the sandstone reservoir core at the moment, and analyzing the electron microscope scanning result of the sandstone reservoir core as shown in fig. 4 and 5;
TABLE 3
Rock sample Content of clay Quartz Potassium feldspar Plagioclase feldspar Calcite Dolomite Mullite Hematite (iron ore) Pyrite Zeolite
S11 15.4 49.0 1.7 31.3 1.2 0.0 0.0 0.0 1.4 0.0
S12 6.7 56.9 7.3 27.8 0.8 0.0 0.0 0.0 0.0 0.5
Fourthly, grinding the sandstone reservoir cores of S11 and S12, fully mixing silicon carbide powder with the volume of 25 percent of the sandstone reservoir core and the ground sandstone reservoir core to prepare an artificial core mixed material, and injecting clay with the underground layer in a mullite-rich section into the artificial core mixed material; preparing mineralized water with the same mineralization degree as the formation water of the original area where the real rock core is located, uniformly mixing the mineralized water with the artificial rock core mixed material, pouring the mixture into a rock core mould, pressurizing the rock core mould, compacting the artificial rock core mixed material in the rock core mould by using high pressure, and sintering the compacted mixture at 1500 ℃ at ultrahigh temperature to meet the experimental temperature condition; and fully reacting the artificial core mixed material in the mould under the conditions of high temperature and high pressure to finally obtain the cemented and remolded honeycomb artificial consolidated core.
Fifthly, heating the remolded honeycomb artificial consolidation core at the ultrahigh temperature of 1500 ℃ through a box type resistance furnace, and measuring the porosity phi of the honeycomb artificial consolidation core heated at the ultrahigh temperature of 1500 DEG C1Calculating the porosity evaluation coefficient phi of the core before and after remodeling at the ultra-high temperature of 1500 ℃, and evaluating the porosity of the honeycomb artificial consolidation core by the coefficient phi, wherein the porosity evaluation coefficient phi has the following relational expression:
Figure GDA0003524772290000071
in the formula phi1The porosity of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 ℃ is calculated in unit; phi0The unit of the porosity of the sandstone reservoir core is the porosity of the sandstone reservoir core heated at the ultrahigh temperature of 1500 ℃; phi is the porosity evaluation coefficient of the rock core before and after remodeling at the ultrahigh temperature of 1500 ℃, and has no dimensional quantity;
TABLE 4
Core number Porosity phi1(％)
S11 12.21
S12 16.44
TABLE 5
Serial number Coefficient of porosity evaluation Φ Evaluation of pore improvement
1 Φ＜0 The pore characteristics of the reservoir are more compact after being remolded
2 Φ＝0 Reservoir pore characteristics were not altered
3 0＜Φ≤0.2 Slight improvement after remodeling of reservoir pore characteristics
4 0.2＜Φ＜0.4 The improved effect after the pore characteristics of the reservoir stratum are remodeled is good
5 Φ≥0.4 The improved effect of the remolded reservoir pore characteristics is excellent
TABLE 6
Core number Coefficient of porosity evaluation Φ
S11 0.19
S12 0.33
According to the pore improvement evaluation table, the pore characteristics of the reshaped honeycomb artificial consolidated core S11 are slightly improved and the pore characteristics of the reshaped honeycomb artificial consolidated core S12 are improved in a good effect under the ultrahigh-temperature environment of 1500 ℃;
sixthly, measuring the gas logging permeability of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 ℃, calculating the gas logging permeability evaluation coefficient J of the core before and after being remolded at the ultrahigh temperature of 1500 ℃, and performing gas logging permeability improvement evaluation on the honeycomb artificial consolidated core, wherein the gas logging permeability evaluation coefficient J has the following relation formula:
Figure GDA0003524772290000081
in the formula, Kg1Gas logging permeability of a sandstone reservoir core heated at the ultrahigh temperature of 1500 ℃, wherein the unit is mD; kg2Gas logging permeability of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 ℃, wherein the unit is mD; j is the gas logging permeability evaluation coefficient of the rock core before and after the remodeling at the ultrahigh temperature of 1500 ℃, and has no dimensional quantity;
TABLE 7
Core number Gas permeability Kg2(mD)
S11 0.0731
S12 0.3347
TABLE 8
Serial number Permeability evaluation coefficient J Permeability optimization evaluation
1 J＜0 Poor water and gas flow capacity of reservoir
2 J＝0 The water-gas flow capacity of the reservoir is not changed
3 0＜J≤1 Slightly enhanced water and gas flow capacity of reservoir
4 1＜J＜2 Enhanced water and gas flow capacity of reservoir
5 J≥2 Greatly enhancing the water and gas flow capacity of the reservoir
TABLE 9
Core number Permeability evaluation coefficient J
S11 0.558
S12 1.806
Combining with a permeability optimization evaluation table, the seepage capability of the reshaped honeycomb artificial consolidated core S11 to water vapor is slightly enhanced, and the seepage capability of the reshaped honeycomb artificial consolidated core S12 to water vapor is enhanced in the ultrahigh temperature environment of 1500 ℃;
seventhly, carrying out a destruction experiment on the honeycomb artificial consolidated core heated at the ultrahigh temperature of 1500 ℃ to obtain core destruction stress sigmar2And near-well reservoir vertical stress σv2Calculating the sand production coefficient A of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 DEG C2From the sand production coefficient A of the core before and after remodeling1、A2Calculating the sand production coefficient Z of the rock core before and after remolding; coefficient of sand production A2The relationship is as follows:
Figure GDA0003524772290000091
in the formula, A2The sand production coefficient of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 ℃ is dimensionless; sigmar2The unit is the core failure stress in the experiment and is MPa; sigmav2The unit is the near-well reservoir vertical stress in the experiment and is MPa; 0.86 is a correction coefficient and has no dimensional quantity;
watch 10
Core number Failure stress sigmar2(MPa) Vertical stress sigmav2(MPa) Coefficient of sand production A2
S11 119.34 120.91 1.17
S12 109.42 92.34 0.98
The relational expression of the sand production rate evaluation coefficient Z of the rock core before and after the ultra-high temperature 1500 ℃ remodeling is as follows:
Z＝-0.5(A2-A1)
in the formula, Z is the sand production rate evaluation coefficient of the rock core before and after the remodeling at the ultrahigh temperature of 1500 ℃, and is free of dimensional quantity; a. the1The sand production coefficient of the sandstone reservoir core after being heated at the ultrahigh temperature of 1500 ℃ is dimensionless; a. the2The sand production coefficient of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 ℃ is dimensionless;
TABLE 11
Serial number Sand yield evaluation coefficient Z Definition of sand production effect
1 -0.1＜Z＜0 Slight increase of free sand grains in reservoir
2 Z＝0 The free sand amount of the reservoir is not changed
3 0＜Z≤0.1 Slight reduction of free sand in reservoir
4 0.1＜Z≤0.2 Free sand grains in reservoir are obviously reduced
5 Z＞0.2 Free sand grains are not contained in reservoir
Substituting sand production coefficient A of core before and after remolding1、A2Evaluating the sand production rate of the rock core, and calculating a sand rate evaluation coefficient Z:
TABLE 12
Core number Evaluation coefficient of sand yield
S11 0.055
S12 0.113
The sand rate evaluation coefficient Z of the calculated result can be used for obtaining that the free sand grains of the storage layer of the reshaped honeycomb artificial consolidated core S11 are slightly reduced and the free sand grains of the storage layer of the reshaped honeycomb artificial consolidated core S12 are obviously reduced under the ultrahigh temperature environment of 1500 ℃; the change in core porosity and permeability before and after combined remodeling can be derived as: the pore permeability characteristic improvement and the free sand amount reduction of the reshaped honeycomb artificial consolidated core both provide positive effects on the sand consolidation capability of the reservoir;
eighthly, performing an X-ray diffraction experiment and an electron microscope scanning experiment on the honeycomb artificial consolidated core heated at the ultrahigh temperature of 1500 ℃ to obtain an X-ray diffraction pattern of the honeycomb artificial consolidated core at the moment, such as the X-ray diffraction pattern shown in figures 6 and 7, and performing X-ray diffraction total rock quantitative analysis on the honeycomb artificial consolidated core; obtaining electron microscope scanning images of the honeycomb artificial consolidated core at the moment, as shown in fig. 8 and 9, and analyzing the electron microscope scanning result of the honeycomb artificial consolidated core;
watch 13
Rock sample Content of clay Quartz Potassium feldspar Plagioclase feldspar Calcite Dolomite Mullite Hematite (iron ore) Pyrite Zeolite
S11 17.2 39.9 0.9 28.3 0.8 0 12.6 0 0.3 0
S12 18.1 40.2 4.4 15.2 0.3 0 21.7 0 0 0.1
Ninthly, after the remodeling, the clay mineralization degree, the pore characteristics, the rock structure and the mineral composition of the honeycomb-shaped artificial consolidated core are changed, and the sand consolidation capability of the reservoir can be optimized by enriching mullite manually according to the table 3 and the table 11; finally substituting the porosity evaluation coefficient, the gas logging permeability evaluation coefficient and the sand production rate evaluation coefficient of the rock core before and after remodeling at the ultrahigh temperature of 1500 ℃ into an underground sand consolidation strengthening evaluation method, calculating an underground sand consolidation strengthening evaluation system coefficient G, and carrying out underground sand consolidation strengthening evaluation according to the calculation result;
G＝0.3φ+0.2J+Z
in the formula, G is the coefficient of the underground sand consolidation strengthening evaluation system and has no dimensional quantity; phi is the porosity evaluation coefficient of the rock core before and after remodeling at the ultrahigh temperature of 1500 ℃, and has no dimensional quantity; j is the gas logging permeability evaluation coefficient of the rock core before and after the remodeling at the ultrahigh temperature of 1500 ℃, and has no dimensional quantity; z is the sand production rate evaluation coefficient of the rock core before and after the remodeling at the ultrahigh temperature of 1500 ℃, and is free of dimensional quantity;
TABLE 14
Serial number Underground sand consolidation strengthening evaluation system coefficient Sand consolidation strengthening evaluation effect of sandstone reservoir
1 -1＜G＜0 The strengthening effect of the sand-fixing capacity of the reservoir is poor
2 G＝0 No reinforcement of sand-fixing ability of reservoir
3 0＜G≤0.5 Slight reinforcement of sand-fixing capacity of reservoir
4 0.5＜G≤1 Obviously strengthening sand-fixing capacity of reservoir
5 G＞1 Excellent reinforcement of sand consolidation capability of reservoir
The porosity evaluation coefficient phi of the rock core before and after the ultra-high temperature 1500 ℃ remodeling, the gas logging permeability evaluation coefficient J of the rock core before and after the ultra-high temperature 1500 ℃ remodeling, and the sand production evaluation coefficient Z of the rock core before and after the ultra-high temperature 1500 ℃ remodeling are brought into common calculation to obtain an underground sand consolidation strengthening evaluation system coefficient G;
watch 15
Core number Underground sand consolidation strengthening evaluation system coefficient G
S11 0.288
S12 0.684
According to the calculation result G, the sand fixing capacity of the reshaped honeycomb artificial consolidated cores S11 and S12 is improved to a different degree compared with the original sandstone reservoir core in the ultrahigh-temperature environment of 1500 ℃.
Further, the evaluation of the porosity of the core before and after remodeling, the evaluation of the gas logging permeability of the core before and after remodeling, and the evaluation of the sand production rate of the core before and after remodeling are carried out.
Compared with the prior art, the invention has the following beneficial effects: (1) the evaluation coefficient is visual, and the evaluation system is convenient and effective; (2) the evaluation system gives consideration to multiple factors influencing sand production, so that the evaluation result is more reliable; (3) the evaluation method is easy to popularize.
Finally, it should be noted that: although the present invention has been described in detail with reference to the above embodiments, it should be understood by those skilled in the art that: modifications and equivalents may be made thereto without departing from the spirit and scope of the invention and it is intended to cover in the claims the invention as defined in the appended claims.

Claims (3)

1. An ultra-high temperature-based downhole sand consolidation strengthening evaluation method is characterized by comprising the following steps of:
s100, obtaining sandstone reservoir cores at the same layer, and heating the sandstone reservoir cores at the ultrahigh temperature of 1500 ℃ by using a box-type resistance furnace;
s200, measuring the porosity phi of the sandstone reservoir core heated at the ultrahigh temperature of 1500 DEG C0Permeability with gasg1；
S300, performing a damage experiment on the sandstone reservoir rock core heated at the ultrahigh temperature of 1500 ℃ to obtain a sand production coefficient A1；
Figure FDA0003524772280000011
In the formula (I), the compound is shown in the specification,a is the sand production coefficient of the rock core and has no dimensional quantity; sigmarThe unit is the core failure stress in the experiment and is MPa; sigmavThe unit is the near-well reservoir vertical stress in the experiment and is MPa; 0.86 is a correction coefficient and has no dimensional quantity;
s400, performing an X-ray diffraction experiment and an electron microscope scanning experiment on the sandstone reservoir core heated at the ultrahigh temperature of 1500 ℃, and analyzing the mineral components and the pore structure of the rock sample; grinding the sandstone reservoir rock core, mixing silicon carbide powder with the volume content of 25% of the rock sample into the ground sandstone reservoir rock core, and injecting mullite-rich clay; finally, the cross-linking agent mixture and the denatured sandstone reservoir core are cemented and remolded into a honeycomb-shaped artificial consolidated core at high temperature and high pressure;
s500, heating the honeycomb artificial consolidated core at the ultrahigh temperature of 1500 ℃ by using a box-type resistance furnace;
s600, measuring the porosity phi of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 DEG C1Calculating the porosity evaluation coefficient phi of the rock core before and after remodeling at the ultra-high temperature of 1500 ℃, and evaluating the porosity of the rock core, wherein the relation of the porosity evaluation coefficient phi is as follows;
Figure FDA0003524772280000012
in the formula phi1The porosity of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 ℃ is calculated in unit; phi0The unit of the porosity of the sandstone reservoir core is the porosity of the sandstone reservoir core heated at the ultrahigh temperature of 1500 ℃; phi is the porosity evaluation coefficient of the rock core before and after remodeling at the ultrahigh temperature of 1500 ℃, and has no dimensional quantity;
s700, measuring gas logging permeability K of honeycomb artificial consolidated core heated at ultra-high temperature of 1500 DEG Cg2Calculating a gas logging permeability evaluation coefficient J of the rock core before and after the remodeling at the ultra-high temperature of 1500 ℃, and carrying out gas logging permeability evaluation on the rock core, wherein the gas logging permeability evaluation coefficient J has the following relational expression;
Figure FDA0003524772280000021
in the formula, Kg1Gas logging permeability of a sandstone reservoir core heated at the ultrahigh temperature of 1500 ℃, wherein the unit is mD; kg2Gas logging permeability of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 ℃, wherein the unit is mD; j is the gas logging permeability evaluation coefficient of the rock core before and after the remodeling at the ultrahigh temperature of 1500 ℃, and has no dimensional quantity;
s800, performing a destruction experiment on the honeycomb artificial consolidated core heated at the ultrahigh temperature of 1500 ℃ to obtain a sand production coefficient A2(ii) a Performing core sand production rate evaluation, and calculating a core sand production rate evaluation coefficient Z before and after remodeling at the ultrahigh temperature of 1500 ℃;
Z＝-0.5(A2-A1)
in the formula, Z is the sand production rate evaluation coefficient of the rock core before and after the remodeling at the ultrahigh temperature of 1500 ℃, and is free of dimensional quantity; a. the1The sand production coefficient of the sandstone reservoir core after being heated at the ultrahigh temperature of 1500 ℃ is dimensionless; a. the2The sand production coefficient of the honeycomb artificial consolidated core after being heated at the ultrahigh temperature of 1500 ℃ is dimensionless;
s900, carrying out an X-ray diffraction experiment and an electron microscope scanning experiment on the honeycomb artificial consolidated core heated at the ultrahigh temperature of 1500 ℃, analyzing mineral components and a pore structure of the honeycomb artificial consolidated core heated at the ultrahigh temperature of 1500 ℃, and comparing to obtain that the sand consolidation capability of the reservoir can be improved by artificially enriching mullite in the reservoir; based on that the mineral components and the pore structure of the manually consolidated core are changed after the core is remolded, substituting the changed mineral components and the pore structure into the porosity evaluation coefficient, the gas logging permeability evaluation coefficient and the sand production evaluation coefficient of the core before and after the core is remolded at the ultrahigh temperature of 1500 ℃, performing underground sand consolidation strengthening evaluation, and calculating an underground sand consolidation strengthening evaluation system coefficient G;
G＝0.3φ+0.2J+Z
in the formula, G is the coefficient of the underground sand consolidation strengthening evaluation system and has no dimensional quantity; phi is the porosity evaluation coefficient of the rock core before and after remodeling at the ultrahigh temperature of 1500 ℃, and has no dimensional quantity; j is the gas logging permeability evaluation coefficient of the rock core before and after the remodeling at the ultrahigh temperature of 1500 ℃, and has no dimensional quantity; z is the sand production rate evaluation coefficient of the rock core before and after the remodeling at the ultrahigh temperature of 1500 ℃, and is free of dimensional quantity;
when G is more than-1 and less than 0, the strengthening effect of the sand-fixing ability of the reservoir stratum after remodeling is poor; when G is 0, the sand fixing capacity of the reservoir after remodeling is not strengthened; when G is more than 0 and less than or equal to 0.5, the sand fixing capacity of the reservoir after remolding is slightly strengthened; when G is more than 0.5 and less than or equal to 1, the sand fixing capacity of the reservoir stratum after remodeling is obviously enhanced; when G is more than 1, the sand fixing capacity of the reservoir after remodeling is remarkably strengthened.
2. The ultra-high temperature based downhole sand consolidation strengthening evaluation method according to claim 1, characterized in that: the evaluation of the core porosity is specifically that when phi is less than 0, the reservoir pore characteristics are more compact after being remolded; when phi is 0, the pore characteristics of the reservoir after remodeling are not changed; when phi is more than 0 and less than or equal to 0.2, the pore characteristics of the reservoir are slightly improved after being remolded; when phi is more than 0.2 and less than 0.4, the improvement effect is good after the pore characteristics of the reservoir stratum are remodeled; when phi is more than or equal to 0.4, the improved effect after the pore characteristics of the reservoir stratum are remolded is excellent; the core gas logging permeability evaluation specifically comprises that when J is less than 0, the water-gas flow capacity of a reservoir layer is poor; when J is 0, the water-gas flow capacity of the reservoir is not changed; when J is more than 0 and less than or equal to 1, the water and gas flow capacity of the reservoir is slightly enhanced; when J is more than 1 and less than 2, the water and gas flow capacity of the reservoir is enhanced; when J is more than or equal to 2, the water-gas flow capacity of the reservoir is greatly enhanced; the sand production rate evaluation specifically comprises the following steps that when Z is more than-0.1 and less than 0, free sand grains in a reservoir are slightly increased after remodeling; when Z is 0, the amount of reservoir free sand after remodeling is unchanged; when Z is more than 0 and less than or equal to 0.1, the free sand grains of the reservoir are slightly reduced after the remodeling; when Z is more than 0.1 and less than or equal to 0.2, the free sand grains of the reservoir are obviously reduced after the remolding; when Z > 0.2, the remodeled reservoir had no free sand.
3. The ultra-high temperature based downhole sand consolidation strengthening evaluation method according to claim 1, characterized in that: the cross-linking agent mixture is specifically a mixture of 36% of phenolic resin, 17% of polyimide resin, 21% of cementing agent, 14% of curing agent and 12% of coupling agent.
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