Oil extraction agent for improving in-situ conversion efficiency of oil shale as well as preparation method and application of oil extraction agent

Abstract

The invention belongs to the technical field of oil shale in-situ conversion, and discloses an oil extraction agent for improving the oil shale in-situ conversion efficiency and a preparation method and application thereof. The oil extraction agent comprises alkali modified minerals, metal ions, an organic complex, alcohol and an alkali treatment solvent, and based on the total weight of the oil extraction agent, the content of the alkali modified minerals is 8.0-47 wt%, the content of the metal ions is 0.1-8 wt%, the content of the organic complex is 0.4-7.0 wt%, the content of the alcohol is 0.8%-20 wt%, and the content of the alkali treatment solvent is 45-85 wt%. According to the oil extraction agent, the energy consumption and the cost are reduced by reducing the pyrolysis temperature. The main raw materials of the preparation method of the oil extraction agent are natural minerals and organic complexes, and the preparation method is low in cost, convenient to prepare, clean, environmentally friendly and suitable for large-scale industrial production.

Description

Technical Field

[0001] This invention belongs to the field of in-situ conversion technology of oil shale, and relates to an oil recovery agent for improving the in-situ conversion efficiency of oil shale, its preparation method and application. Background Technology

[0002] Shale oil is a deep-seated petroleum resource, found in dense carbonate rocks or fragment interlayers within organic-rich mudstone or shale formations. As an unconventional energy source, shale oil boasts advantages such as large reserves, high flammability, and high oil content. However, due to the rapid sedimentary facies changes, strong reservoir heterogeneity, and low thermal evolution of shale formations in my country, the crude oil in shale has a high wax content and poor fluidity, making extraction challenging. Before the 21st century, shale oil resources were primarily developed and utilized through surface dry distillation technology. While this method was simple and produced stably, it was constrained by severe environmental pollution and poor economic returns. Consequently, more environmentally friendly and efficient underground in-situ extraction technologies have gradually developed. Improving the in-situ conversion efficiency of shale oil is crucial within these technologies.

[0003] CN202211412676.2 describes a method that uses a combination of conductive proppant and other components to improve the thermal conductivity of shale oil reservoirs, effectively improving the in-situ extraction and conversion efficiency of shale oil. The composition includes an aggregate core, polymer materials, conductive agents, curing agents, and surface modifiers. However, the in-situ conversion effect of this composition underground is not ideal, and the synergistic effect between the components is poor. CN201710822240.3 discloses a method for improving the in-situ extraction efficiency of oil shale by increasing its porosity and permeability through horizontal well segmented perforation and segmented fracturing. Although this method can improve some in-situ conversion efficiency, it has high production costs and lacks universality. CN202311245064.3 discloses a method for in-situ conversion and development of organic-rich rocks. This method involves deploying a high-conductivity three-dimensional well network in the target layer of an organic-rich reservoir, performing multi-stage fracturing to form a three-dimensional fracture network. The distal ends of the fracture network are interconnected through microfractures. Working fluid is injected into heated wells to heat the formation and perform in-situ conversion. Oil and gas are then produced through production wells, improving the in-situ conversion efficiency. CN202311495964.3 discloses a method for in-situ catalytic extraction of shale oil and gas from medium- and low-maturity oil shale using supercritical CO2-double U-shaped well fracturing. Specifically, supercritical carbon dioxide fluid is used to perform staged fracturing on horizontal wells, forming a complex fracture network. Proppant and catalyst are injected into the fractured fractures, and hot gas is injected to heat the oil shale formation. The produced shale oil and gas, along with the hot gas, are produced through production wells and recovered at a surface separation unit. The separated hot gas is then recycled back into the wells. This invention employs a double-U-shaped well design, utilizing supercritical carbon dioxide fracturing technology to create a complex, interconnected network of fractures within oil shale formations, providing seepage channels for the migration of hot gases and shale oil and gas. The extraction effect of supercritical carbon dioxide extracts organic matter from the pores of the oil shale, facilitating the efficient cracking of organic matter by the catalyst. Simultaneously, the catalyst effectively lowers the heating temperature required for the pyrolysis of organic matter in the oil shale, enhancing the extraction efficiency and thus achieving efficient and economical in-situ conversion of oil shale. The catalyst is a copper-manganese-aluminum catalyst with copper, manganese, and aluminum content of 2%, 2%, and 25% by weight, respectively. However, this technology has high implementation costs, poor catalyst durability, and low in-situ conversion efficiency. CN202111682132.3, CN200880016011.1, CN201520114231.5, CN201510085726.4, and CN202111291684.1 all employ the fire-flooding method to improve in-situ conversion efficiency by increasing formation temperature. CN202311190775.5, however, makes an improvement by disclosing an in-situ catalytic combustion method for oil shale fire-flooding. This method involves creating fractures in the oil shale reservoir using fracturing technology and injecting a catalyst into the fractures. The high temperature generated during the fire-flooding combustion process activates the catalyst. The crude oil produced by the high-temperature pyrolysis is then collected and stored through fractures, pipelines, and equipment.The in-situ combustion catalyst for oil shale includes heterogeneous catalysts, molecular sieve catalysts, homogeneous catalysts, and metal catalysts. These measures improve the in-situ conversion efficiency.

[0004] CN202210181054.7 proposes an in-situ conversion catalyst to reduce the activation energy and pyrolysis temperature of catalytic pyrolysis and improve the in-situ conversion efficiency. The catalyst is composed of mesoporous molecular sieves, quaternary ammonium bases, supported metal nano-alumina, ethyl cyclohexane, and surfactants. This technology aims to enhance catalytic pyrolysis by making full use of rare earth-containing molecular sieves. However, the large number of catalyst components and the complex preparation process affect its practical application.

[0005] CN201710082567.1 discloses a method for in-situ oil shale mining by fracturing oil shale formations before in-situ conversion and then injecting a catalyst solution into the modified oil shale formation to achieve well shut-in. The catalyst in this technology is magnesium sulfate and water; however, this catalyst has a single component and low conversion efficiency.

[0006] CN202210181054.7 discloses a rare earth mesoporous molecular sieve and its catalyst preparation method for catalytic cracking of oil shale. The pore size of the rare earth mesoporous molecular sieve is 3-7 nm; the catalyst includes a rare earth mesoporous molecular sieve, a quaternary ammonium base, supported metal nano-alumina, ethyl cyclohexane, and a surfactant. However, although the catalyst used in this technology can accelerate the conversion of oil source material to oil and gas and reduce the cracking conversion temperature of oil shale, it suffers from problems such as cumbersome preparation process and poor compatibility of various components.

[0007] CN202311495964.3 describes a technique that uses supercritical carbon dioxide fluid for staged fracturing of horizontal wells to create a complex fracture network. Proppant and catalyst are injected into the fractured areas, along with hot gas to heat the oil shale formation. The produced shale oil and gas, along with the hot gas, are produced through production wells and recovered at a surface separation unit, with the separated hot gas being recycled back into the system. The catalyst is a copper-manganese-aluminum catalyst with copper, manganese, and aluminum content of 2%, 2%, and 25% by weight, respectively. However, this technology has high implementation costs, poor catalyst durability, and low in-situ conversion efficiency.

[0008] Analysis of existing technologies reveals that current methods for improving the efficiency of in-situ conversion of shale oil mainly focus on field engineering techniques, fracturing techniques, and improvements in combination with catalysts. However, these methods suffer from numerous problems, such as unsatisfactory sustained catalyst efficacy, complex preparation processes, and high implementation costs. Therefore, there is an urgent need to develop a highly efficient in-situ conversion oil recovery agent. Summary of the Invention

[0009] The purpose of this invention is to provide an oil recovery agent that improves the in-situ conversion efficiency of oil shale, its preparation method, and its application. This invention improves the in-situ conversion efficiency of oil shale, thereby increasing oil and gas production.

[0010] To achieve the above objectives, the present invention provides an oil recovery agent for improving the in-situ conversion efficiency of oil shale. The oil recovery agent comprises: alkali-modified minerals, metal ions, organic complexes, alcohols, and alkali-treated solvents. Based on the total weight of the oil recovery agent, the content of the alkali-modified minerals is 8.0-47 wt%, the content of the metal ions is 0.1-8 wt%, the content of the organic complexes is 0.4-7.0 wt%, the content of the alcohols is 0.8%-20 wt%, and the content of the alkali-treated solvents is 45-85 wt%.

[0011] The oil recovery agent of the present invention, by weight of the oil recovery agent, comprises 8.0-30 wt% alkali-modified minerals, 1.0-8 wt% metal ions, 1.0-7 wt% organic complexes, 1-18 wt% alcohols, and 55-85 wt% alkali-treated solvents.

[0012] The oil recovery agent of the present invention includes at least one of sodium, calcium, potassium, iron, magnesium, and titanium as the metal ion.

[0013] The oil recovery agent of the present invention has an alkali-modified mineral with a specific surface area of ​​80 m². 2 / g-200m 2 / g, with pore volumes ranging from 0.18mL / g to 0.40mL / g.

[0014] The oil recovery agent of the present invention includes alkali-modified minerals comprising natural minerals of the kaolinite group; preferably, the natural minerals of the kaolinite group include at least one of kaolinite, montmorillonite, illite, halloysite, attapulgite, leucite, magnesite, calcite, and dolomite.

[0015] The oil recovery agent of the present invention uses a solvent that is a lower C1-C6 alcohol; preferably, the lower C1-C6 alcohol includes at least one of methanol, ethanol, and propanol.

[0016] The oil recovery agent of the present invention comprises an organic complex that is a product of the reaction of an organic polymer with a phytic acid solution; preferably, the organic polymer includes at least one of carboxymethyl cellulose, methyl cellulose, cellulose, starch, and biomass; preferably, the mass concentration of the phytic acid solution is 5-80%, and the mass ratio of the organic polymer to the phytic acid solution is 1:1.5-10.

[0017] The oil recovery agent of the present invention, wherein the phytic acid solution is used to treat the organic polymer at 50-120°C for 0.5-6 hours.

[0018] The oil recovery agent of the present invention has a pH range of 8.0-14.0, preferably 10-12.

[0019] This invention also provides a method for preparing an oil-enhancing agent, the method comprising:

[0020] (1) Natural minerals are contacted with alkaline solution for alkaline treatment, and solid-liquid separation is performed to obtain alkaline-modified minerals and alkaline-treated solvent;

[0021] (2) The organic polymer was treated with phytic acid solution to obtain an organic complex;

[0022] (3) Mix alkali-modified minerals, alkali-treated solvents, alcohols and organic complexes to obtain an oil production agent.

[0023] In the preparation method of the oil-enhancing agent of the present invention, in step (1), the conditions for the alkali treatment include:

[0024] Temperature 20-100℃; and / or

[0025] The time is 10-120 minutes; and / or

[0026] pH range: 8-14.0.

[0027] In the preparation method of the oil-enhancing agent of the present invention, in step (1), the alkaline solution comprises inorganic alkali and / or organic alkali; and / or

[0028] The mass percentage concentration of the alkaline solution is 1-60%; and / or

[0029] The mass ratio of the alkaline solution to the natural minerals is 1:1 to 8:1.

[0030] In the preparation method of the oil-enhancing agent of the present invention, in step (1), the inorganic base includes at least one selected from NaOH, KOH, Ca(OH)2, NaNH2, and NH3·H2O; and / or

[0031] The organic base includes at least one of the following: aqueous solution of 1,1,3,5-tetramethylpiperidine hydroxide, tetraethylammonium hydroxide, tetramethylammonium hydroxide, tetrapropylammonium hydroxide, tetrabutylammonium hydroxide, tetrabutylphosphine hydroxide solution, benzyltrimethylammonium hydroxide, guanethidine, guanethidine, triethylamine, aniline, ethylenediamine, p-phenylenediamine, ethylamine, butylamine, dimethylamine, and diethylamine.

[0032] In the preparation method of the oil-enhancing agent of the present invention, in step (1), the total content of metals (in atomic terms) in the natural mineral is 1-80 wt%.

[0033] In the preparation method of the oil-producing agent of the present invention, in step (1), the natural minerals include kaolinite natural minerals; preferably, the kaolinite natural minerals include at least one of kaolinite, montmorillonite, illite, halloysite, attapulgite, leucite, magnesite, calcite, and dolomite.

[0034] In the preparation method of the oil recovery agent of the present invention, in step (3), the solvent is a lower C1-C6 alcohol; preferably, the lower C1-C6 alcohol includes at least one of methanol, ethanol, and propanol.

[0035] In the preparation method of the oil-producing agent of the present invention, in step (3), the concentration of the alcohol is 10-100 wt%.

[0036] The method for preparing the oil-producing agent of the present invention includes an organic polymer comprising at least one of carboxymethyl cellulose, methyl cellulose, cellulose, starch, and biomass; preferably, the mass concentration of the phytic acid solution is 5-80%, and the mass ratio of the organic polymer to the phytic acid solution is 1:1.5-10.

[0037] In the preparation method of the oil recovery agent of the present invention, in step (2), the organic polymer is treated with phytic acid solution at 50-120°C for 0.5-6 hours.

[0038] In the preparation method of the oil-producing agent of the present invention, in step (3), the total mass ratio of the alkali-modified mineral, the alkali-treated solvent, and the alcohol to the organic complex is 9-1:1-9.

[0039] This invention relates to the application of another oil extraction agent in oil extraction.

[0040] This invention provides an oil recovery agent for improving the in-situ conversion efficiency of oil shale, its preparation method, and its application.

[0041] The oil recovery agent of this invention, when applied in oil extraction, avoids the traditional method of improving in-situ conversion efficiency through engineering techniques and fracturing. Instead, it develops a method for preparing an oil recovery agent that improves the in-situ conversion efficiency of oil shale through slow-release technology. Compared with existing technologies, this invention has at least the following beneficial effects:

[0042] (1) In this invention, natural minerals of the Kaolinite group are treated with an alkaline solution of a certain concentration. The purpose of alkaline treatment is not only to obtain natural minerals with high specific surface area and pore volume, but more importantly, to obtain free metal ions through alkaline treatment. These ions can serve as important active centers in oil production agents to participate in the catalytic reaction of solid organic matter in oil shale and play a role in breaking bonds. At the same time, the natural minerals after alkaline treatment can serve as a porous "reaction bed" with abundant specific surface area, playing a role in adsorption and containment, and synergistically reacting.

[0043] (2) This invention uses phytic acid to complex organic polymers. The most significant characteristic of phytic acid is that it has a strong complexing effect with organic polymers to form a stable complex. Under certain temperature and pressure, the complex will undergo structural changes and slowly release O2 and other organic matter, which enter the formation to change the state of kerogen and achieve quality improvement. It works together with the released water molecules to improve the in-situ conversion efficiency and increase the oil and gas production rate.

[0044] (3) A small amount of alcohol is added to the oil extraction agent of the present invention. The alcohol can form a complex with the alkali-treated magnesium and calcium metals, and at the same time continuously release water molecules. The released water molecules are in a supercritical state, which can efficiently dissolve hydrocarbons and salts in the rock layer and enter the kerogen network structure pores of the oil shale layer, promoting the discharge of generated oil and gas, thereby playing a synergistic role in enhancing energy and driving oil.

[0045] (4) The present invention fully utilizes the slow-release technology to improve the in-situ conversion efficiency of oil shale, thereby increasing oil and gas production.

[0046] (5) The oil recovery agent of the present invention reduces energy consumption and cost by lowering the pyrolysis temperature. The main raw materials for the preparation method of the oil recovery agent of the present invention are natural minerals and organic complexes, which are low in cost, easy to prepare, clean and environmentally friendly, and suitable for large-scale industrial production. Attached Figure Description

[0047] Figure 1 This is an electron microscope image of the natural mineral after alkali treatment in Example 4. Detailed Implementation

[0048] The present invention will now be described in detail through embodiments. It should be noted that the following embodiments are only for further illustration of the present invention and should not be construed as limiting the scope of protection of the present invention. Those skilled in the art can make some non-essential improvements and adjustments to the present invention based on the above description.

[0049] For any experimental steps or conditions not specified in the examples and comparative examples, the procedures and conditions described in the literature in this field can be followed. Reagents or instruments whose manufacturers are not specified are all commercially available conventional reagent products.

[0050] This invention provides an oil recovery agent comprising: alkali-modified minerals, metal ions, organic complexes, alcohols, and alkali-treated solvents. Based on the total weight of the oil recovery agent, the alkali-modified minerals comprise 8.0-47 wt%, the metal ions comprise 0.1-8 wt%, the organic complexes comprise 0.4-7.0 wt%, the alcohols comprise 0.8%-20 wt%, and the alkali-treated solvents comprise 45-85 wt%.

[0051] The oil recovery agent of this invention reduces energy consumption and cost by lowering the pyrolysis temperature. The main raw materials for the preparation method of the oil recovery agent of this invention are natural minerals and organic complexes, which are low-cost, easy to prepare, clean, and environmentally friendly, making them suitable for large-scale industrial production.

[0052] The oil recovery agent provided by this invention has a good oil displacement effect, which can continuously promote the discharge of generated oil and gas, and increase the amount of oil discharged and oil and gas production in oil shale, with an increase in oil and gas production of up to 19.87%. The high in-situ conversion efficiency, according to evaluation results, may be due to: fully utilizing alkali treatment to transform kaolinite natural minerals into natural minerals with higher specific surface area and pore volume, and combining this with the precipitation of metal ions to participate in the catalytic reaction of solid organic matter in oil shale, playing a role in bond breaking and adsorption and containment; phytic acid complexes slowly release O2 and other organic matter, entering the formation to change the state of kerogen, achieving quality improvement, and working together with released water molecules to improve in-situ conversion efficiency and increase oil and gas production rate; the introduction of solvent alcohol can form complexes with alkali-treated metals, efficiently dissolving hydrocarbons and salts in the rock formation, entering the kerogen network structure pores of the oil shale layer, and promoting the discharge of generated oil and gas. Through the above comprehensive technology, the in-situ conversion efficiency of oil shale is improved, thereby increasing oil and gas production rate.

[0053] In this invention, the alkaline solution comprises an inorganic base and / or an organic base. The inorganic base comprises at least one of NaOH, KOH, Ca(OH)2, NaNH2, and NH3·H2O. The organic base comprises at least one of the following: aqueous solution of 1,1,3,5-tetramethylpiperidine hydroxide, tetraethylammonium hydroxide, tetramethylammonium hydroxide, tetrapropylammonium hydroxide, tetrabutylammonium hydroxide, tetrabutylphosphine hydroxide solution, benzyltrimethylammonium hydroxide, guanethidine, guanethidine, triethylamine, aniline, ethylenediamine, p-phenylenediamine, ethylamine, butylamine, dimethylamine, and diethylamine.

[0054] In this invention, the natural minerals of the kaolinite group include at least one of kaolinite, montmorillonite, illite, halloysite, attapulgite, leucite, magnesite, calcite, and dolomite.

[0055] In this invention, the alkali treatment process involves treating kaolinite natural minerals with an alkali solution at a pH of 8–14.0 and a temperature of 20–100°C for 10–120 min, preferably 10–60 min; the mass percentage concentration of the alkali solution is 1–60%, and the mass ratio of the alkali solution to the natural minerals is 1:1–8:1.

[0056] In this invention, the total mass of elemental metals (in atomic terms) in the alkali-treated solvent is 20-95% of the total mass of metals (in atomic terms) in the natural mineral.

[0057] In this invention, the alcohol includes at least one of methanol, ethanol, and propanol, and the concentration of the alcohol is 10-100 wt%.

[0058] In this invention, the organic polymer includes at least one of carboxymethyl cellulose, methyl cellulose, cellulose, starch, and biomass.

[0059] In this invention, the mass concentration of the phytic acid solution is 5-80%, and the mass ratio of the organic polymer to the phytic acid solution is 1:1.5-10.

[0060] In this invention, the phytic acid solution is used to treat the organic polymers at 50–120°C for 0.5–6 hours, preferably at 60–100°C for 1–4 hours.

[0061] In this invention, alkali-modified minerals, alkali-treated solvents, and alcohols are mixed to obtain an alkali-treated system product. The alkali-treated composite system, organic complexes, and oil shale are then mixed and subjected to catalytic pyrolysis.

[0062] The mass ratio of the alkali-treated composite system and the organic complex formed in this invention is 9-1:1-9.

[0063] When the oil recovery agent in this invention is used to improve oil and gas recovery, its addition amount accounts for 10-90% of the total mass of oil shale.

[0064] The conditions for the catalytic pyrolysis reaction described in this invention are: reaction temperature 100-600℃ and pressure 10-30 MPa.

[0065] Source of raw materials or equipment:

[0066] Kaolinite (Na: 0.56%, Fe: 0.70%), montmorillonite (Mg: 22%, Ca: 34%), illite (K: 7.47%, Na: 1.12%), halloysite (Fe: 0.5%, Na: 0.58%), attapulgite (Na: 1.31%, Mg: 16.34%, Ca: 2.87%, Fe: 6.64%), tartarite (Na: 1.26%, K: 1.12%, Ca: 3.39%, Fe: 2.14%, Ti: 0.83%), magnesite (Mg: 47.82%, Ca: 5.18%), calcite (Mg: 30%, Ca: 50%), dolomite (Mg: 21.86%, Ca: 21.72%), commercially available from Shandong Xinhai Mining Equipment Company.

[0067] NaOH, KOH, Ca(OH)2, NaNH2, NH3·H2O, aqueous solution of 1,1,3,5-tetramethylpiperidine hydroxide, tetraethylammonium hydroxide, tetramethylammonium hydroxide, tetrapropylammonium hydroxide, tetrabutylammonium hydroxide, tetrabutylphosphine hydroxide solution, benzyltrimethylammonium hydroxide, guanethidine, guanethidine, triethylamine, aniline, ethylenediamine, p-phenylenediamine, ethylamine, butylamine, dimethylamine, diethylamine, chemically pure, Sinopharm Chemical Reagent Co., Ltd.

[0068] Methanol, ethanol, propanol, Sinopharm Chemical Reagent Co., Ltd.

[0069] Phytic acid solution: 80% concentration (mass percentage), chemically pure, Sinopharm Chemical Reagent Co., Ltd.

[0070] Carboxymethyl cellulose, methyl cellulose, cellulose, starch, biomass, chemically pure, Sinopharm Chemical Reagent Co., Ltd.

[0071] Oil shale: 80-120 mesh, China National Petroleum Corporation Changqing Oilfield Branch.

[0072] Analysis and conversion performance testing methods:

[0073] The BET specific surface area and pore volume of the samples were determined using an ASAP 2460 fully automated specific surface area analyzer from Micromeritics, USA.

[0074] The surface morphology of the scanning electron microscope samples was tested using an Ultra Plus scanning electron microscope from Carl Zeiss GmbH, Germany.

[0075] The conversion performance of the catalyst was tested using a gold tube hydrocarbon generation thermal simulator (model: JGMN-1).

[0076] The detailed testing method is as follows:

[0077] Specific surface area and pore volume testing methods:

[0078] The samples were first pretreated at high temperature (300℃) (under vacuum) for 8 hours; then, they were analyzed at liquid nitrogen temperature of -196℃. The total specific surface area was calculated using the BET method, while the remaining surface area and micropore volume were calculated using the t-plot method, and the mesopore volume was calculated using the BJH method.

[0079] Scanning electron microscopy testing methods:

[0080] Operating parameters: accelerating voltage 5-20KV, working distance: WD = 8-12mm, magnification: 86-200Kx. Specific operating procedure: After the sample to be tested undergoes two gold sputtering treatments over 10 minutes, it is placed on the observation platform for observation.

[0081] Conversion performance testing methods:

[0082] Testing was conducted according to the oil and gas industry standard SYT7035-2016. A 0.8g sample was taken from a mixture of oil displacement agent and oil shale at a mass ratio of 1:10-9:10 and placed in a gold tube hydrocarbon generation simulator for catalytic pyrolysis. The fluid pressure was 10-30 MPa, and the temperature was rapidly increased to 100-600℃ at a heating rate of 20℃ / min. After holding at this temperature for 72 hours, the sample was cooled and the gas and oil were collected for subsequent analysis.

[0083] 1) Quantitative analysis of gaseous products

[0084] The collection of gaseous products in the gold tube was carried out using a special quantitative collection device. First, the reacted gold tube was fixed in a suitable position on the sampling device, sealed tightly, and then evacuated to a near-vacuum state. The vacuum pressure (P1) was recorded. The gold tube was then punctured, and the pressure value was recorded after the pressure gauge showed equilibrium (P2). The gas volume was calculated using the following formula:

[0085] V = V0 × (P2 - P1) / P0

[0086] In the formula: V0 is the volume of the gas collection device; P0 is the atmospheric pressure when the gas is collected in a fixed quantity.

[0087] The simulated generated gas components were analyzed using an Agilent 6890 gas chromatograph with helium as the carrier gas. The injection port temperature for gas analysis was 250℃, and the split ratio was 25:1. Column oven temperature conditions were as follows: initial temperature 68℃, held for 7 min, then increased to 90℃ at a rate of 10℃ / min and held for 1.5 min, then increased to 175℃ at a rate of 15℃ / min, and finally held for 5 min.

[0088] The mass of each gaseous component is calculated using the ideal gas law:

[0089] M = V × m0 / 22.4

[0090] In the formula, m0 is the molar mass of the gas component being calculated. The total weight of the gas components (G0) is the sum of the masses of each gas component.

[0091] 2) Quantitative analysis of light hydrocarbons

[0092] Because light hydrocarbon solutions are volatile, direct measurement is difficult. In this experiment, the quantitative measurement of light hydrocarbons was performed using the difference method. First, the simulated gold tube containing the sample was weighed, and its weight (G) was recorded. tThen, after the gas analysis was performed, the gold tube was left to stand for one day until all the gas and light hydrocarbons in the gold tube had dissipated before being weighed and its weight (G) was recorded. cz1 The weight of the light hydrocarbon (G1) is equal to the weight lost minus the total weight of the gas, that is:

[0093] G1 = G t -G cz1 -G0

[0094] 3) Liquid hydrocarbons / discharged oil metering

[0095] The amount of liquid hydrocarbons generated in the reaction / the amount of oil discharged was obtained by combining CH2Cl2 ultrasonic extraction and the weighing difference method. After gas analysis, the gold tube was placed in CH2Cl2 and cut open. The organic solvent soaking the gold tube was then ultrasonicated three times. The solid residue was then filtered through a chromatographic membrane. The resulting liquid solution was weighed after the organic solvent had completely evaporated to obtain the weight of the liquid hydrocarbons (G). cy1 ).

[0096] After the gold tubes and residues that have passed through extraction and filtration have been dried, they are weighed and their weight (G) is recorded. cz2 This weight is the same as the weight of the gold tube and sample after gas and light hydrocarbon analysis (G). cz1 The difference is also the weight of the liquid hydrocarbons produced (G). cy2 ),Right now:

[0097] G cy2 =G cz1 -G cz2

[0098] To reduce errors, the weight of liquid hydrocarbons (G) during the experiment... y Calculate using the following formula:

[0099] G y =(G cy1 +G cy2 ) / 2.

[0100] 4) Calculation of oil and gas increments

[0101] The total amount of oil and gas in Comparative Example 1 (G 对比例1 (Based on)

[0102] Increment in oil and gas volume = (Total oil and gas volume - G) 对比例1 / G 对比例1 )×100%.

[0103] pH testing method: At room temperature, immerse the pH meter electrode in a standard buffer solution and calibrate according to the instrument instructions. Rinse the electrode with distilled or deionized water to remove surface impurities. Immerse the pH meter electrode in the solution to be tested, allow it to stand for a moment until the value stabilizes, and then read the pH value.

[0104] Example 1

[0105] 43 g of kaolinite and a 1% tetramethylammonium hydroxide solution were thoroughly mixed at 20°C with a liquid-to-solid mass ratio of 1. The mixture was treated at pH 8.8 for 120 minutes. After filtration, alkali-modified mineral 1 and alkali-treated solvent 1 were obtained. The specific surface area of ​​alkali-modified mineral 1 was 81 m². 2 / g, pore volume is 0.18mL / g, the total mass of metal (in atomic terms) in alkali-treated solvent 1 is 60% of the total mass of metal (in atomic terms) in natural minerals; then 4.12g of 10wt% methanol solution is slowly added to alkali-treated solvent 1, stirred thoroughly at 20℃ for 60min, and then mixed with alkali-modified mineral 1 to obtain mixture 1; 1g of carboxymethyl cellulose and 1.5g of 5% phytic acid solution are treated at 50℃ for 6h to obtain organic complex 1; 0.3g of a sample of mixture 1 and organic complex 1 (mass ratio of mixture 1 to organic complex 1 is 9:1, pH value of oil recovery sample is 8.0) is thoroughly mixed with 3g of oil shale powder, and 0.8g is weighed out and evaluated in a hydrocarbon generation simulation experiment at 100℃ and 30MPa, and the change in oil and gas yield is analyzed after the reaction.

[0106] Example 2

[0107] 25 g of montmorillonite and a 35% guanethidine solution were thoroughly mixed at 50 °C with a liquid-to-solid mass ratio of 8 and a pH of 9.6 for 40 minutes. The mixture was then filtered to obtain alkali-modified mineral 2 and alkali-treated solvent 2. The specific surface area of ​​alkali-modified mineral 2 was 105 m². 2 / g, pore volume is 0.21mL / g, the total mass of metal (in atomic terms) in alkali-treated solvent 2 is 30% of the total mass of metal (in atomic terms) in natural minerals; then 2.14g of 100wt% ethanol solution is slowly added to alkali-treated solvent 2, stirred thoroughly at 60℃ for 10min, and then mixed with alkali-modified mineral 2 to obtain mixture 2; 1.2g of methylcellulose and 12g of 56% phytic acid solution are treated at 120℃ for 0.5h to obtain organic complex 2; a sample with a total mass of 2.7g of mixture 2 and organic complex 2 (mass ratio of mixture 2 to organic complex 2 8:2, pH value of oil recovery sample is 13.7) is thoroughly mixed with 3g of oil shale powder, and 0.8g is weighed out and subjected to hydrocarbon generation simulation experiment evaluation at 180℃ and 10MPa, and the change in oil and gas yield is analyzed after the reaction.

[0108] Example 3

[0109] 67 g of illite and a 60% triethylamine solution were thoroughly mixed at 100 °C with a liquid-to-solid mass ratio of 2. The mixture was treated at pH 13.2 for 10 minutes. After filtration, alkali-modified mineral 3 and alkali-treated solvent 3 were obtained. The specific surface area of ​​alkali-modified mineral 3 was 176 m². 2 / g, pore volume is 0.35mL / g, the total mass of metals (in atomic terms) in alkali-treated solvent 3 is 80% of the total mass of metals (in atomic terms) in natural minerals; then 16.57g of 20wt% ethanol solution is slowly added to alkali-treated solvent 3, stirred thoroughly at 30℃ for 20min, and then mixed with alkali-modified mineral 3 to obtain mixture 3; 1.5g of cellulose and 13.5g of 72% phytic acid solution are treated at 60℃ for 1h to obtain organic complex 3; a sample with a total mass of 2.4g of mixture 3 and organic complex 3 (mass ratio of mixture 3 to organic complex 3 7:3, pH value of oil recovery sample is 8.5) is thoroughly mixed with 3g of oil shale powder, and 0.8g is weighed out and subjected to hydrocarbon generation simulation experiment evaluation at 600℃ and 20MPa, and the change in oil and gas yield is analyzed after the reaction.

[0110] Example 4

[0111] 35 g of halloysite and a 25% (w / w) butylamine solution were thoroughly mixed at 70 °C with a liquid-to-solid mass ratio of 5 and a pH of 13.9 for 30 minutes. The mixture was then filtered to obtain alkali-modified mineral 4 and alkali-treated solvent 4. The specific surface area of ​​alkali-modified mineral 4 was 132 m² / g. 2 / g, pore volume is 0.31mL / g, the total mass of metals (in atomic terms) in alkali-treated solvent 4 is 90% of the total mass of metals (in atomic terms) in natural minerals; then 30.23g of 30wt% propanol solution is slowly added to alkali-treated solvent 4, stirred thoroughly at 50℃ for 30min, and then mixed with alkali-modified mineral 4 to obtain mixture 4; 2g of starch and 10g of 80% phytic acid solution are treated at 80℃ for 2h to obtain organic complex 4; a sample with a total mass of 2.1g of mixture 4 and organic complex 4 (mass ratio of mixture 4 to organic complex 4 6:4, pH value of oil recovery sample is 8.9) is thoroughly mixed with 3g of oil shale powder, and 0.8g is weighed out and subjected to hydrocarbon generation simulation experiment evaluation at 500℃ and 15MPa, and the change in oil and gas yield is analyzed after the reaction.

[0112] Example 5

[0113] 88 grams of attapulgite clay and a 55% KOH solution were thoroughly mixed at 40°C with a liquid-to-solid mass ratio of 7 and a pH of 11.2 for 80 minutes. The mixture was then filtered to obtain alkali-modified mineral 5 and alkali-treated solvent 5. The specific surface area of ​​alkali-modified mineral 5 was 114 m². 2 / g, pore volume is 0.26mL / g, the total mass of metals (in atomic terms) in alkali-treated solvent 5 is 20% of the total mass of metals (in atomic terms) in natural minerals; then 12.98g of 45wt% methanol solution is slowly added to alkali-treated solvent 5, stirred thoroughly at 55℃ for 35min, and then mixed with alkali-modified mineral 5 to obtain mixture 5; 1.3g of starch and 7.8g of 63% phytic acid solution are treated at 90℃ for 3h to obtain organic complex 5; a sample with a total mass of 1.8g of mixture 5 and organic complex 5 (mass ratio of mixture 5 to organic complex 5 5:5, pH value of oil recovery sample is 13.6) is thoroughly mixed with 3g of oil shale powder, and 0.8g is weighed out and subjected to hydrocarbon generation simulation experiment evaluation at 400℃ and 25MPa, and the change in oil and gas yield is analyzed after the reaction.

[0114] Example 6

[0115] 97 g of calcite and a 42% NaOH solution were thoroughly mixed at 80°C with a liquid-to-solid mass ratio of 3 and a pH of 12.4 for 50 minutes. The mixture was then filtered to obtain alkali-modified mineral 6 and alkali-treated solvent 6. The specific surface area of ​​alkali-modified mineral 6 was 191 m². 2 / g, pore volume is 0.23mL / g, the total mass of metals (in atomic terms) in alkali-treated solvent 6 is 95% of the total mass of metals (in atomic terms) in natural minerals; then 98.60g of 55wt% ethanol solution is slowly added to alkali-treated solvent 6, stirred thoroughly at 35℃ for 25min, and then mixed with alkali-modified mineral 6 to obtain mixture 6; 1.6g of cellulose and 12.8g of 47% phytic acid solution are treated at 100℃ for 3.5h to obtain organic complex 6; a sample with a total mass of 1.5g of mixture 6 and organic complex 6 (mass ratio of mixture 6 to organic complex 6 4:6, pH value of oil recovery sample is 12.8) is thoroughly mixed with 3g of oil shale powder, and 0.8g is weighed out and subjected to hydrocarbon generation simulation experiment evaluation at 550℃ and 12MPa, and the change in oil and gas yield is analyzed after the reaction.

[0116] Example 7

[0117] 76 g of magnesite and a 13% NaNH2 solution were thoroughly mixed at 30°C with a liquid-to-solid mass ratio of 5 and a pH of 9.9 for 110 minutes. The mixture was then filtered to obtain alkali-modified mineral 7 and alkali-treated solvent 7. The specific surface area of ​​alkali-modified mineral 7 was 117 m². 2 / g, pore volume is 0.31mL / g, the total mass of metals (in atomic terms) in alkali-treated solvent 7 is 40% of the total mass of metals (in atomic terms) in natural minerals; then 58.46g of 65wt% ethanol solution is slowly added to alkali-treated solvent 7, stirred thoroughly at 25℃ for 45min, and then mixed with alkali-modified mineral 7 to obtain mixture 7; 2g of methylcellulose and 6g of 32% phytic acid solution are treated at 70℃ for 5h to obtain organic complex 7; 0.6g of a sample of mixture 7 and organic complex 7 (mass ratio of mixture 7 to organic complex 7 3:7, pH value of oil recovery sample is 11.2) is thoroughly mixed with 3g of oil shale powder, and 0.8g is weighed out and evaluated in a hydrocarbon generation simulation experiment at 450℃ and 17MPa, and the change in oil and gas yield is analyzed after the reaction.

[0118] Example 8

[0119] 68 grams of calcite and a 30% ammonia solution were thoroughly mixed at 60°C with a liquid-to-solid mass ratio of 4. The mixture was treated at pH 12.8 for 95 minutes. After filtration, alkali-modified mineral 8 and alkali-treated solvent 8 were obtained. The specific surface area of ​​alkali-modified mineral 8 was 145 m². 2 / g, pore volume is 0.33mL / g, the total mass of metals (in atomic terms) in alkali-treated solvent 8 is 50% of the total mass of metals (in atomic terms) in natural minerals; then 24.53g of 70wt% methanol solution is slowly added to alkali-treated solvent 8, stirred thoroughly at 30℃ for 40min, and then mixed with alkali-modified mineral 8 to obtain mixture 8; 0.8g of carboxymethyl cellulose and 3.2g of 22% phytic acid solution are treated at 110℃ for 1.5h to obtain organic complex 8; a sample with a total mass of 0.9g of mixture 8 and organic complex 8 (mass ratio of mixture 8 to organic complex 8 2:8, pH value of oil recovery sample is 9.6) is thoroughly mixed with 3g of oil shale powder, and 0.8g is weighed out and subjected to hydrocarbon generation simulation experiment evaluation at 300℃ and 22MPa, and the change in oil and gas yield is analyzed after the reaction.

[0120] Example 9

[0121] 43 grams of dolomite and an 18% Ca(OH)₂ solution were thoroughly mixed at 90°C with a liquid-to-solid mass ratio of 6. The mixture was treated at pH 11.6 for 65 minutes. After filtration, alkali-modified mineral 9 and alkali-treated solvent 9 were obtained. The specific surface area of ​​alkali-modified mineral 9 was 98 m². 2 / g, pore volume is 0.33mL / g, the total mass of metals (in atomic terms) in alkali-treated solvent 9 is 60% of the total mass of metals (in atomic terms) in natural minerals; then 3.48g of 80wt% propanol solution is slowly added to alkali-treated solvent 9, stirred thoroughly at 20℃ for 50min, and then mixed with alkali-modified mineral 9 to obtain mixture 9; 1g of biomass and 7g of 13% phytic acid solution are treated at 105℃ for 2.5h to obtain organic complex 9; a sample with a total mass of 1.2g of mixture 9 and organic complex 9 (mass ratio of mixture 9 to organic complex 9 1:9, pH value of oil recovery sample is 10.7) is thoroughly mixed with 3g of oil shale powder, and 0.8g is weighed out and subjected to hydrocarbon generation simulation experiment evaluation at 350℃ and 27MPa, and the change in oil and gas yield is analyzed after the reaction.

[0122] Example 10

[0123] 90 g of montmorillonite and a 6% NaOH solution were thoroughly mixed at 65 °C with a liquid-to-solid mass ratio of 5.5 and a pH of 10.8 for 100 minutes. The mixture was then filtered to obtain alkali-modified mineral 10 and alkali-treated solvent 10. The specific surface area of ​​alkali-modified mineral 10 was 156 m². 2 / g, pore volume is 0.30mL / g, the total mass of metals (in atomic terms) in alkali-treated solvent 10 is 70% of the total mass of metals (in atomic terms) in natural minerals; then 17.65g of 90wt% methanol solution is slowly added to alkali-treated solvent 10, stirred thoroughly at 45℃ for 15min, and then mixed with alkali-modified mineral 10 to obtain mixture 10; 0.9g of cellulose and 1.8g of 8% phytic acid solution are treated at 85℃ for 5.5h to obtain organic complex 10; after the total mass of mixture 10 and organic complex 10 is 0.45g (mass ratio of mixture 10 to organic complex 10 is 5.5:4.5, pH value of oil recovery sample is 9.1) and 3g of oil shale powder is thoroughly mixed, and 0.8g is weighed out and subjected to hydrocarbon generation simulation experiment at 200℃ and 19MPa for evaluation, and the change in oil and gas yield is analyzed after the reaction.

[0124] Comparative Example 1

[0125] A simulated evaluation condition was selected and compared with Example 7. In Comparative Example 1, no oil recovery agent was added. 0.8 grams of oil shale was weighed and subjected to a hydrocarbon generation simulation experiment at 450℃ and 17 MPa. The changes in oil and gas yield after the reaction were analyzed.

[0126] Comparative Example 2

[0127] Compared with Example 5, Comparative Example 2 only added 1.3 grams of starch and 3 grams of oil shale, and after thorough mixing, 0.8 grams was weighed out and subjected to a hydrocarbon generation simulation experiment at 400℃ and 25 MPa for evaluation. The change in oil and gas yield after the reaction was analyzed.

[0128] Comparative Example 3

[0129] Compared with Example 1, 4.12 g of 10 wt% methanol and 3 g of oil shale powder were thoroughly mixed, and 0.8 g of the mixture was weighed out and subjected to a hydrocarbon generation simulation experiment at 100 °C and 30 MPa. The changes in oil and gas yield after the reaction were analyzed.

[0130] Comparative Example 4

[0131] Compared with Example 3, 67 grams of illite and a 60% triethylamine solution were thoroughly mixed at 100°C with a liquid-to-solid mass ratio of 2, and treated at pH 13.2 for 10 minutes. The mixture was then filtered to obtain alkali-modified mineral 3 and alkali-treated solvent 3. The specific surface area of ​​alkali-modified mineral 3 was 176 m². 2 / g, with a pore volume of 0.35mL / g, the total mass of metals (in atomic terms) in alkali-treated solvent 3 is 80% of the total mass of metals (in atomic terms) in natural minerals; then, 2.4g of alkali-treated solvent 3 is thoroughly mixed with 3g of oil shale powder, and 0.8g is weighed out and subjected to a hydrocarbon generation simulation experiment at 600℃ and 20MPa for evaluation. After the reaction, the changes in kerogen pyrolysis temperature and activation energy are analyzed.

[0132] Table 1 shows the components and contents of the oil recovery agents in the examples.

[0133]

[0134]

[0135] Table 2 Evaluation results of the examples and comparative examples

[0136]

[0137] Figure 1 Here are electron microscope images of the natural minerals after alkali treatment in Example 4. Figure 1 The results showed that the treated minerals had high porosity, abundant specific surface area and pore volume, which could fully adsorb and accommodate active components and organic complexes, and play a role in slow release and structural stabilization.

[0138] The reaction evaluation results of the examples and comparative examples are shown in Table 2. As can be seen from the data in Table 2, compared with Examples 1-10 (without added oil recovery agent), the oil recovery agent obtained by the method of this invention has two advantages: First, alcohol is added to the above-mentioned alkali-treated mixture system. The metal ions in the mixture and the alcohol will form stable metal-containing crystalline alcohols. Through this step, the alcohols and the alkali-treated natural minerals form a composite mineral system. Second, when this composite mineral system is under the temperate and compressive formation conditions of the oil shale zone, the alcohols in the composite mineral system will slowly undergo a chemical reaction, continuously releasing water molecules. The released water molecules are in a supercritical state under these conditions. The system has several key advantages. First, it can efficiently dissolve hydrocarbons and salts in rock formations, allowing them to penetrate the kerogen network structure of oil shale layers and promote the release of generated oil and gas, thus enhancing oil recovery. Second, the system utilizes phytic acid to complex organic polymers. Phytic acid's most significant characteristic is its strong complexing effect with organic polymers, forming stable organic complexes. Under certain temperature and pressure conditions, these organic complexes undergo structural changes, slowly releasing O2 and other organic matter. These substances enter the formation, altering the state of the kerogen and achieving quality improvement. Together with the released water molecules, they enhance in-situ conversion efficiency and increase oil and gas production. Data shows that the addition of the mineral system prepared in this invention significantly increases both the amount of oil discharged and the total amount of oil and gas, with an increase in oil and gas production of 13.98%–19.87%.

[0139] Comparative Example 2 involved the direct addition of organic polymers instead of phytic acid to form an organic complex. The oil and gas yield remained unchanged, showing no significant increase compared to Examples 1-10. Comparative Example 3 involved the addition of only alcohol without any other treatment. The results also showed that adding only alcohol did not significantly increase oil and gas production. Comparative Example 4 involved the addition of only an alkaline solvent. The addition of the alkaline solvent did not improve the in-situ conversion efficiency of the oil shale.

[0140] In summary, the oil extraction agent of this invention improves the in-situ conversion efficiency of oil shale, increases the total amount of oil and gas generated, and has a promising application prospect.

[0141] Of course, the present invention may have other various embodiments. Without departing from the spirit and essence of the present invention, those skilled in the art can make various corresponding changes and modifications according to the present invention, but these corresponding changes and modifications should all fall within the protection scope of the claims of the present invention.

Claims

1. An oil recovery agent for improving the in-situ conversion efficiency of oil shale, characterized in that, include: The oil recovery agent comprises, by weight, alkali-modified minerals, metal ions, organic complexes, alcohols, and alkali-treated solvents, wherein the content of the alkali-modified minerals is 8.0-47 wt%, the content of the metal ions is 0.1-8 wt%, the content of the organic complexes is 0.4-7.0 wt%, the content of the alcohols is 0.8%-20 wt%, and the content of the alkali-treated solvents is 45-85 wt%.

2. The oil recovery agent according to claim 1, characterized in that, Based on the total weight of the oil-producing agent, the content of the alkali-modified mineral is 8.0-30 wt%, the content of metal ions is 1.0-8 wt%, the content of organic complexes is 1.0-7 wt%, the content of alcohols is 1-18 wt%, and the content of alkali-treated solvent is 55-85 wt%.

3. The oil recovery agent according to claim 1, characterized in that, The metal ion includes at least one of sodium, calcium, potassium, iron, magnesium, and titanium; Preferably, the specific surface area of ​​the alkali-modified mineral is 80 m². 2 / g-200m 2 / g, with pore volumes of 0.18mL / g-0.40mL / g; Preferably, the alkali-modified minerals include natural minerals of the kaolin group; Preferably, the kaolinite group of natural minerals includes at least one of kaolinite, montmorillonite, illite, halloysite, attapulgite, leucite, magnesite, calcite, and dolomite.

4. The oil recovery agent according to any one of claims 1-3, characterized in that, The solvent is a C1-C6 lower alcohol; Preferably, the C1-C6 lower alcohols include at least one of methanol, ethanol, and propanol.

5. The oil recovery agent according to any one of claims 1-3, characterized in that, The organic complex is the product of the reaction between an organic polymer and a phytic acid solution; Preferably, the organic polymer includes at least one of carboxymethyl cellulose, methyl cellulose, cellulose, starch, and biomass; Preferably, the phytic acid solution has a mass concentration of 5-80%, and the mass ratio of the organic polymer to the phytic acid solution is 1:1.5-10. Preferably, the organic polymer is treated with phytic acid solution at 50–120°C for 0.5–6 hours.

6. The oil recovery agent according to claim 1 or 2, characterized in that, The pH range of the oil-producing agent is 8.0-14.0, preferably 10-12.

7. A method for preparing an oil-enhancing agent, characterized in that, include: (1) Natural minerals are contacted with alkaline solution for alkaline treatment, and solid-liquid separation is performed to obtain alkaline-modified minerals and alkaline-treated solvent; (2) The organic polymer was treated with phytic acid solution to obtain an organic complex; (3) Mix alkali-modified minerals, alkali-treated solvents, alcohols and organic complexes to obtain an oil production agent.

8. The preparation method according to claim 7, characterized in that, In step (1), the conditions for the alkali treatment include: Temperature 20-100℃; and / or The time is 10-120 minutes; and / or pH range: 8-14.0; Preferably, in step (1), the alkaline solution comprises inorganic bases and / or organic bases; and / or The mass percentage concentration of the alkaline solution is 1-60%; and / or The mass ratio of the alkaline solution to the natural minerals is 1:1 to 8:

1.

9. The preparation method according to claim 8, characterized in that, In step (1), the inorganic base includes at least one of NaOH, KOH, Ca(OH)2, NaNH2, and NH3·H2O; and / or The organic base includes at least one of the following: aqueous solution of 1,1,3,5-tetramethylpiperidine hydroxide, tetraethylammonium hydroxide, tetramethylammonium hydroxide, tetrapropylammonium hydroxide, tetrabutylammonium hydroxide, tetrabutylphosphine hydroxide solution, benzyltrimethylammonium hydroxide, guanethidine, guanethidine, triethylamine, aniline, ethylenediamine, p-phenylenediamine, ethylamine, butylamine, dimethylamine, and diethylamine.

10. The preparation method according to claim 7, characterized in that, In step (1), the total content of metals (in atomic terms) in the natural mineral is 1-80 wt%. Preferably, in step (1), the natural minerals include kaolinite group natural minerals; Preferably, the kaolinite group of natural minerals includes at least one of kaolinite, montmorillonite, illite, halloysite, attapulgite, leucite, magnesite, calcite, and dolomite.

11. The preparation method according to claim 7, characterized in that, In step (3), the solvent is a C1-C6 lower alcohol; Preferably, the C1-C6 lower alcohols include at least one of methanol, ethanol, and propanol; Preferably, in step (3), the concentration of the alcohol is 10-100 wt%.

12. The preparation method according to claim 7, characterized in that, The organic polymer includes at least one of carboxymethyl cellulose, methyl cellulose, cellulose, starch, and biomass; Preferably, the phytic acid solution has a mass concentration of 5-80%, and the mass ratio of the organic polymer to the phytic acid solution is 1:1.5-10.

13. The preparation method according to claim 7, characterized in that, In step (2), the phytic acid solution is used to treat the organic polymer at 50–120°C for 0.5–6 hours. Preferably, in step (3), the total mass ratio of the alkali-modified mineral, the alkali-treated solvent, and the alcohol to the organic complex is 9-1:1-9.

14. The application of an oil-enhancing agent according to any one of claims 1-6 or an oil-enhancing agent prepared by any one of claims 7-13 in oil extraction.

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